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207-093
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251107 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-26 50283201820000 220058 9/20/2025 AK E-LINE Perf BRU 212-35 50283100270000 162018 10/12/2025 AK E-LINE TubingPuncher BRU 234-27 50283202070000 225065 7/17/1905 AK E-LINE CBL-02-October BRU 234-27 50283202070000 225065 10/6/2025 AK E-LINE CIBP/Perf GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey MPL-57 50029236090000 218072 10/27/2025 READ CaliperSurvey MPU B-21 50029215350000 186023 10/25/2025 AK E-LINE RBP NCIU A-07 50883200270000 169058 10/10/2025 AK E-LINE JetCut NCIU A-17A 50883201880100 225089 10/10/2025 AK E-LINE Perf NCIU A-17A 50883201880100 225089 10/14/2025 AK E-LINE Perf PBU 01-10A 50029201690200 225055 8/29/2025 HALLIBURTON RBT PBU 05-11A 50029202520100 196097 10/11/2025 BAKER RPM PBU 05-31B 50029221590200 210085 10/14/2025 BAKER SPN PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM PBU H-07B 50029202420200 225064 9/29/2025 BAKER MRPM PBU L5-27 50029236270000 219046 10/7/2025 BAKER SPN PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF SRU 222-33 50133207150000 223100 7/15/2025 YELLOWJACKET PERF Please include current contact information if different from above. T41066 T41067 T41068 T41068 T41069 T41069 T41070 T41071 T41072 T41073 T41074 T41074 T41075 T41076 T41077 T41078 T41079 T41080 T41081 T41082 T41083 T41084 PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.07 15:03:51 -09'00' 11043, 11267 & 11268(x2) ADL 028280, 028277 & 028278 29 - 8677 By Grace Christianson at 3:31 pm, Sep 25, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.09.25 08:43:32 - 08'00' Sean McLaughlin (4311) 325-581 TS 10/15/25 DSR-9/25/25J.Lau 10/21/25 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. Open hole window milling not to exceed 15'. 10-407 JLC 10/21/2025 10/22/25 To: Alaska Oil & Gas Conservation Commission From: William Long Drilling Engineer Date: September 24, 2025 Re:F-42A Sundry Request Sundry approval is requested to set a whipstock in the F-42A wellbore as part of the drilling and completion of the proposed F-42B CTD lateral. Proposed plan: Prior to drilling activities, screening has been conducted including drift for whipstock, MIT-T, MIT-IA and multi- finger calliper log. Coil has milled the XN-nipple. See F-42B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set a 4-1/2" whipstock on packer and mill a single string 3.80" window + 10' of formation. The well will kick off in the Schublik building inclination down through the Ivishak Zone 4 and back up to land in the Sag formation. The lateral will continue in the Sag to TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8 solid liner, cemented in place and selectively perforated with CDR. This completion will completely isolate and abandon the parent Prudhoe Pool perfs. In addition to cement, a liner top packer is planned. If significant losses are NOT experienced while cementing, the liner top packer will be set. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: 1. Slickline : Dummy WS drift (Unsuccessful 4/8/2025), 40 ARM Multi-finger Caliper (Complete 4/10/2025) 2. Fullbore : MIT-IA and MIT-T to 2,750 psi (Complete 4/9/2025) 3. Coil : Mill XN nipple at 10,439' MD, Dress 10,420' - 10,450', Drift with 3.78" gauge rings to 11,043' (Complete 6/16/2025) 4. Slickline : Dummy WS drift (Unsscccesful with 20', Successful with 10' 6/22/2025) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in November 2025) Reference F-42B Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,364 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2 Packer Whipstock at 10,662 oriented 0° ROHS. 3. Mill 3.80 Single String 4-1/2" Window. 4. Drill build section: 4.25" OH, ~226' (25 deg DLS planned). 5. Drill production lateral: 4.25" OH, ~2626' (12 deg DLS planned). Swap to KWF for liner. 6. Run 3-1/2 x 3-1/4 x 2-7/8 L-80 solid liner. 7. Pump primary cement job*: 38 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). NOTE: Volumes will be updated based on actual window depth and TD. 8. Only if not able to do with service coil extended perf post rig; perforate ~1500' Liner with 1-1/4" CS Hydril 9. Freeze protect well to a min 2,200' TVD. 10. Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Liner lap test, set KO GLV's, contingent LTP 3. Service Coil : Post rig CBL and perforation ~3 x 500 see extended perf procedure attached. 4. Testing : Portable test separator flowback. William Long CC: Well File Drilling Engineer Joe Lastufka 907-263-4372 Well Date Quick Test Sub to Otis - Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular CL Annular Bottom Annular CL Blind/Shears CL Coiled Tubing Pipe / Slips Kill Line Choke Line CL BHA Pipe / Slip CL Coiled Tubing Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR#-AC BOP Schematic CDR Rig's Drip Pan Fill Line Normally Disconnected HP hose to Micromotion LP hose open ended to Flowline (optional) Hydril 7 1/16" Annular Blind/Shear CT Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross CT Pipe/Slips BHA Pipe / Slips nneeeeeceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 2 1 5 1 4 9 "1- 0c► 3 21 .41 2 4 RECEIV 26 65 7 4117,6c,s% 16 65 9 RIM SAN 1907 2 BAKER PRINT DISTRIBUTION LIST HUGHES AOCCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME G-10DIz F-42Aij N-30 900 E.Benson Blvd. ex. / /201 R ,i K BEND Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE December 6,2015 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(cilbakerhughes.com TODAYS DATE January 18,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- FINAL FIELD/ CD/DVD FINAL COMPANY PRELIM (las,dlis,PDF,META, SURVEY REPORT LOGS LOGS CGM,Final Surveys) (Compass) ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) PERSON ATTENTION #OF PRINTS #UI-I'KIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 1^ 1 550 West 7th Avenue,Suite 802 SC ®�SE® !YI 3 LU IU Anchorage,Alaska 99501 bra **Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 0 I 0 I 0 I 0 I 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMSON e ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill Plug RI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-093 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22108-01-00 7. Property Designation(Lease Number): ADL 0028278 8. Well Name and Number: PBU F-42A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED-a 11.Present Well Condition Summary: E 1 m Total Depth: measured 11360 feet Plugs OCTems Pmeasured feet Oo 7 2 Un$5 true vertical 9150 feet Junk measured 11260 feet Effective Depth: measured 11274 feet Packer measured 6308 feet true vertical 9108 feet Packer true vertical 5574.75 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 34-114 34-114 Surface 2659 13-3/8"68#NT-80 34-2693 34-2693 5020 2260 Intermediate 6432 9-5/8"47#NT8OS 31 -6463 31 -5677 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11030-11055 feet 11152-11157 feet 12257-12268 True vertical depth: 8983-8998 feet 9050-9052 feet 8938-8945 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 26-10454 26-8565 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: s f n S ANNEL JAI\ 2 0 LA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 732 35669 4610 1260 1322 Subsequent to operation: 741 34720 4665 2011 1335 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ij Exploratory 0 Development a Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I7 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 134,...1 ( Phone +1 907 564 4424 Date 10/7/15 Form 10-404 Revised 5/2015 J'71 1 f / Alti Q,�� CRSDMS OCT - 7 2015 Submit Original Only 41 40 m a o 0 0 0 0 0 0 is mcor oo N N- V LO to Ln C N V U y 0 0 0 0 0 0 i N I- V tt M M M 7 O 00 N N N M LOCO I` ti 00 00 00 , CON- r-- 1.0001.0 CO O CO = s- In N t.O lO OO a) O) C7O • i i i I I I I I- I� IO O NI' Nr = 00 M 1.0 T- O M M M N c- N LU O CA mm = CO M Nr N- O M O N M O = N CO O 0 p M M M M N N 0 N N C LL M 00 F- a w 0O O w ° IL PpCDC) _j0 OZZ °° °o 2 O O N O M UN _ U O M CV CV N CI LO r i CO +' M N N M O LO M 00 O M N C 00 CO V N M M 00 J (N (0 (0 NYCYC O W I Q C - U W ' NQ � 0 U• O W W . Q D W Z Z a W W W W W m Q D t Z_ Z_ Z_ Z_ D U CA JJ J .. H • Packers and SSV's Attachment PBU F-42A SW Name Type MD TVD Depscription F-42A PACKER 6307.71 5574.75 7" Baker ZXP Top Packer F-42A TBG PACKER 10448.95 8561.02 4-1/2" Baker ZXP Packer . • 7 as 0_ co O C 0 0 c E C I \ E co § ƒasd 2 (‘) / � a n 2 75— 0 Q G 'S a) e ƒ u G / o � 21 / 0' o m � \ �_ / O / co _o _a \ « e 0 _ \ \ / \ » \ m \ \ / // k / , 0 0 w I • 0 E R E £ U 0 S CDC 7.± ® ® D \ ® m CO 0 / _ _2 e / = 2 " 2 g •g U / & f U \ R t \ ¢ ¢ w / Ls) r - \ ® \ w c 3 / / 0 \ \ TREE= 4-1/16"CtW IfiTYNOTES:***4-1/2"CHROME TBG&LNR*** ACTUATOR= BAKER C KB.ELEV= 66.61' BF.ELEV= 37.11' KOP= 3299' Max Angle= 61°@ It284" ' ' 2136' 4-1/2"HES X NP,ID=3.813" Datum MD= 10856 GAS LFT MANDRELS Datum TVD= 8800'SS1 ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3614 3607 15 KBG2 DOPE RIC " 16 11/05/07 13-3/8"CSG,68#,NT-80 GYNE ID=12.415" —1 2692' 4 6325 5586 49 KBG2 SO RK r 20 11/05/07 3 8323 6934 39 KBG2 DMY RC r 0 08/20/07 ESTIMATE)TOP OF CEMENT —r— ? QF-0 2 9525 7858 40 KBG2 DMY RK 0 08/20/07 i P 1 10263 8417 39 KBG2 DMY RK r 0 08/20/07 7"SCAB LN2,26#,L-80 TC$ --r 6299' 1 .0383 bpf,ID=6.276" 7 6299' —9-5/8"X 7"BKR C-2 ZXP LW w/11.6'TtBACKSLV,ID=6.26 6309' —7"BKR PORTED TEBK ASSY Minimum ID =3.725" @ 10439' w/NO GO LOCATOR D=6.170" 4-1/2" HES XN NIPPLE 831T H9-5/8"X 7"BKR FMC LN2 HGR,ID=6,33" 9-5/8"MLLOUT WINDOW(F-42A) 6463'-6480' 9-5/8"W-i 'STOCK(08/07/07) H 6464' 10332' .R4-1/2"HES X NP,ID=3.813" 9-5/8"EZSV(08/07/07) — 6485' 10353' —7"X 4112"BKR S-3 FCR, 0=3.875" 4-1/2"TBG STIR(07/28/07) H 6848' CI M t , 10376' —14-1/2"FES X NP,D=3.813" PERFORATION S1 MiARY 11111111/1 =-�11111/111R-= REF LOG:MAO GR ON 08/19/07 ►11111111111. ANGLE AT TOP PERF:53°@ 11030' ' ;1111111 , 10439' —14-1/2"Nth XN NP,D=3.725• Note:Refer to Production DB for historical perf data 11111 SIZE SPF INTERVAL Opn/Sqz DATE 1'O'1VOV1 2-7/8" Ir 6 11030-11055 0 11/27/07 11111111111111111 10446' —7"X 4-1/2"BKR ZXP LTP" 2-7/8" r 6 11152- 11157 0 11/27/07 1111111111111111..111.11 , ` w 1 11'TACK D=4.410 11 I1 \\\ 10451' —14 D 1/2"WLEG, =3.958" 111111111 11111- 11 1111111111111111- 10464' —7"X 41/2"BKR HMC 1.4.1 .1 LNR HGR,D=4.400" 9-5/8"CSG,47#,NT-80S NSCC,0=8.681" I 10853' MME , 10471' --15'X 4-1/2"XO,D=3.958" Mtn '1..1"1'1'1'11"1' ►11111114 41/2"TBG,12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958" H 10451' 1 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" H 10600' 11260' H FIStt MLLED 013P(09/18/15) PBTD — 11274' -' •i•i•i 0•••••.. ••• 4-1/2"LNR,12.61#,13CR 80 VAM TOP, .0152 bpf,D=3.958' 1- 11360' DATE REV BY COMMENTS DATE REV BY COAMBYTS FRUDHOE BAY UNIT 01/05/91 N22E ORIGINAL COMPLETION 10/07/15 SW/JMD FISH:MLLE)asp(09/18/15) WELL F-42A 08/24/07 i N2ES SIDETRACK(F-42A) PERMIT No:"'2070930 11/19/07 JLJ/PJC GLV C/O(11/15/07) AR No: 50-029-22108-01 11/28/07 SRB/PJC NTIAL PERFORATIONS SEC 2,T11N,R13E, 1910'FN-&2173'FEL 07/01/08 CAZ/PJC DRLG DRAFTCOMECT1ONS 10/01/09 RRLYSV SET CDP(09/13/09) BP Exploration(Alaska) • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (~ ~ - Q ~.~ Well History File Identifier Organizing (done) RE AN Color Items: ~eyscale Items: ^ Poor Quality Originals: ~..o,<,a iuuiuiuimuii DIG TAL DATA Diskettes, No. ^ Other, No/Type: Re,~a~~e~ee iiiuiiiuiiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ^ Other:: '" °~ 1 ~ ~ f~ /s/ Pro'ect Proofin J g III IIII'I IIIII II III BY: Maria Date: ~ cy- ~. ~ ~ '"' l.~J ~ /s/ x ~ 30 = ~ + ~~. = TOTAL PAGES Scanning Preparation _ (Count does not include cover sheet) BY: Maria Date: ,r~ ~ ~'" '~ ~ ~-° c~a /s/ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: l ~ °'~~ '° ~~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ IIIIIIII Scannin is com fete at this point unless rescanning is required. II I II ~) II I 9 P ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lII III III III 10/6/2005 Well History File Cover Page.doc ,: ~. ~ ~s ~, r~. ',~ ""~, f_~ ~ ~~ b ~~ wx ,~ .tee ~ - r ~.. rt ~.. n ~ E a `a MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 9/23/2009 Permit to Drill 2070930 Well Name/No. PRUDHOE BAY UNIT F-42A Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-22108-01-00 MD 11360 TVD 9150 Completion Date 11/27/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / ly mearrrmi rvumuer ryarng a~aro mcwa rvo scan 7wp ~+n RCl:C1VC4 ~.vnnncnw D C Las 15486 Induction/Resistivity 113 6338 Open 10/3/2007 DRHO, FNCL, GR, NCNL, ~ ~ NPHI, RHOB, ROP w/EMF graphics D Asc Directional Survey 29 11360 Open 12/3/2007 Directional Survey 29 11360 Open 12/3/2007 pt LIS Verification 6331 11273 Open 5/19/2008 LIS Veri, GR, FET, RPD, RPX, RPS, RPM, ROP, FCNT, NCNT, NPHI, I RHOB,DRHO iED C Lis 16255 Induction/Resistivity 6331 11273 Open 5/19/2008 LIS Veri, GR, FET, RPD, ~ HOP, RPM I P FCNTRNCN RHOB,DRHO og Induction/Resistivity 25 Col 6463 11360 Open 11/3/2008 i MD ROP, EWR, DGR, ALD, CTN 21-Aug-2007 /i J Log Induction/Resistivity 25 Col 6463 11360 Open 11/3/2008 TVD ROP, EWR, DGR, ALD, CTN 21-Aug-2007 D C 17123 Induction/Resistivity 0 0 Open 11/3/2008 PDS, EMF and CGM graphics for EWR logs ' Vell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 9/23/2009 Permit to Drill 2070930 Well Name/No. PRUDHOE BAY UNIT F-42A Operator BP EXPLORATION (ALASK/~ INC MD 11360 ND 9150 Completion Date 11/27/2007 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Chips Received? --~7N"-- Analysis -~Fld-~'~ Received? Daily History Received? ~ N Formation Tops ~/ N API No. 50-029-22108-01-00 UIC N Comments: Compliance Reviewed By: Date: •I •I ~ ~ WELL LOG TRANSMITTAL 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: F-42A October 14, 2008 AK-MW-5193678 F-42A: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22108-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22108-01 Digital Log Images: 1 CD Rom 50-029-22108-01 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: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907``-273=3536 Date: Signed: ~o~ - v~3 '~ ,~- r 23 --~ ,~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska May 14, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: F-42A AK-MW-5193678 1 LDWG formatted CD rom with verification listing. API#: 50-029-22108-01 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 ~~~ t ~~ Date: ~ ~- ~' ~ ~ " Signed: ~ V ~~ moo„ ~ l Ga~~j STATE OF ALASKA /,~~~ ALASKA~L AND GAS CONSERVATION COM~SION ~'~~ DV~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ~~ C2~.ZO~l7 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAa,c zs.los 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 br ' ~"' ®Developrnllt~~xploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11!27/2007 ~ 12. Permit to Drill Number 207-093 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded G,"" 8 2007 13. API Number 50-029-22108-01-00- 4a. Location of Well (Governmental Section): Surface: 1910' FNL 2173' FEL SEC 02 T11N R13E UM 7. Date T.D. Reached 8/20/2007 ~ 14. Well Name and Number: PBU F-42A - , , . , , , Top of Productive Horizon: 1665' FSL, 5089' FEL, SEC. 35, T12N, R13E, UM 8. KB (ft above MSL): 67.06' Ground (ft MSL): 35.74' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1551' FSL, 154' FEL, SEC. 34, T12N, R13E, UM 9. Plug Back Depth (MD+T~/p) 11274 ~ 9108 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 652648 y- 5974904 Zone- ASP4 .10. Total Depth (MD+TVD) 11360 9150 16. Property Designation: ADL 028278 TPI: x- 649657 y_ 5978419 Zone- ASP4 Total Depth: x- 649315 y- 5978298 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25. 71) MWD DIR / GR /RES / PWD, DIR / GR /RES /DEN / NEU ~i~/dG+w~ ~3yKS"M~J S : ~7JiD 22• CASING, LINER AND CEMENTING RECORD CASING .SETTING DEPTH MD .SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Surface 110' S rface 110' 13-3/8" 68# L-80 Surface 2692' Surface 2692' 17-1/2" 3673 cu ft Permafrost 9-5/8" 47# L-80 Surface 4 Surface 5677' 12-1/4" 2310 cu ft Class'G' 7" 26# L-80 6299' 10600' 5569' 8677' 8-1/2" 719 cu ft LiteCrete 125 cu ft Class 7" 26# L-80 Surface 6308' Surface 5575' Tieback 281 cu ft GasBlok Ex . 'A', 241 cu ft'G' 4-1/2" 12.6# 13Cr80 10446' 11360' 8559' 9150' 6-1/8" 152 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. Tuewc RECORD If Yes, list each interval open (MD+TVD of Top 8~ Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 10451' 10353' MD TVD MD TVD 11030' - 11055' 8983' - 8998' 11152' - 11157' 9050' - 9052' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT St KIND OF MATERIAL USED 2200' Freeze Protect w/ 75 Bbls of Diesel 26• PRODUCTION TEST Date First Production: December 1, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 12/19/2007 HOUfS Tested: 4 PRODUCTION FOR -TEST PERIOD OIL-BBL: 339 GAS-MCF: 3,099 WATER-BBL: 811 CHOKE SIZE: 92 GAS-OIL RATIO: 9,142 Flow Tubing Press. 1,140 Casing Press: 1,840 CALCULATED 24-HOUR RATE• OIL-BBL: 2,034 GAS-MCF: 18,596 WATER-BBL: 4,865 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 2A.,A,AC.25.Q.Q s LOt~;ir'gq~7~E'i':G~l None ~ ~~. ~~~ ~ (i 2008 d~~ ~i~~~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE V 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD WeIlTested. ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 10605' 8681' None Shublik 10664' 8725' Sadlerochit 10764' 8800' Top CGL /Zone 3 10921' 8912' Base CGL /Zone 2C 11022' 8978' 25N /Zone 26 11140' 9044' 23N 11220' 9083' Formation at Total Depth (Name): 23N 11220' 9083' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Perf Operation Summary, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d ~ Z~~o7 gne Terrie Hubble Title Technical Assistant Date PBU F-42A 207-093 Prepared ey Mame/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Kris Honas, 564-4338 INSTRUCTIONS GeNer~A~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 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). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: F-42 Common Name: F-42 -_ __ ~ - YP - P ~ - ) _ P (__ ) ___ ~ -__ ___ -__ ( -) i Test Date ~ Test T e Test De th TMD Test De th TVD AMW Surface Pressure Leak Off Pressure BHP EMW -- _ _ _._ 8/8/2007 FIT 6,499.0 (ft) 5,700.0 (ft) 8.80 (ppg) ~ 950 (psi) 3,556 (psi) 12.01 (ppg) 8/18/2007 FIT 10,600.0 (ft) 8,677.0 (ft) 8.40 (ppg) 1,040 (psi) 4,826 (psi) 10.71 (ppg) • Nnntea: tsizaizuui iz:auno rm ~ ~ BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: F -42 Common W ell Name: F -42 Spud Date: 12/13/1990 Event Name : R EENTE R+COM PLET E Start : 8/4/2007 End: 8/24/2007 Contractor Name: N ABOBS ALASK A DRI LLING I Rig R elease: 8/24/2007 ,Rig Name: N ABOBS Rig N umber: 2ES Date From - To 'I Hours Task Code ~, NPT I Phase Description of Operations 8/3/2007 22:00 - 00:00 2.00 MOB i P ~ PRE Release rig from F-O1A at 2200 hours. Rig down for move to F-42A. 8/4/2007 00:00 - 06:00 6.00 MOB P PRE Rig down primary unit. Move camp, shop and out buildings. Pull pits away from primary unit. Prepare to move sub to F-42A. 06:00 - 08:00 2.00 MOB P PRE Move rig from F-01A to F-42A. 08:00 - 12:00 4.00 MOB P PRE Set new tree and tubing spool behind rig for later placement. Lay down herculite and spot sub over well. Spot pits and hook up interconnect. Build berms. Hook up water and steam to rig. Spot cuttings tank and out buildings. Calibrate alarm systems. 12:00 - 12:30 0.50 MOB P PRE Hold pre-spud safety meeting. Rig accepted at 1200 hours. 12:30 - 17:00 4.50 WHSUR P DECOMP Install secondary annulus valve and rig up circulating lines. Tie into OA with test pump. Use diesel to test the 9-5/8" x 13-3/8" annulus and packoff to 2000 psi for 30 minutes. Monitor IA. Test OK. Shut in. Make up bleed hose and bleed off. 17:00 - 18:00 1.00 WHSUR P DECOMP Pick up and make up DSM lubricator to tree. Pressure test lubricator to 500 psi. Pull BPV. Well on a vac. Lay down lubricator. 18:00 - 20:30 2.50 W HSUR P DECOMP MU circulation lines to top of tree. Line up and reverse diesel freeze protect out of tubing. Shut in. Swap lines and circulate out annulus through choke manifold to cuttings tank at 150 gpm. Blow down and rig down lines. 20:30 - 22:00 1.50 WHSUR P DECOMP Dry rod TWC and test from below to 1000 psi. Blow down and rig down lines. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM. Nipple down tree and adapter flange and remove from cellar. 8/5/2007 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. Function test all lock down screws. Verify XO to hanger thread. Make up with 11-1/2 turns by hand. Threads appear in good shape. 01:00 - 04:00 3.00 WHSUR P DECOMP PJSM. Nipple up BOP stack. Install turn buckles, riser and mouse hole. PJSM. Fill stack. Check for leaks. Test surface equipment to 3500 psi. Check for leaks on 4" mud line. Good tests. Fill choke and gas buster. MU TIW and dart to 4" test joint. 04:00 - 10:00 6.00 BOPSU P DECOMP PJSM. Test ROPE to 250 psi low, 3500 psi high and Hydril to 250 psi low and 2500 psi high as per AOGCC. Witness waived by Bob Noble with AOGCC. Test witnessed by WSL's Mitch Skinner and Dick Maskell and Toolpushers Bruce Simonson and Cleve Coyne. 10:00 - 11:30 1.50 BOPSU P DECOMP PJSM. Pick up a joint of drill pipe. Make up XO for hanger to landing joint and lay back down. PU casing equipment. Clear and clean floor. 11:30 - 12:30 1.00 BOPSU P DECOMP PJSM. Bring up DSM lubricator and lubricator extension. Make up DSM lubricator. Secure and pressure test to 250 psi. Attempt to pull TWC. 12:30 - 18:30 6.00 BOPSU N DPRB DECOMP Unable to engage TWC. Pull lubricator assembly out and hang back. Make up joint of DP. Flush hanger neck at 520 gpm. Lay down DP. Secure lubricator assembly and attempt to engage TWC. Still unable to screw in. Pull string out and inspect threads. Found small rock on tool shoulder. Make up and try again. Able to engage but unable to retract tool. Suspect junk on top of plug. Rig up circulating lines to IA. Put 500 psi under TWC but unable to establish circulation. Plug still set. Bleed off Printed: 8/26/2007 1:34:31 PM BP EXPLORATION Page 2 of 15 Operations. Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/5/2007 ~ 12:30 - 18:30 F-42 F-42 Spud Date: 12/13/1990 REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 NABOBS Rig Number: 2ES Hours ' Task 'Code 6.001 BOPSU~N 18:30 - 19:00 0.50 BOPSU P 19:00 - 20:00 1.00 PULL P 20:00 - 20:30 I 0.501 PULL I P 20:30 - 00:00 I 3.50 I PULL I P 18/6/2007 00:00 - 01:30 1.50 ~ PULL P 01:30 - 02:00 0.50 PULL P 02:00 - 07:30 5.50 PULL P 07:30 - 09:00 1.50 PULL P 09:00 - 11:00 2.00 BOPSU P 11:00 - 12:00 I 1.001 CLEAN I P 12:00 - 14:30 2.501 CLEAN ~ P 14:30 - 19:30 ~ 5.00 ~ CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 21:30 1.00 WHSUR P 21:30-23:30 I 2.001 WHSURIP NPT ~ Phase Description of Operations DPRB DECOMP pressure. Disengage plug. Pull and hang back assembly. Make up joint of drill pipe with small ID XO. Make up top drive and flush profile at 550 gpm with 250 psi for 10 minutes. Inspect lubricator string connections and secure lubricator. DECOMP ,Engage TWC and retrieve. Break and LD lubricator and extension. Blow down and rig down cellar lines and circulating lines. DECOMP Pick up and make up landing joint. Screw into hanger neck and MU top drive. DECOMP Evacuated rig due to high level H2S alarm. Driller and lead (floorhand secured the well. The crew evacuated to the primary ;muster area. All hands were accounted for. The loader operator closed off the pad entrance and the pad operator was notified. A meeting was held with the senior staff and the field engineers for BP and Nabors were notified. A probable false alarm was suspected. Two personnel trained with SCBA breathing apparatus donned the gear, checked the rig from outside with hand held positive read H2S monifors, checked the shaker and inside rig areas and announced the all clear. The crews returned to work and discussed the operation. Several observations were noted with all hands participating in the discussion. (A subsequent discussion was held with the other crew when they came on tour.) DECOMP Back out lock down screws. Unseat hanger with 165k up. Pull to floor with 100k. Break circulation surface to surface at 500 I gpm with 450 psi. Break out hanger. Break and lay down landing joint. Rig up spooling unit. Pull 4-1/2", 12.6#, NT 13Cr-80 tubing. DECOMP PJSM. LD 4-1/2" tubing to SSSV at 52 joints. Recover 26 control line protectors and 3 SS bands. DECOMP PJSM. Rig down control line spooler. Lay hanger and spooler down beaver slide. Norm test control line. Test OK. Clear floor. DECOMP i Lay down 4-1/2" tubing. Pull 171 full joints, 2 GLM, and one cut joint at 25.26'. DECOMP PJSM. Rig down and lay down casing equipment. Pick up test plug and wear ring. Clear and clean floor. DECOMP PJSM. Install test plug. MU TIW on 4" test joint. Test lower 2-7/8" x 5" variable rams to 250 psi low, 3500 psi high as per AOGCC. Unable to test. Leaking past test plug. Attempt to RILDS. Energize seal. Still leaking. Pull plug and tighten rubber. Run back in. Test OK. Pull test plug. Break out TIW. DECOMP PJSM. Install wear ring. Bleed off OA from 70 psi. Leave open to tank and monitor. DECOMP PJSM. Rabbit, PU and make up bit, bit sub, string mill, bumper sub, 9 DC's, 18 HWDP and XO to 848'. DECOMP PJSM. Pick up and RIH with 4" drill pipe to 6730'. Rack back one stand. DECOMP Pump sweep surface to surface at 500 gpm with 1300 psi. DECOMP PJSM. Pick up and make up 9-5/8" storm packer. Set 10' below ground level. Test to 500 psi from below. Back out and lay down running tool. Up 150k, do 130k. DECOMP PJSM. MU XO and pull wear ring. MU packoff running tool. Engage packoff. Make up top drive and pull and release Pri ntetl: 8/26/2007 1:3431 PM BP EXPLORATION Operations Summary Report Page 3 of 15 Legal Well Name: F-42 'Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES Date From - To ' Hours Task i Code NPT ~ Phase Description of Operations 8/6/2007 121:30 - 23:30 2.00 WHSUR P DECOMP several times with a max pull of 130k up. Packoff would not ;pull. 23:30 - 00:00 0.50 BOPSU P DECOMP i PJSM. Nipple down BOP stack. 8/7/2007 00:00 - 03:00 3.00 WHSUR P DECOMP ., PJSM. Remove mouse hole and riser. Finish ND BOPE. Nipple down tubing spool. The 9-5/8" pack off was stuck in tubing spool. Set back BOP stack. Remove tubing spool from well head. Jack up rig to open doors and remove spool from cellar. Bring new casing spool into cellar. 03:00 - 07:00 4.00 WHSUR P DECOMP PJSM. Install new 9-5/8" pack off. RILDS. Install new casing spool. Nipple up casing spool and BOP stack. Pick up test joint and install wear ring. LD test joint. Test void and bottom break to 5000 psi for 30 minutes. Test OK. 07:00 - 08:00 1.00 WHSUR P DECOMP PJSM. Pick up RTTS running tool and make up with 1 joint of drill pipe and TIW. Stab in with 17 rounds to the right. Open TIW, no pressure. Close and test top break against top rams to ~ 250 psi low, 3500 psi high as per AOGCC. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Cleve Coyne. 08:00 - 09:00 1.00 WHSUR P DECOMP ~ PJSM. Latch up top drive and pull and release RTTS with ~ % 150k. Pull to floor, break and lay down. Establish circulation 'and pump dry job. Blow down. Install air slips and rubbers. 09:00 - 09:30 0.50 WHSUR P DECOMP PJSM. POOH with mills to 4489'. Up weight 150k, down 130k. 09:30 - 10:30 1.00 WHSUR P ~ DECOMP Service top drive and lubricate rig. 10:30 - 12:00 1.50 WHSUR P DECOMP PJSM. POOH to 848'. Clear and clean floor. 12:00 - 13:30 1.50 WHSUR P DECOMP PJSM. Stand back HWDP and drill collars. Break and lay down bit, bit sub, mills and bumper sub. Clear and clean floor. 13:30 - 18:30 5.00 DHB P DECOMP PJSM. Rig up E-line. Make up EZSV and RIH. Log and corelate. Set plug at 6485'. Top of window will be -6464'. POOH with E-line. Rig down E-Line unit. 18:30 - 19:30 1.00 DHB P DECOMP Line up and test EZSV and casing to 3500 psi for 30 minutes. Record for corelation with FIT. Test OK. 19:30 - 20:30 1.00 STWHIP N HMAN WEXIT A pallet broke carting the MWD tools (TM & DM) while setting pallet down on rig mat. The tools fell approximately 3' to the mat. All personnel were clear of the area. The tool had to be re-checked to verify functionality. Tools tested OK. 20:30 - 23:00 2.50 STWHIP P WEXIT PJSM. Pick up and make up whipstock BHA. PU single of HWDP. MU mills, flex joint, float sub and DM collar. Scribe offset. Unpin and MU whipstock slide. MU RLL tool and TM collar. 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT MU XO and flow test MWD. No pulse. Pull up and plug in to trouble shoot. 8/8/2007 00:00 - 03:00 3.00 STWHIP N DFAL WEXIT PJSM. Break out TM and LD. Break out RLL and MWD. Lay down in shed. Plug in and test. Bad RLL. Change out RLL and pulser on TM collar. PU new RLL and TM. Upload MWD. Surface test MWD. Good test. 03:00 - 03:30 0.50 STWHIP P WEXIT Flow test MWD equipment. 03:30 - 05:00 1.50 STWHIP P WEXIT PJSM. Pick up remaining BHA to 963'. Change out handling equipment. 05:00 - 08:00 3.00 STWHIP P WEXIT RIH with whipstock on 4" drill pipe to 6345'. Fill pipe every 20 stands. Test MWD each time at 500 gpm. Tests OK. RIH at 90 to 120 fpm. Lay down top single on stand 58. PU stand 59 and make up top drive. 08:00 - 09:00 1.00 STWHIP P WEXIT j Establish circulation at 500 gpm with 1800 psi. Orient Printed: 8/26/2007 1:34:31 PM S~ F4~} BP EXPLORATION Operations Summary Report Legal Well Name: F-42 Common Well Name: F-42 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS Date ', From - To Hours ~ Task 'Code NPT __ _ i 8/8/2007 108:00 - 09:00 I 1.00 STWHIPI P 09:00 - 10:00 1.001 STWHIPI P 10:00 - 18:00 I 8.00 18:00 - 19:00. 1.001 STWHIPI P 19:00 - 20:00 I 1.001 STWHIPI P 20:00 - 22:00 I 2.00 ~ STWHIP P 22:00 - 00:00 i 2.00 i STWHIP P 8!9/2007 100:00 - 03:00 I 3.00 I STWHIPI P 03:00 - 04:00 I 1.001 STWHIPI P Start: 8/4/2007 Rig Release: 8/24/2007 Rig Number: 2ES ' Phase W EXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 4 of 15 Spud Date: 12/13/1990 End: 8/24/2007 Description of Operations whipstock to 65 degrees left. Up weight 152k, down 128k. Tag EZSV at 6485'. Slack off to 110k and shear bottom anchor. Pick up to 165k. Slack off to 80k and shear bolt. Pick up and verify. PJSM. Pump 30 bbls hi-vis spacer followed by 8.8 ppg LSND mud. Displace well. Install magnets in ditches and screens to catch metal cuttings. Close manual choke and kill lines on stack. SPR at 6458'/1000 hours. Pump #1 30/280, 45/340. Pum #2 30/280 45/330. Mill window to 6500'. Pump from 300 to 450 gpm with 700 to 1200 psi. WOB 1-10k. Rotate at 60-90 rpm with torque 5-6k off bottom, 9-12k on bottom. Ream and drift window. Up weight 155k, down 125k, RT 137k. Minimal show of cement while milling. TOW 6463' BOW 6480' Hole 6500' Pump 30 bbl super sweep surface to surface at 455 gpm with 1225 psi. Mud weight in and out 8.8 ppg. Line up and perform FIT to 12.0 paa EMW with 950 psi at 5700' TVD. Pump dry job. Blow down top drive, kill and choke lines. Remove blower hose. SPR's both pumps 30/290, 45/330, at 6500'/1900 hours. PU single and POOH to 941'. PJSM. Stand back HWDP. Flush drill collars and MWD tools with fresh water. Lay down drill collars. Plug in and download MWD tools. PJSM. Download MWD. Break out TM collar. Pull pulser and change out. Make up TM to RLL. Lay down together. LD DM and float sub. Break out mills. Top mills in guage. Lay down mills. PU stack jetting tool and 8-1/2" BHA. PJSM. Clear and clean floor. PU test joint. Remove wear ring. Make up stack jetting tool and flush stack at 550 gpm. Reciprocate and rotate at 40 rpm. Function all BOP preventors. Repeat and bleed off. Break out top drive and jetting tool and lay down. Blow down top drive, choke and kill lines. Install wear ring. Recovered a total of 225 Ibs of metal from milling operations. 04:00 - 06:00 2.00 STWHIP P WEXIT PJSM. PU and MU motor, bit, and MWD tools. Plug in and upload MWD. 06:00 - 07:00 i 1.00 STWHIP N DFAL WEXIT MWD tool not reading. Break out DM collar and check connections. Run PWD in mousehole and read without DM. Bad DM. Change out DM collar. Pick up and plug in. Upload and test. Test OK. 07:00 - 08:30 1.50 STWHIP P WEXIT Pick up remaining BHA to 841'. Change out handling equipment. 08:30 - 09:00 0.50 STWHIP P WEXIT Make up top drive. Surface test MWD at 450 gpm with 760 psi. ~ Cycle pumps. Test OK. Break out top drive. 09:00 - 15:00 6.00 STWHIP P WEXIT PJSM. Pick up 39 drill pipe singles. Install ghost reamer. Continue to PU 4" DP to 6449'. Fill pipe and test MWD every 90 joints. Establish baseline ECD at 9.3 ppg. Pump at 450 gpm with 1350 psi. SPR's at 1445 hours/6450', both pumps 30/310, Printed: 8/26/2007 1:34:31 PM ~~ • BP EXPLORATION Operations Summary Report 'Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 8/9/2007 From - To ~ 09:00 - 15:00 15:00 - 16:30 16:30 - 00:00 6.00 STWHIP P 1.50, STWHIP P 7.50. DRILL P 18/10/2007 100:00 - 22:00 I 22.001 DRILL ; P 22:00 - 00:00 ~ 2.00; DRILL P ~ INTi INTi INTi 18/11/2007 100:00 - 08:00 8.00 DRILL ~ P ( ~ INT1 08:00 - 08:30 0.50 DRILL N DPRB INTi 08:30 - 12:30 4.00 DRILL N DPRB INT1 12:30 - 15:00 2.50 ' DRILL N DPRB INT1 15:00 - 17:30 2.50 i DRILL P INT1 Page 5 of 15 Spud Date: 12/13/1990 End: 8/24/2007 Description of Operations 45/350. PJSM. Cut and slip 104' of drilling line. Inspect traction motor brushes and brakes. Lube Elmago hubs. Service top drive, crown and draworks. Orient face and run through window. Second string stabilizer slight hang up and MWD tools slight hang up. Up weight 145k, down 120k. Tag and drill ahead to 6915' MD, 5956' TVD. Up weight 155k, down 110k, RT 135k. WOB 5-15k. Torque 7-9k on bottom, 7-8k off bottom at 80 rpm. Pump at 500 gpm with 2150 psi on bottom, 1910 psi off bottom. AST - 2.43, ART - 2.2. Mud weight in 8.8 ppg, out 8.8+ ppg. Directional drill ahead to 7625' MD. Pump at 500 gpm with 2120 psi off bottom, 2330 psi on bottom. Rotate at 80 rpm with 7-8k torque off bottom, 8-10k torque on bottom. WOB 5-15k. Up weight 167k, down 120k, RT 138k. Mud weight out 9.1+ ppg, mud weight in 9.0+ ppg. SPR's both pumps 30/310, 45/370 at 7568'/1100 hours. AST 4.82, ART 2.72 Continue to drill ahead to 8503' MD, 7075' TVD. Pump at 500 gpm with 2400 psi off bottom, 2605 psi on bottom. Rotate at 80 rpm with 7-8k torque off bottom, 9-10k torque on bottom. WOB 5-12k. Up weight 190k, down 120k, RT 150k. Mud weight out 9.5 ppg, in 9.3 ppg. SPR's at 8414'/2100 hours. Pump #1 30/390, 45/450. Pump #2 30/380, 45/440. AST 1.21, ART 4.92 PJSM. Weight up from 9.3 ppg to 11.2 ppg with 15.3 ppg spike fluid containing product for hole stability and HTHP fluid loss control through HRZ and Kingak. Directional drill ahead to 8876' MD, 7363' TVD. Pump at 475 gpm with 3180 psi off bottom, 3380 psi on bottom. Rotate at 80 rpm with 8-9k torque off bottom, 9-10k on bottom. WOB 10-17k. Up weight 195k, down 125k, RT 150k. Mud weight in and out 11.2 ppg. Calculated ECD 11.66 ppg. ECD 11.99 ppg at 8780' MD. SPR's at 8503'/2400 hours. Both pumps, 30/290, 45/380. AST 2.09, ART 2.61. Pump pressure loss of 900 psi recorded. PJSM. Check and test surface equipment for leaks. No leaks found. PJSM. Mud weight in and out 11.2 ppg. POOH to 6449' into 9-5/8" window. Hole pulling tight from 7290' to 7260', 7060' to 6970' and 6925' to 6920'. Monitor well for 10 minutes. Continue to POOH looking for washout in pipe. Found washout on stand #44 at 4858'. LD washed pipe and replace. Monitor hole for 10 minutes,OK. Up weight 125k, down 105k. PJSM. RIH to 6449'. Change out bottom joint on stand #60, (damaged tool joint at pin base). Make up top drive and fill pipe. Orient to 65 degrees left. Shut down and run through window. Break out top drive. Continue in hole to 8876'. No problems running in hole, good shape. Make up top drive. Fill pipe and wash down stand #88. Top of window up weight 150k, down 105k. Drill ahead to 9017' MD. Pump at 475 gpm with 3620 psi off bottom, 3810 psi on bottom. Rotate at 80 rpm with 8-9k torque off bottom, 9-10k torque on bottom. WOB 12-15k. Up weight F-42 F-42 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS Start: 8/4/2007 Rig Release: 8/24/2007 Rig Number: 2ES Hours Task I Code NPT I Phase W EXIT W EXIT rrmcen: arzbizwi Lanai rm o s BP EXPLORATION Operations Summary Report Legal Well Name: F-42 Page 6 of 15 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES ~ l Date ', From - To ', Hours ' Task Code NPT Phase 8/11/2007 ~ 15:00 - 17:30 ~ 2.50 ~ DRILL P ~ j INTi 17:30 - 18:30 1.00 DRILL P INT1 18:30 - 21:30 3.00 DRILL N RREP INT1 21:30 - 00:00 I 2.501 DRILL I P I i INT1 ~ 8/12/2007 j 00:00 - 00:00 24.001 DRILL j P j INT1 18/13/2007 100:00 - 06:00 j 6.00 DRILL j P j j INT1 06:00 - 07:30 j 1.501 DRILL j P j j INT1 07:30 - 08:30 I 1.001 DRILL I P I I INT1 08:30 - 10:30 j 2.001 DRILL j P j j INT1 10:30 - 11:30 1.00 DRILL P INT1 11:30 - 13:00 1.50 DRILL P INT1 13:00 - 15:00 I 2.001 DRILL I P I I INT1 Description of Operations 190k, down 125k, RT 150k. Mud weight in and out 11.2 ppg. Slow pump rates at 1630 hours/8966'. Pump #1 30/430, 45/530. Pump #2 30/420, 45/530. Service and tube top drive and rig. The #1, 3512 generator lost power. Trouble shooting. Mud weight in and out 11.2 ppg. POOH above HRZ and circulate at 250 gpm with 1192 psi. Reciprocate and rotate at 80 rpm. Rack one stand back every 1/2 hour. Make repairs to motor. Break out top drive and RIH to 9017'. Make up top drive and break circulation. Drill ahead to 9157' MD, 7577' TVD. Pump at 475 gpm with 3545 psi off bottom, 3742 psi on bottom. Rotate at 80 rpm with 7-8k torque off bottom, 8-9k torque on bottom. WOB 12-15k. Up weight 193k, down 125k, RT 153k. Mud weight in and out 11.2. AST .44, ART 2.77. Calculated ECD 11.78 ppg, ECD 11.95 ppg. Drill ahead to 9725' MD, 8014' TVD. Pump at 475 gpm with 3520 psi off bottom, 3710 psi on bottom. Rotate at 80 rpm with 8-10k torque off bottom, 9-11 k torque on bottom. W OB 12-18k. Mud weight in and out 11.2 ppg. Up weight 195k, down 130k, RT 160k. SPR's at 0130 hours/9251' both pumps, 30/410, 45/510. ART 6.21, AST 1.22. Continue to drill ahead to 10358' MD, 8490' TVD. Pump at 475 gpm with 3760 psi off bottom, 4115 psi on bottom. Rotate at 80 rpm with 7-8k torque off bottom, 8-9k torque on bottom. WOB 12-15k. Up weight 197k, down 140k, RT 165k. Mud weight in 11.1 ppg, out 11.2 ppg. SPR's at 1300 hours/9805'. Pump #1 30/390, 45/490. Pump #2 30/400, 45/500. AST 1.81, ART 6.36. Calculated ECD 11.63 ppg, ECD 11.91 ppg. Drill ahead to TD at 10600' MD, 8676' TVD. Pump at 470 gpm with 3870 psi off bottom, 4040 psi on bottom. Rotate at 80 rpm with 7-8k torque off bottom, 9-11k on bottom. WOB 5-14k. Up weight 210k, down 140k, RT 170k. Mud weight in and out 11.2 ppg. Calculated ECD 11.73, ECD 11.90. SPR's at 10371'/0020 hours, both pumps 30/440, 45/540. ART 1.62, AST 2.37. Circulate up samples from TD at 480 gpm with 3990 psi. TD called. Pump hi-vis sweep surface to surface at 500 gpm with 4040 psi. Monitor well for 10 minutes, OK. Mud weight in and out 11.2 ppg. SPR's at 10600'/0830 hours, both pumps 30/360, 45/460. PJSM. POOH to 8503' for wiper trip. Up weight 225k, down 145k. Slight overpull at 9780'-9720', 9400'-9340', 9278'-9246' and 9192'-9172'. Cleaned up after one wipe on each occassion. Service and tube top drive and rig. RIH to 10600' with no problems. Hole in good shape. Make up top drive and wash last stand down to bottom. PJSM. Pump hi-vis sweep surface to surface at 475 gpm with 3850 psi. Rotate at 80 rpm. The #1 pump discharge manifold washed out. Shut in pump and continue to circulate sweep around at 296 gpm with 1865 psi. Will change out manifold on Printetl: 8/26/2007 1:34:31 F'M • r BP EXPLORATION Operations Summary Report Legal Well Name: F-42 Page 7 of 15 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES Date 'From - To 'Hours Task Code NPT Phase Description of Operations 8/13/2007 13:00 - 15:00 2.00 DRILL P INT1 trip out. 15:00 - 17:00 2.00 DRILL P INT1 PJSM. Mud weight in and out 11.2 ppg. POOH to 6552' with no ~ problems. 17:00 - 18:00 1.00 DRILL P INT1 MAD pass from 6552' to 6400' at 300 fph. 18:00 - 20:00 2.00 DRILL P INT1 ~ PJSM. Circulate BU above window in 9-5/8" casing at 294 gpm with 1400 psi. Rotate and reciprocate at 80 rpm. Free torque 5-6k. Break out top drive and drop CCV operating ball, make up top drive and pump operating ball down at 126 gpm with 420 psi. Open circ sub with 1800 psi shear pressure. Verify with pump pressure. Pump dry job and remove blower hose. 20:00 - 23:30 3.50 DRILL P INT1 i PJSM. POOH to 2054'. Break and lay down ghost reamer. Continue to POOH to BHA at 834'. Change out handling ' equipment and monitor well, OK. 23:30 - 00:00 0.50 DRILL P INT1 PJSM. Lay down BHA to 527'. 8/14/2007 00:00 - 03:30 3.50 DRILL P INT1 PJSM. Lay down HWDP, MWD tools and bit. Bring tools down beaver slide. 03:30 - 04:00 .0.50 BOPSU P ~ LNR1 I PJSM. PuII wear ring. Install test joint. ', 04:00 - 05:00 1.00 BOPSU P LNR1 PJSM. Change out top rams from 3-1/2" x 6" variables to 7". 05:00 - 06:30 1.50 BOPSU P LNR1 ~ PJSM. Rig up and test 7" rams to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle.Witness of test waived by AOGCC Jeff Jones 06:30 - 07:00 0.50 BOPSU P LNR1 Pull Test joint and Set Wear Bushing 07:00 - 08:30 1.50 BOPSU P LNR1 Service Rig Top Drive and Draw Works 08:30 - 12:00 3.50 CASE P LNR1 PJSM, Run 7" 26# BTC-Mod casing Baker Lock Shoe Track Best O-Life 2000 pipe Dope Avg Tq 9400 FUlbs 12:00 - 13:30 1.50 BOPSU N SFAL LNR1 ~ Seal on Upper Ram door hinge failed, Change out fluid hinge. 13:30 - 14:30 1.00 BOPSU P LNR1 Service Rig Top Drive, Draw Works and Rig 14:30 - 18:30 4.00 CASE P LNR1 PJSM, Run 7" 26# BTC-Mod casing Best O-Life 2000 pipe Dope Avg Tq 9400 FUlbs Filling every jt, and topping off every 5 jts 18:30 - 19:00 0.50 CASE P LNR1 P/U Baker HMC Liner Hanger and Baker C-2 ZXP LTP Tieback Sleeve 19:00 - 19:30 0.50 CASE P LNR1 i Circ. 170 tills @ 5 bpm / ICP 400 psi, FCP 290 psi PUW = 125k /SOW = 115k 19:30 - 20:30 1.00 CASE P LNR1 RIH to TOW 6372' with 4" DP 20:30 - 21:00 0.50 CASE P LNR1 CBU @ 5 bpm / 560 psi -Conduct PJSM with Schlumberger Cementers and Rig Crew 21:00 - 23:30 2.50 CASE P LNR1 RIH w/4" DP -break circ. @ 8709' @ 5 bpm / 860 psi Continue RIH to 10310'. String took 50k down drag, (75k SOW) Unable to Pick up with 275k PUW, Normal PUW 240k /SOW 107k 23:30 - 00:00 0.50 CASE P LNR1 Worked pipe down to 10326', Screw in and start circulating down @ 2 bpm / 920 psi Worked down slowly, setting 50k down /stroke 8/15/2007 00:00 - 01:00 1.00 CASE P LNR1 Continue Washing casing down @ 2 bpm / 900 psi, Slacking rnmea: aizaizuui i:~aai rnn • BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: F-42 Common Well Name: F-42 '.Event Name: REENTER+COMPLETE (Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS Date From - To ,Hours Task Code NPT I ~_ l 18/15/2007 00:00 - 01:00 I 1.00; CASE P 01:00 - 01:30 0.50 CEMT P 01:30 - 03:00 1.50 CEMT P 03:00 - 06:00 3.001 CEMT P 06:00 - 07:00 1.00 ~ CEMT P 07:00 - 07:30 I 0.501 CEMT I P 07:30 - 09:00 ~ 1.50 CEMT P 09:00 - 14:00 ~ 5.00 CEMT P 14:00 - 18:00 4.00 CASE P 18:00 - 23:00 5.00 CASE P 23:00 - 23:30 0.50 DUMRN P 23:30 - 00:00 0.50 DUMRN P 8/16/2007 00:00 - 02:00 2.00 DUMRN P 02:00 - 02:30 0.50 DUMRN P 02:30 - 05:00 I 2.501 DUMRN I P Spud Date: 12/13/1990 Start: 8/4/2007 End: 8/24/2007 I Rig Release: 8/24/2007 Rig Number: 2ES Phase Description of Operations LNR1 off to 50k down drag and working up to 275k PUW, successfully pick up free @ 240k PUW @ 10342', continue to wash and work down ,free going down @ 10346' -Continue RIH, Washing to bottom without problems -P/U Cement head -Landed @ 10600' LNR1 Stage up circulation to 5 bpm / 980 psi LNRi Circ. Bottoms and condition mud 5 bpm / 980 psi LNR1 Start Cement Job -Pump 5 bbls water and test lines to 4000 psi. -Pump 30 bbls Mud Push II (10.5 ppg.) -Pump 129 bbls Lead Cement @ 5 BPM (12.5 ppg) -Pump 23 bbls Tail Cement @ 5 BPM (15.8 ppg) -Drop Top Plug & Kick Out with 5 bbls water. -Displace with Rig using 11.2 ppg mud @ 5 bpm -Slow pumps to 3 BPM prior to latching liner wiper plug @ top of liner -Bump Plugs with 3500 psi to set hanger as per Baker Plug bumped @ 3824 strokes CIP @ 05:08 8/15/07 Check floats, O. K., Rotated 15 turns to the right, Pressure up 1000 psi, Pick up until pressure drop, Bring pumps up to 10 bpm / 2360 psi for 30 bbls Set 50k down, set ZXP liner top packer with 44k LNR1 Circulate excess cement @ 10 bpm / 2360 psi 10 barrel of cement back to surface Flush Stack with Retarder LNR1 Lay down cement head and single drill pipe, R/D cement lines POH with 1 stand of DP LNR1 Slip and Cut Drilling Line, Service TDS LNR1 Break Circ. to pump dry job, mud clabbered up and cement contaminated Circ. and Condition Contaminated Mud @ 500 gpm / 2100 psi LNR1 POH LNR1 Clean cement and contaminated mud from surface equipment -Pull Wear Bushing, -P/U Stack wash tool and flush BOP's and Tubing spool -Set Wear Bushing -Pull Floor Plates and suck out under Rotary Table and Drip Pans -Clean Pits and Surface Equipment TIEB1 Make up Polish Mill BHA TIEB1 RIH with Polish Mill to Dress Tieback Receptible TIEB1 RIH TIEB1 Wash down through Liner top -set down 10k on nogo TIEB1 Circulate and Condition Cement contaminated mud 420 gpm ! 1200 psi Heavy returns of cement and clay balls on first bottoms up, After second bottoms up hole clean up, Diluted mud back and treat out contamination Printed: 8/2ti/2007 1:34:31 PM • ~ BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: F-42 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES Date I From - To , Hours Task Code 8/16/2007 ' 02:30 - 05:00 2.50 ~ DUMRN P . 05:00 - 05:30 0.50 ~ ' DUMRN P 05:30 - 08:30 . 3.001 DUMRN P 08:30 - 09:00 0.50 ~ CASE P 09:00 - 10:00 1.00 CASE ~ P 10:00 - 11:30 ~ 1.501 CASE ~ P 11:30 - 22:30 11.00 CASE P 22:30 - 00:00 ~ 1.501 CASE ~ P 18/17/2007 (00:00 - 01:30 01:30 - 02:00 02:00 - 05:00 1.501 CEMT I P 0.501 CEMT P 3.001 CEMT P NPT ' Phase ~' Description of Operations TIEB1 Final Mud 10.7 ppg in / 10.8 out TIEB1 Wash down through Liner top -set down 10k on nogo TIEB1 POH and VD Mill TIEB1 Pull Wear Bushing TIEB1 Test & chart Liner & Liner Lap to 3500 psi for 30 min. TIE61 TIE61 TIEB1 TIEB1 TIEB1 TIEB1 05:00 - 05:30 0.50 CEMT P TIE61 05:30 - 07:00 1.50 BOPSU P TIEB1 07:00 - 09:00 2.00 WHSUR N SFAL TIEB1 09:00 - 10:30 1.50 WHSUR P TIEB1 10:30 - 12:00 1.50 BOPSU P TIEB1 12:00 - 14:00 2.00 1 WHSUR P TIEB1 14:00 - 16:30 2.50 BOPSUF I P TIEB1 16:30 - 17:30 1.00 BOPSU P TIE61 17:30 - 18:30 1.00 ~ BOPSU P TIEB1 18:30 - 19:00 0.50 BOPSU P TIEB1 19:00 - 23:30 I 4.501 BOPSUR P I I TIEB1 R/U to Run 7" Tieback Liner Run 7" 26# TCII Tieback Liner Total of 158 jts and 1 pup joint ran -BakerLock Shoe Track -Jet Lube Seal Guard pipe dope -Avg. Tq 10,100 ft/Ibs PUW = 175k SOW = 130k Check Space out, P/U Pups to position Cut Joint in Tubing spool -R/U Cement head and lines -Break circ. -Sting in TBR and Test seals with 500 psi f/5 min, O.K. -UnSting and break circ. -circ. @ 6 bpm / 1000 psi Displace to Seawater 390 gpm / 850 psi PJSM with Schlumberger, LRS, Veco and NAD Rig Crews -Pump 5 bbis of water, PT line to 4000 psi, Pump 5 bbis of 9.5 ppg Mud push -Turn over to LRS and Pump 90 bbis of 80 degree Diesel -Switch over to DS, Drop bottom plug -Pump 50 bbis of 15.4# /gal "GasBlok" expandable A Lead cement -Pump 43 bbl 15.8#/gal "G" Tail Cement, -Drop top Plug, Chase out with 5 bbis of water -Displace with Rig Pumps @ 6 bpm Displace with 236 bbis of 11.2 ppb mud, bump plug on schedule and pressure to 500 psi over pump rate to 1450 psi CIP @ 05:00 hr Slackoff into TBR Seals and land SOW 132k Pickup to PICK UP wieght of 170k RD & Flush lines, RD third party equipment Split Stack and set 7" Casing slips Rig Cameron Wachs Cutter, tool failed, repair cutter Cut off 7" and UD Landing joint Set Back BOP Stack Nipple up New Tubing Spool -test Packoff to 4300 psi for 30 min, good test Nipple Up stack, riser , flowline and turnbuckles Change out Upper Pipe Rams to 6" x 3" Variable Rams Clean Rig after casing /cement jobs Perform Rig Evacuation /Muster Drill PJSM with Rig Crew on Testing BOP's Test Witness by Dave Newton BP WSL, Jon Castle NAD TP Witness of test waived by Chuck Scheve -Set Test Plug Printed: 8/26/2007 1:34:31 PM BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: F-42 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES i Hours ' NPT~ Phase Date From - To ', Task Code ____ 8/17/2007 19:00 - 23:30 4.501 BOPSUF} P ~ TIEB1 23:30 - 00:00 0.50 BOPSU P 8/18/2007 00:00 - 02:30 2.50 DRILL ~ P 02:30 - 03:30 ~ 1.00 DRILL ; P 03:30 - 05:30 2.00 DRILL P 05:30 - 06:30 1.00 DRILL P 06:30 - 07:30 I 1.001 DRILL i P 07:30 - 08:00 ' 0.50 DRILL P 08:00 - 09:00 1.00 DRILL P 09:00 - 11:30 2.50 DRILL P 11:30 - 12:30 1.00 DRILL P 12:30 - 14:30 2.00 DRILL P 14:30-15:30 ~ 1.00~DRILL ~P TIE61 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations Test BOPE, 250 low, 3500 psi high, holding each test for 5 min. and record on chart 4" Test Joint -Test #1 -Top Rams, Dart, HCR Kill & Choke -Test #2 -choke manifold valves 1, 2 & 3 -Test #3 -choke manifold valves 4, 5, 6 -Test #4 -choke manifold valves 7, 8, 9 -Test #5 -choke manifold valves 10, 11 -Test #6 -choke manifold valves 12, 13, 14 -Test #7 -choke manifold valve 15 -Test #8 -hydraulic choke & manual choke -250 low / 1000 high -Test #9 -Lower Pipe Rams -Test #10 -Annular 250 Low / 2500 High -Test #11 - Blinds,0utside Mud Cross valves 4 1/2" Test Joint, -Test #12 -Top Rams, Inside Mud Cross, lower IBOP -Test #13 -Lower Rams, Top IBOP Perform Accumulator Test -3000 psi, bled down to 1600 psi -200 psi recovery 19 secs -Full 3000 psi recovery 1 min 38 sec -6 Bottles of Nitrogen avg. 2200 psi Pull Test Joint and Set Wear Bushing PJSM on P/U BHA and Loading Nuke Sources M/U BHA; Bit, Motor, FS, Stab, MWD/LWD, 3 x NM Flex DC, Circ sub, 3 x HWDP, Jar, 2 x HWDP, XO Shallow hole test MWD, Good Test -Load RA Sources RIH - 6199' Break Circ. and Wash to 6265' -Circ. t/15 min -Test LinerTie-back to 3500 osi hold for 10 minutes and chart Drill Plugs and Ported Float Collar to 6287' -250 gpm / 1850 psi, -30 rpm / 4k fUlbs oft / 5k fUlbs on -3-5k WOB PUW=120k /SOW=95k Wash Down 6287 to 6920' (pushing junk) CBU Q 250 gpm / 1950 psi RIH to 10,399' -wash down to Landing Collar Q 10,513' -precautionary break Circ. every 10 stds. Test & Chart 7" casing for 30 min. -Good test Drill Plugs and Float Equip to 10,595' -250 gpm / 2570 psi off / 2700 psi on -50 rpm / 11 k fUlbs off / 11.5k fUlbs on -8-10k WOB - PUW=190k /SOW=125k RtWt = 150k Displace10.9 LSND Mud to 8.4 FloPro -Pump 50 bbl fresh water pill, 45 bbl Hi-Vis Pill w/Cube and follow with FloPro Printed: 8/26/200/ 1:34:31 F'M • BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: F-42 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES 8/1sDoo7 ~ 15 30 --17:00 Ho 1 5o Task 'Code NPT Phase Description of Operations DRILL ~ P ~ ~ PROD1 Drill Float Shoe and 26' of New Hole' 17:00 - 17:30 I 0.501 DRILL I P 17:30 - 00:00 I 6.501 DRILL I P 18/19/2007 100:00 - 07:00 I 7.001 DRILL I P 07:00 - 08:00 1.00 DRILL P 08:00 - 13:00 5.00 DRILL P 13:00 - 15:00 2.00 DRILL P 15:00 - 17:30 I 2.501 DRILL I P 17:30 - 22:00 4.50 DRILL P 22:00 - 00:00 2.00 DRILL P 18/20/2007 100:00 - 15:00 ~ 15.00 ~ DRILL P -300 gpm / 2090 psi off / 2280 psi on -50 rpm / 4k ft/Ibs off / 5k ft/Ibs on -10k WOB ~-PUW=175k /SOW=140k RtWt= 155k PROD1 ~ Perform FIT to 10.7ppg EMW Pump 1.3 bbl to 1040 psi, held for 10 min PROD1 Directional Drill as per HES Directional Driller, 10626' - 10766' (8801'tvd) - 80 Rpm , 4k Tq off / 5k Tq On - 300 gpm, 2090 psi off / 2200 psi on - 8-10k WOB PUW 175k /SOW 140k / RtWt 155k AST= 4.85 /ART=.43 ADT=5.28 Mud Wt. 8.4 in/out PROD1 Directional Drill as per HES Directional Driller 10766' - 10920' (8909' tvd) - 80 Rpm , 4k Tq off / 5k Tq On - 300 gpm, 2220 psi off / 2350 psi on - 3-10k WOB PUW 175k /SOW 140k / RtWt 155k Mud Wt. 8.4 in/out AST = 4.94 hrs Unable to get DLS from Bit & BHA, POH for BIT and increase in PDM bend PROD1 CBU @ 295 gpm / 2270 psi Monitor Well, static 8.4 ppg in/out PROD1 POH to BHA -No issues pulling through open hole PROD1 PJSM on handling BHA and Handling RA source on surface Set Back HWDP, Jars, Flex DC's, -Remove RA Source -Download MWD Data -Break Bit PROD1 M/U Bit and Motor, Adjust motor AKO to 1.76 deg -Orient with MWD, Shallow hole test MWD -Load Nukes RIH to 403' and change handling equipment PROD1 RIH to 10,865, Fill Pipe every 30 stds Break Circ. and Wash to bottom, No Fill PROD1 Directional Drill as per HES Directional Driller 10920' - 10,958 (8937' tvd) - 250 gpm, 2020 psi off / 2220 psi on - 10-18k WOB -PUW 175k /SOW 140k / RtWt 155k - AST = 0.97 hrs - MW 8.5 ppg in/out PROD1 Directional Drill as per HES Directional Driller 10,958-11,360 - TD (9149' tvd) - 290 gpm, 2240 psi off / 2360 psi on - 60 RPM Torque 5k off / 6-10k on - 10-20k WOB -PUW 185k !SOW 135k / RtWt 155k Printed: 8/26/2007 1:34:31 PM • A BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: F-42 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES Date ~ From - To ~ Nours Task II Code'~~ NPT I Phase Description of Operations 8/20/2007 00:00 - 15:00 15.00 DRILL P PROD1 -Mud Wt. 8.5 in/out - AST = 7.41 hrs ART = 4.64 hrs ADT = 12.05 hrs ' 15:00 - 16:00 1.00 DRILL P PROD1 CBU 290gpm / 2420 -Monitor well for 10 min, static 8.5 ppg in /out 16:00 - 19:30 3.50 DRILL P PROD1 Mad Pass Log to shoe -Backream @ 20 rpm T0= 5K -250 gpm / 1920 psi -No Problems backreaming to shoe -Monitor well @ shoe for 10 min, static j 19:30 - 20:00 0.50 DRILL P PROD1 RIH, No issues running in j -Precautionary ream last stand to bottom, No Fill 20:00 - 21:30 1.50 DRILL P PROD1 Pump 40 bbl Hi-Vis Sweep around, cuttings increase 15% with sweep -Circulate till shakers cleaned up -290 gpm / 2310 psi -60 rpm / 5k ft/Ibs TO -Monitor well for 10 min, static 8.5 ppg in/out . 21:30 - 22:00 0.50 DRILL P PROD1 POH to Shoe -No problems pulling in open hole 22:00 - 23:30 1.50 DRILL P PROD1 , Drop Ball and open Circ. sub -CBU @ 400 gpm / 1560 psi -Obtain SPRs ' -Monitor well, static 8.5 ppg in/out PUW - 180k SOW - 150k RtWt - 155k 23:30 - 00:00 0.50 DRILL P PROD1 POH 8/21/2007 ' 00:00 - 03:30 3.50 DRILL P PROD1 POH to BHA 03:30 - 06:30 3.00 DRILL P PROD1 PJSM ;Removing RA source on surface with HES MWD and NAD rig Crews -Lay Down BHA to MWD -Remove Sources & Download Recorded Data - Flush Motor &MWD with Water -UD MWD/LWD, NM Stab, XO's, Motor & Bit -Clean and clear floor of third party tools 1 06:30 - 08:30 2.00 CASE P RUNPRD PJSM on Rigging up for Chrome Tubing -UD Bales and Pick up long Bales -Pick up Compensator and power tongs -R/U handling equipment and ready floor for running liner 08:30 - 10:30 2.00 CASE P RUNPRD PJSM on running Chrome Liner -M/U Float equipment, Baker-Lok all connection below Landing Collar -Run 21 jts 4-1/2" #12.6 13Cr-80 Vam-Top liner as per Running Order. -Top off every 5 Jts. -Dope With Jet Lube Seal Guard 10:30 - 11:30 1.00 CASE P RUNPRD R/D Handling equipment 11:30 - 12:00 0.50 CASE P RUNPRD Make up liner hanger, XO, and 1 stand of 4" DP. -Rig Down Power Tong and compensator 12:00 - 12:30 0.50 CASE P RUNPRD Circulate liner volume -PUW = 40k SOW = 40k -120 gpm / 120 psi 12:30 - 18:00 5.50 CASE P RUNPRD RIH on 4" HT40 Drill Pipe -Fill every 10 Stds 18:00 - 19:00 1.00 CASE P RUNPRD Circulate Bottoms up @ shoe Printed: 8/26/2007 1:34:31 PM BP EXPLORATION Page 13 of 15 ~ Operations Summary Report Legal Well Name: F-42 ',Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES ,r Date 18/21/2007 From - To I Hours Task ,Code I! NPT Phase Description of Operations __~_ 18:00 - 19:00 1.00. CASE P 19:00 - 19:30 0.50 CASE P 19:30 - 20:00 0.50 CEMT P 20:00 - 22:30 I 2.501 CEMT P 22:30 - 00:00 18/22/2007 100:00 - 01:00 01:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 00:00 8/23/2007 100:00 - 07:30 1.501 CEMT I P 1.001 CEMT ~ P 2.00 CEMT P 1.00 CEMT P 1.00 CASE P 9.50 CASE P 0.50 BOPSU P 1.00 CASE P -- - -- RUNPRD -Stage pumps up 5 bpm / 880 psi RUNPRD Run liner in open hole, no problems running in RUNPRD P/U Cement Head and Rig up Cement lines RUNPRD Circulate and Condition hole for cement job -Stage Pumps up to 5 bpm / 1080 psi -Conduct PJSM with Dowell Schlumberger, NAD Rig Crerws, Baker Tool Hand and BP WSL -Conduct PJSM with MI Mud Man, Pitwatcher and VECO truck Drivers RUNPRD Cement liner as follows: Pump 3 bbl water to cement head, test lines to 4000 psi, good test Pump 30 bbl MudPush II at 11.8 ppg. Mix and pump 27 bbl of 15.8 ppg class "G"w/GasBlok tail at 5 BPM. Pump 5 bbl water to clear lines through tee back to flow line Drop Plug, Kick out plug and displace with 12 bbls Seawater followed by 120 bbls.,8.5 ppg Flo-Pro mud. Slow down pump rate as requested by Baker hand while latching up dart to wiper plug. Bump plug to 3,500 psi CIP @ 23:53 hrs RUNPRD Set hanger or as directed by Baker rep. Slack off 56k to confirm hanger is set. Bleed pressure and check floats. Rotate 20 turns to release from the liner. Pressure up string to 1000, pick up slowly, seen pressure bleed off as pack-off was pulled from RS bushing. Immediately circulate 30 bbl up hole at 1 i bpm / 2460 psi. Slow pumps to 1.5 BPM, set weight down to set ZXP liner top packer Pick up and circulate out cement @ 11 bpm / 2450 psi, slowed to 6 bpm / 1100 psi when mud push and cement returned to surface. Total of 7 bbls of cement back to surface RUNPRD Flush Surface Lines and clean and Lay Down Cement head -Spot Trucks RUNPRD Displace to 8.4ppg Seawater @ 487 gpm / 2500 psi RUNPRD Slip & Cut Drilling Line -Service TDS and Draw Works RUNPRD Lay Down 4" Drill pipe -also Lay Down extra 11 stands from Derrick RUNPRD Pull Wear Bushing RUNPRD PJSM on testing casing -Held Test for~30~miri.~, record~on c~ -Good Test 2.00 BUNCO P RUNCMP PJSM on Rigging up to run Chrome Tubing and Run chrome pipe -Rig Up elevators, Slips, Compensator and Stack Tongs 6.00 BUNCO P RUNCMP Begin Running 243 jts of 4.5 Chrome 12.6# Cr-80 Vam Top Completion Tubing -1 Baker "S-3" Production Packer -5 GLM, 1 "XN" npple, 3 "X" nipple 7.50 BUNCO P RUNCMP Ran 4 1/2" completion as follows -4.5" WLEG 9CR Printed: 6/26/2007 1:34:31 PM BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Wetl Name: F-42 Common Well Name: F-42 Spud Date: 12/13/1990 Event Name: REENTER+COMPLETE Start: 8/4/2007 End: 8/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2007 Rig Name: NABOBS Rig Number: 2ES Date ', From - To ,Hours ! Task I Code i NPT Phase 8/23/2007 100:00 - 07:30 ~ 7.50 , RUNCOMP ~ RUNCMP 07:30 - 09:00 1.50 ~ RUNCOf~IP ~ RUNCMP 09:00 - 11:30 I 2.501 RUNCON~IP I I RUNCMP Description of Operations -4.5" TCII Tubing Pup -XN Nipple (3.813" bore) 4.5" 12.6# 13Cr-80 XO pup Vam Top box x TCII pin 1 jt (#1) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin Baker S-3 7"x 4.5" Packer TCII Box x Pin 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 1 jts (#2) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #1 4.5"x1.5" MMG 9Cr w/DV RK latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 17 jts (#3-19) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #2 4.5"x 1" MMG 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 28 jts (#20-47) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #3 4.5"x 1" MMG 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 47 jts (#48-94) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #4 4.5"x 1"MMG 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 47 jts (#95-158) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM # 4.5"x 1" MMG 9Cr w/ Shear & RKP 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 35 jts (#159-193} Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 49 jts (#194-242) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing Space Out PUPS 4.5" 12.6" 13Cr-80 Vam Top tubing 1 jts (#243) Jt 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin Cameron Tubing Hanger 13.625" x 4.5" TCII Box x Pin Space out TBG added 2.06 Pup Jt. -Btm TBG at 10451.47 -R/D Compensator and Elevators -M/U Landing Jt. and Hanger -Run in lock down screws R/U to reverse circ. pump seawater and spot corrosive inhibitor -Reverse 159 bbls of clean 8.5 Seawater, Followed with 128 bbls of Seawater treated with corrision inhibtor, spot in place with 67 bbls of Seawater -3 BPM Q 250 psi Printed: 8/26/2007 1:34:31 PM ~ ~ BP EXPLORATION Operations Summary Report Legal WeII Name: F-42 Common Well Name: F-42 Event Name: REENTER+COMPLETE 'Contractor Name: NABOBS ALASKA DRILLING I 'I Rig Name: NABOBS Date I From - To ' Hours Task ,Code -NPT 18/23/2007 111:30 - 13:30 I 2.00 13:30 - 14:30 I 1.001 BOPSUFI P 14:30 - 18:00 I 3.501 BOPSURX 18:00 - 19:30 1.50 BOPSUF~ P 19:30 - 22:00 2.50 W HSUR P 22:00 - 00:00 2.00 WHSUR ~ P 18/24/2007 100:00 - 03:00 I 3.001 WHSUR I P 03:00 - 04:00 1.00 WHSUR P 04:00 - 05:00 1.00 WHSUR P Start: 8/4/2007 Rig Release: 8/24/2007 Rig Number: 2ES Page 15 of 15 Spud Date: 12/13/1990 End: 8/24/2007 Phase Description of Operations RUNCMP Drop 1 7/8 ball and rod -PUW 135K SOW 108K -UD landing jt -Test tubin to 3500 si for 30 min. Good Test -Bleed off to 1500 psi ,Test Annulus to 3500 psi for 30 min. Good Test -Bleed down pressure to 0 -Pressure up on Annulus to 2490 psi, Shear DCK valve -Pump both ways to ensure shearing of DCK valve RUNCMP PJSM -Set TWC Test 1000 psi above & below Good Test -Blow down & R/D RUNCMP Remove all rams and hydraulic hoses from BOP in preparation for annual inspection RUNCMP PJSM, N/D BOP set on Stump RUNCMP PJSM, N/U adapter flange and tree -Test adaptor flange to 5000 psi, Good test -Test tree to 5000 psi, Good test, All tests done with diesel and charted RUNCMP PJSM with DSM and NAD rig crew on pulling TWC -R/U lubricator test to 500 psi, Good test -Pull TWC RUNCMP Rig up Little Red Services -Pressure test lines to 3500 psi -Pump 75 bbls of diesel @ 3bpm / 900 psi -Let U tube -Diesel spotted at 2200 ft TVD RUNCMP R/U DSM install BPV -Test from below for 1000 psi POST Secure Well -Remove secondary annulus valve -Prepare RDMO -Release Rig at 05:00 Printed: 8/26/2007 1:34:31 PM Halliburton Company Survey Report DEFINITIVE Company: BP Amoco Dater 9/10/2007 Time: 17:21:52 Pager 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: W ell: F-42, True N orth ~ Site: PBF Pad ' Vertical (TVD) Reference: F-42A: 67.1 ~ Well: F-42 Section (VS) Reference: W ell (O.OON,O.OOE ,316.66Azi) Wellpath: F-42A Survey Calculation iVlethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: F-42 Slot Name: F-42 Well Position: +N/-S 2342.53 ft Northing: 5974904. 09 ft Latitude: 70 20 18.320 N +E/-W 1735.10 ft Easting : 652648. 18 ft Longitude: 148 45 40.790 W Position Uncertainty: 0.00 ft Wellpath: F-42A Drilled From: F-42 50029221080100 Tie-on Depth: 6454.75 ft Current Datum: F-42A: Height 67. 06 ft Above System Datum: Mean Sea Level Magnetic Data: 8/8/2007 Declination: 23.63 deg Field Strength: 57653 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29 .95 0.00 0.00 316.66 Survey Program for Definitive Wellpath Date: 9/10/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 36.55 11313.25 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 6463.00 11312.65 F-42A IIFR+MS+Sag (6463 .00-113 MWD+IFR+MS MWD +IFR + Multi Station Survey -- - _ - MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 29.95 0.00 0.00 29.95 -37.11 0.00 0.00 5974904.09 652648.18 TIE LINE 36.55 0.40 229.47 36.55 -30.51 -0.01 -0.02 5974904.07 652648.16 GCT-MS 50.25 0.38 217.98 50.25 -16.81 -0.08 -0.08 5974904.00 652648.10 GCT-MS 63.95 0.37 212.73 63.95 -3.11 -0.15 -0.13 5974903.93 652648,05 GCT-MS 77.65 0.37 211.54 77.65 10.59 -0.23 -0.18 5974903.85 652648.01 GCT-MS 91.55 0.38 212.35 91.55 24.49 -0.31 -0.23 5974903.77 652647.96 GCT-MS 105.25 0.35 210.91 105.25 38.19 -0.38 -0.27 5974903.70 652647.92 GCT-MS 118.65 0.30 211.06 f 18.65 51.59 -0.45 -0.31 5974903.63 652647.88 GCT-MS 132.25 0.27 216.29 132.25 65.19 -0.50 -0.35 5974903.58 652647.84 GCT-MS 145.75 0.25 220.16 145.75 78.69 -0.55 -0.39 5974903.53 652647.80 GCT-MS 159.45 0.27 220.51 159.45 92.39 -0.60 -0.43 5974903.48 652647.77 GCT-MS 173.15 0.27 220.01 173.15 106.09 -0.65 -0.47 5974903.43 652647.72 GCT-MS 186.95 0.28 221.07 186.95 119.89 -0.70 -0.51 5974903.38 652647.68 GCT-MS 200.85 0.27 222.34 200.85 133.79 -0.75 -0.56 5974903.33 652647.64 GCT-MS 214.65 0.27 221.79 214.65 147.59 -0.80 -0.60 5974903.28 652647.60 GCT-MS 228.55 0.28 221.87 228.55 161.49 -0.85 -0.65 5974903.23 652647.55 GCT-MS 242.35 0.28 224.05 242.35 175.29 -0.90 -0.69 5974903.18 652647.51 GCT-MS 255.95 0.30 228.07 255.95 188.89 -0.94 -0.74 5974903.13 652647.46 GCT-MS 269.65 0.32 233.15 269.65 202.59 -0.99 -0.80 5974903.08 652647.40 GCT-MS 283.55 0.35 235.42 283.55 216.49 -1.04 -0.87 5974903.03 652647.34 GCT-MS 297.15 0.40 234.42 297.15 230.09 -1.09 -0.94 5974902.98 652647.27 GCT-MS 310.95 0.43 232.90 310.95 243.89 -1.15 -1.02 5974902.92 652647.19 GCT-MS ~ 325.25 0.47 232.16 325.25 258.19 -1.22 -1.11 5974902.85 652647.10 GCT-MS 338.95 0.50 231.32 338.94 271.88 -1.29 -1.20 5974902.77 652647.01 GCT-MS 352.85 0.52 231.01 352.84 285.78 -1.37 -1.30 5974902.69 652646.92 GCT-MS 366.85 0.53 228.64 366.84 299.78 -1.45 -1.39 5974902.61 652646.82 GCT-MS 380.65 0.52 223.03 380.64 313.58 -1.54 -1.48 5974902.52 652646.73 GCT-MS 394.35 0.48 217.83 394.34 327.28 -1.63 -1.56 5974902.43 652646.65 GCT-MS 407.65 0.48 216.33 407.64 340.58 -1.72 -1.63 5974902.34 652646.59 GCT-MS ~.~~~ ~~3 } t; • Halliburton Company Survey Report DEFINITIVE Company: BP Amoco - Date: 9ft0/2007 Time: 17:21:52 Page• 2 ~ FSeld: Prudhoe Bay Co-ordinate(NE) Re ference: W ell: F-42, True North Site: PB F Pad Vertical (TVD) Refe rence: F- 42A: 67.1 Well: F-42 Section (VS) Reference: W ell (O.OON,O.OOE ,316.66Azi) WeIIpath: F-42A -- Survey Calcula6onMethod: Mi nimum Curvature Db: Oracle Survey MD Intl ' Az6n TVD Sys TVD N/S E/W MapN MapE Tool ft, deg deg tt ft ft f< n ft J 421.65 0.48 217.16 421.64 354.58 -1.81 -1.70 5974902.24 652646.52 GCT-MS 435.75 0.45 218.75 435.74 368.68 -1.90 -1.77 5974902.15 652646.45 GCT-MS 449.05 0.43 220.50 449.04 381.98 -1.98 -1.83 5974902.07 652646.39 GCT-MS 463.45 0.42 220.86 463.44 396.38 -2.06 -1.90 5974901.99 652646.32 GCT-MS 477.45 0.42 221.87 477.44 410.38 -2.14 -1.97 5974901.91 652646.25 GCT-MS 490.85 0.42 224.04 490.84 423.78 -2.21 -2.04 5974901.84 652646.19 GCT-MS 504.55 0.42 225.81 504.54 437.48 -2.28 -2.11 5974901.76 652646.12 GCT-MS 518.15 0.43 226.33 518.14 451.08 -2.35 -2.18 5974901.69 652646.05 GCT-MS 531.95 0.43 226.30 531.94 464.88 -2.42 -2.26 5974901.62 652645.97 GCT-MS 545.55 0.43 227.11 545.54 478.48 -2.49 -2.33 5974901.55 652645.90 GCT-MS 559.45 0.43 227.92 559.44 492.38 -2.56 -2.41 5974901.48 652645.83 GCT-MS 573.35 0.43 227.56 573.34 506.28 -2.63 -2.49 5974901.40 652645.75 GCT-MS 587.25 0.43 227.93 587.24 520.18 -2.70 -2.56 5974901.33 652645.68 GCT-MS 600.75 0.45 231.54 600.74 533.68 -2.77 -2.64 5974901.26 652645.60 GCT-MS 614.15 0.48 235.10 614.14 547.08 -2.83 -2.73 5974901.20 652645.51 GCT-MS 627.45 0.50 236.09 627.44 560.38 -2.90 -2.82 5974901.13 652645.42 GCT-MS 640.75 0.50 238.18 640.73 573.67 -2.96 -2.92 5974901.07 652645.32 GCT-MS 654.15 0.50 239.23 654.13 587.07 -3.02 -3.02 5974901.00 652645.22 GCT-MS 667.55 0.50 239.07 667.53 600.47 -3.08 -3.12 5974900.94 652645.13 GCT-MS 681.05 0.50 239.40 681.03 613.97 -3.14 -3.22 5974900.88 652645.03 GCT-MS 694.25 0.50 238.49 694.23 627.17 -3.20 -3.32 5974900.82 652644.93 GCT-MS 707.65 0.52 236.55 707.63 640.57 -3.27 -3.42 5974900.75 652644.83 GCT-MS 721.55 0.50 236.45 721.53 654.47 -3.33 -3.52 5974900.68 652644.73 GCT-MS 735.05 0.48 237.42 735.03 667.97 -3.40 -3.62 5974900.62 652644.63 GCT-MS 748.25 0.48 236.23 748.23 681.17 -3.46 -3.71 5974900.55 652644.54 GCT-MS 762.55 0.48 234.97 762.53 695.47 -3.52 -3.81 5974900.48 652644.44 GCT-MS 776.15 0.48 234.33 776.13 709.07 -3.59 -3.91 5974900.42 652644.35 GCT-MS 789.65 0.48 233.62 789.63 722.57 -3.66 -4.00 5974900.35 652644.26 GCT-MS 803.75 0.45 233.50 803.73 736.67 -3.73 -4.09 5974900.28 652644.17 GCT-MS 817.35 0.43 233.63 817.33 750.27 -3.79 -4.17 5974900.21 652644.09 GCT-MS 831.05 0.45 233.11 831.03 763.97 -3.85 -4.26 5974900.15 652644.00 GCT-MS 844.45 0.45 230.93 844.43 777.37 -3.91 -4.34 5974900.08 652643.92 GCT-MS 857.95 0.42 227.02 857.93 790.87 -3.98 -4.42 5974900.01 652643.85 GCT-MS 871.35 0.32 227.92 871.33 804.27 -4.04 -4.48 5974899.96 652643.78 GCT-MS 885.15 0.22 237.90 885.13 818.07 -4.08 -4.53 5974899.91 652643.73 GCT-MS 899.05 0.20 242.48 899.03 831.97 -4.11 -4.58 5974899.89 652643.69 GCT-MS 913.05 0.23 241.82 913.03 845.97 -4.13 -4.62 5974899.86 652643.64 GCT-MS 924.95 0.27 245.09 924.93 857.87 -4.15 -4.67 5974899.84 652643.60 GCT-MS 936.55 0.27 242.87 936.53 869.47 -4.18 -4.72 5974899.81 652643.55 GCT-MS 948.05 0.22 242.01 948.03 880.97 -4.20 -4.76 5974899.79 652643.51 GCT-MS 960.05 0.15 256.38 960.03 892.97 -4.21 -4.80 5974899.77 652643.47 GCT-MS 970.95 0.08 285.70 970.93 903.87 -4.22 -4.82 5974899.77 652643.45 GCT-MS 980.05 0.05 299.93 980.03 912.97 -4.21 -4.83 5974899.78 652643.44 GCT-MS 989.15 0.03 315.14 989.13 922.07 -4.21 -4.83 5974899.78 652643.44 GCT-MS 998.25 0.05 336.24 998.23 931.17 -4.20 -4.84 5974899.79 652643.43 GCT-MS 1007.35 0.10 336.84 1007.33 940.27 -4.19 -4.84 5974899.80 652643.43 GCT-MS 1016.35 0.15 330.75 1016.33 949.27 -4.17 -4.85 5974899.81 652643.42 GCT-MS 1025.45 0.17 330.16 1025.43 958.37 -4.15 -4.86 5974899.84 652643.40 GCT-MS 1034.75 0.18 335.49. 1034.73 967.67 -4.13 -4.88 5974899.86 652643.39 GCT-MS 1044.05 0.20 346.93 1044.03 976.97 -4.10 -4.89 5974899.89 652643.38 GCT-MS 1053.25 0.23 4.09 1053.23 986.17 -4.06 -4.89 5974899.92 652643.38 GCT-MS ~ 1062.45 0.25 13.77 1062.43 995.37 -4.03 -4.88 5974899.96 652643.38 GCT-MS • Halliburton Company ~ I T I ~ Survey Report Company: BP Amoco Date: 9/10/2007 Time: 17:21:52 Page: 3 held: ' Prudhoe Bay tro-ordinate(NE) Reference: W ell: F-42, True North Site: PB F Pad Vertical (TVD) Refe rence: F- 42A: 67.1 Well: F-42 Section(VS) Reference: W ell (O.OON,O.OOE ,316.66Azi) ~ Wellpath: F-42A Survey Calculation Method: Mi nimum Curvatur e Db: Oracle Survey MD InCI Azim TVD Sys TVD N!S ` E!W MapN MapE Tool '~ ft ` deg deg ` ft' ft ft ft ft ft 1071.85 0.25 18.73 1071.83 1004.77 -3.99 -4.87 5974900.00 652643.39 GCT-MS 1080.85 0.27 25.68 1080.83 1013.77 -3.95 -4.85 5974900.04 652643.41 GCT-MS 1090.35 0.27 29.75 1090.33 1023.27 -3.91 -4.83 5974900.08 652643.43 GCT-MS 1099.65 0.28 33.30 1099.63 1032.57 -3.87 -4.81 5974900.12 652643.45 GCT-MS 1109.15 0.32 36.79 1109.13 1042.07 -3.83 -4.78 5974900.16 652643.48 GCT-MS 1120.45 0.37 37.46 1120.43 1053.37 -3.78 -4.74 5974900.21 652643.52 GCT-MS 1131.75 0.40 39.48 1131.73 1064.67 -3.72 -4.69 5974900.27 652643.57 GCT-MS 1143.15 0.40 43.08 1143.12 1076.06 -3.66 -4.64 5974900.33 652643.62 GCT-MS 1154.45 0.40 40.09 1154.42 1087.36 -3.60 -4.59 5974900.39 652643.67 GCT-MS 1165.85 0.38 30.55 1165.82 1098.76 -3.54 -4.54 5974900.46 652643.71 GCT-MS 1177.05 0.37 26.21 1177.02 1109.96 -3.47 -4.51 5974900.52 652643.74 GCT-MS 1188.35 0.40 28.48 1188.32 1121.26 -3.40 -4.47 5974900.59 652643.78 GCT-MS 1200.45 0.45 32.25 1200.42 1133.36 -3.33 -4.43 5974900.67 652643.82 GCT-MS 1212.05 0.47 34.76 1212.02 1144.96 -3.25 -4.38 5974900.75 652643.87 GCT-MS 1223.25 0.47 37.08 1223.22 1156.16 -3.17 -4.32 5974900.82 652643.92 GCT-MS 1234.65 0.45 39.51 1234.62 1167.56 -3.10 -4.27 5974900.90 652643.98 GCT-MS 1246.35 0.43 46.79 1246.32 1179.26 -3.04 -4.21 5974900.96 652644.04 GCT-MS 1257.55 0.45 56.67 1257.52 1190.46 -2.98 -4.14 5974901.02 652644.11 GCT-MS 1268.75 0.47 59.19 1268.72 1201.66 -2.94 -4.06 5974901.07 652644.18 GCT-MS 1280.15 0.47 58.78 1280.12 1213.06 -2.89 -3.98 5974901.12 652644.26 GCT-MS 1291.65 0.50 60.78 1291.62 1224.56 -2.84 -3.90 5974901.17 652644.34 GCT-MS 1303.25 0.53 60.05 1303.22 1236.16 -2.79 -3.81 5974901.22 652644.43 GCT-MS 1314.85 0.55 57.26 1314.82 1247.76 -2.73 -3.71 5974901.28 652644.52 GCT-MS 1325.95 0.58 63.76 1325.92 1258.86 -2.68 -3.62 5974901.34 652644.62 GCT-MS 1337.65 0.60 73.51 1337.62 1270.56 -2.63 -3.51 5974901.38 652644.73 GCT-MS 1349.35 0.60 76.72 1349.32 1282.26 -2.60 -3.39 5974901.42 652644.85 GCT-MS 1360.95 0.62 77.31 1360.92 1293.86 -2.57 -3.27 5974901.45 652644.97 GCT-MS 1372.85 0.63 76.96 1372.82 1305.76 -2.55 -3.14 5974901.48 652645.09 GCT-MS 1384.25 0.65 77.34 1384.22 1317.16 -2.52 -3.02 5974901.51 652645.22 GCT-MS 1395.65 0.63 77.30 1395.61 1328.55 -2.49 -2.89 5974901.54 652645.34 GCT-MS 1406.95 0.65 76.79 1406.91 1339.85 -2.46 -2.77 5974901.57 652645.46 GCT-MS 1418.15 0.65 76.80 1418.11 1351.05 -2.43 -2.65 5974901.60 652645.59 GCT-MS 1429.45 0.65 77.74 1429.41 1362.35 -2.40 -2.52 5974901.63 652645.71 GCT-MS 1440.65 0.65 78.01 1440.61 1373.55 -2.38 -2.40 5974901.66 652645.83 GCT-MS 1451.75 0.63 77.46 1451.71 1384.65 -2.35 -2.28 5974901.69 652645.95 GCT-MS 1463.15 0.60 80.68 1463.11 1396.05 -2.33 -2.16 5974901.71 652646.07 GCT-MS 1474.55 0.58 85.60 1474.51 1407.45 -2.31 -2.04 5974901.73 652646.19 GCT-MS 1485.65 0.58 85.57 1485.61 1418.55 -2.30 -1.93 5974901.74 652646.30 GCT-MS 1496.75 0.55 85.42 1496.71 1429.65 -2.30 -1.82 5974901.75 652646.41 GCT-MS 1507.95 0.53 88.16 1507.91 1440.85 -2.29 -1.71 5974901.76 652646.52 GCT-MS 1519.65 0.52 89.14 1519.61 1452.55 -2.29 -1.61 5974901.77 652646.62 GCT-MS 1530.75 0.50 88.24 1530.71 1463.65 -2.29 -1.51 5974901.77 652646.72 GCT-MS 1542.05 0.45 87.91 1542.01 1474.95 -2.28 -1.41 5974901.78 652646.82 GCT-MS 1551.05 0.43 88.46 1551.01 1483.95 -2.28 -1.34 5974901.78 652646.88 GCT-MS 1559.55 0.40 96.13 1559.51 1492.45 -2.28 -1.28 5974901.78 652646.95 GCT-MS 1568.35 0.42 109.01 1568.31 1501.25 -2.30 -1.22 5974901.77 652647.01 GCT-MS 1576.95 0.47 113.78 1576.91 1509.85 -2.32 -1.16 5974901.74 652647.07 GCT-MS 1585.55 0.47 113.04 1585.51 1518.45 -2.35 -1.09 5974901.72 652647.14 GCT-MS 1593.95 0.50 112.13 1593.91 1526.85 -2.38 -1.03 5974901.69 652647.20 GCT-MS 1602.15 0.52 111.60 1602.11 1535.05 -2.40 -0.96 5974901.66 652647.27 GCT-MS 1610.55 0.52 111.74 1610.50 1543.44 -2.43 -0.89 5974901.64 652647.34 GCT-MS 1619.25 0.53 110.59 1619.20 1552.14 -2.46 -0.82 5974901.61 652647.42 GCT-MS 1629.35 0.53 107.99 1629.30 1562.24 -2.49 -0.73 5974901.58 652647.50 GCT-MS • Halliburton Company ®~ I I T I V E Survey Report Company: BP Amocq Date: 9/10/2007 Timer 17:21:52 Page: 4 Field:. Prudhoe Bay Co-ordinate(NE) Reference: W ell: F-42, True North Site: PB F Pad Vertical (TVD) Refe rence: F- 42A: 67.1 Well: F-42' Section (VS) Reference: W ell (O.OON,O.OOE,316.66Azi) Wellpath: F-42A Survey Calculation,Method: Mi nimum Curvature Db: Oracle Survey MD Incl Aztn TVD Sys TVD N/S' E/W MapN MapE Tool ft deg;`.. deg ft` ft ft ft ft ft 1639.15 0.53 105.20 1639.10 1572.04 -2.52 -0.64 5974901.56 652647.59 GCT-MS 1649.15 0.50 101.37 1649.10 1582.04 -2.54 -0.55 5974901.54 652647.68 GCT-MS 1659.05 0.42 97.30 1659.00 1591.94 -2.55 -0.48 5974901.53 652647.76 GCT-MS 1668.75 0.32 106.86 1668.70 1601.64 -2.56 -0.41 5974901.51 652647.82 GCT-MS 1678.55 0.30 123.03 1678.50 1611.44 -2.58 -0.37 5974901.49 652647.87 GCT-MS 1688.35 0.33 128.26 1688.30 1621.24 -2.62 -0.32 5974901.46 652647.91 GCT-MS 1698.75 0.37 128.83 1698.70 1631.64 -2.66 -0.27 5974901.42 652647.96 GCT-MS 1708.75 0.37 128.72 1708.70 1641.64 -2.70 -0.22 5974901.39 652648.01 GCT-MS 1718.75 0.38 128.80 1718.70 1651.64 -2.74 -0.17 5974901.35 652648.07 GCT-MS 1728.55 0.37 128.79 1728.50 1661.44 -2.78 -0.12 5974901.31 652648.12 GCT-MS 1739.05 0.33 130.49 1739.00 1671.94 -2.82 -0.07 5974901.27 652648.17 GCT-MS 1748.95 0.30 131.69 1748.90 1681.84 -2.85 -0.03 5974901.23 652648.21 GCT-MS 1759.15 0.30 127.38 1759.10 1692.04 -2.89 0.01 5974901.20 652648.25 GCT-MS 1768.85 0.30 120.35 1768.80 1701.74 -2.92 0.05 5974901.17 652648.29 GCT-MS 1778.75 0.28 115.65 1778.70 1711.64 -2.94 0.10 5974901.15 652648.34 GCT-MS 1788.35 0.25 109.04 1788.30 1721.24 -2.96 0.14 5974901.13 652648.38 GCT-MS 1798.25 0.22 124.21 1798.20 1731.14 -2.97 0.17 5974901.12 652648.42 GCT-MS 1808.35 0.20 150.18 1808.30 1741.24 -3.00 0.20 5974901.09 652648.44 GCT-MS 1818.25 0.22 154.90 1818.20 1751.14 -3.03 0.21 5974901.06 652648.46 GCT-MS 1828.25 0.23 152.58 1828.20 1761.14 -3.07 0.23 5974901.02 652648.48 GCT-MS 1838.35 0.23 145.76 1838.30 1771.24 -3.10 0.25 5974900.99 652648.50 GCT-MS 1848.15 0.25 138.48 1848.10 1781.04 -3.14 0.28 5974900.96 652648.52 GCT-MS 1857.95 0.25 131.45 1857.90 1790.84 -3.17 0.31 5974900.93 652648.55 GCT-MS 1867.85 0.23 122.96 1867.80 1800.74 -3.19 0.34 5974900.90 652648.59 GCT-MS 1877.65 0.15 119.57 1877.60 1810.54 -3.21 0.37 5974900.89 652648.62 GCT-MS 1887.65 0.10 146.29 1887.60 1820.54 -3.22 0.38 5974900.87 652648.63 GCT-MS 1897.55 0.13 172.39 1897.50 1830.44 -3.24 0.39 5974900.85 652648.64 GCT-MS 1907.45 0.17 171.07 1907.40 1840.34 -3.27 0.39 5974900.83 652648.64 GCT-MS 1917.35 0.20 164.99 1917.30 1850.24 -3.30 0.40 5974900.80 652648.65 GCT-MS 1927.15 0.22 154.47 1927.10 1860.04 -3.33 0.41 5974900.76 652648.66 GCT-MS 1937.05 0.20 137.02 1937.00 1869.94 -3.36 0.43 5974900.74 652648.68 GCT-MS 1946.75 0.15 128.29 1946.70 1879.64 -3.38 0.46 5974900.72 652648.71 GCT-MS 1956.35 0.12 121.56 1956.30 1889.24 -3.39 0.47 5974900.70 652648.72 GCT-MS 1966.15. 0.07 88.89 1966.10 1899.04 -3.40 0.49 5974900.70 652648.74 GCT-MS 1975.95 0.03 74.64 1975.90 1908.84 -3.40 0.50 5974900.70 652648.75 GCT-MS 1985.95 0.02 16.22 1985.90 1918.84 -3.40 0.50 5974900.70 652648.75 GCT-MS 1996.25 0.00 3.39 1996.20 1929.14 -3.39 0.50 5974900.70 652648.75 GCT-MS 2005.95 0.00 41.92 2005.90 1938.84 -3.39 0.50 5974900.70 652648.75 GCT-MS 2015.75 0.08 359.15 2015.70 1948.64 -3.39 0.50 5974900.71 652648.75 GCT-MS 2025.35 0.20 339.29 2025.30 1958.24 -3.36 0.49 5974900.73 652648.74 GCT-MS 2033.35 0.25 344.39 2033.30 1966.24 -3.33 0.48 5974900.76 652648.73 GCT-MS 2041.15 0.28 342.37 2041.10 1974.04 -3.30 0.47 5974900.80 652648.72 GCT-MS 2049.15 0.32 341.87 2049.10 1982.04 -3.26 0.46 5974900.84 652648.71 GCT-MS 2057.05 0.33 340.37 2057.00 1989.94 -3.22 0.45 5974900.88 652648.69 GCT-MS 2065.25 0.35 335.88 2065.20 1998.14 -3.17 0.43 5974900.92 652648.68 GCT-MS 2073.15 0.37 331.62 2073.10 2006.04 -3.13 0.41 5974900.97 652648.65 GCT-MS 2080.85 0.35 329.22 2080.80 2013.74 -3.09 0.38 5974901.01 652648.63 GCT-MS 2088.75 0.35 325.43 2088.70 2021.64 -3.05 0.36 5974901.05 652648.60 GCT-MS 2096.75 0.30 319.35 2096.70 2029.64 -3.01 0.33 5974901.08 652648.57 GCT-MS 2104.85 0.27 313.47 2104.80 2037.74 -2.98 0.30 5974901.11 652648.54 GCT-MS 2112.75 0.27 304.23 2112.70 2045.64 -2.96 0.27 5974901.14 652648.52 GCT-MS 2120.65 0.28 297.10 2120.60 2053.54 -2.94 0.24 5974901.15 652648.48 GCT-MS s • Halliburton Company ®E i ~ ~ i E Survey Report Company: -- BP Amoco ----- Dater 9/10/2007 Time: 17:21:52 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: F-42, True North Site: PB F Pad Vertical (TVD) Reference: F-42A: 67.1 -Well: F-42 Section(VS) Reference: Well (O.OON,O.OOE,316.66Azi) `Wellpath: F-42A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD f< Inct deg Azim _deg 2128.45 0.32 299.09 2136.55 0.33 304.28 2149.35 0.33 308.68 2163.15 0.33 305.98 2177.15 0.32 295.77 2191.15 0.27 299.22 2204.95 0.27 319.04 2217.15 0.30 324.44 2226.55 0.30 311.24 2236.05 0.28 301.12 2246.25 0.27 304.83 2259.25 0.28 309.76 2272.05 0.28 310.38 2284.85 0.25 312.41 2297.95 0.23 309.20 2310.85 0.25 297.96 2323.55 0.27 296.37 2336.75 0.27 300.32 2349.75 0.27 292.92 2362.75 0.23 292.23 2375.15 0.25 292.39 2387.95 0.28 285.93 2400.95 0.23 280.91 2413.75 0.22 286.40 2426.15 0.27 289.59 2438.95 0.25 276.76 2451.75 0.20 275.52 2464.35 0.20 290.71 2476.95 0.27 293.27 2489.75 0.28 276.65 2502.35 0.22 276.38 2515.25 0.20 293.78 2528.45 0.27 298.07 2541.55 0.28 288.49 2554.55 0.28 285.56 2567.25 0.28 291.25 2580.05 0.25 290.80 2593.05 0.23 280.40 2606.25 0.27 276.09 2618.95 0.30 282.67 2631.95 0.30 290.37 2644.85 0.28 293.86 2657.75 0.30 293.70 2670.75 0.30 288.36 2683.45 0.33 279.70 2697.15 0.40 275.50 2711.35 0.53 275.89 2725.15 0.68 275.57 2738.65 0.80 275.60 2752.25 0.85 275.06 2765.85 0.85 273.87 2779.55 0.83 273.98 2793.65 0.85 274.36 TVD sy5 TVD it- n, 2128.40 2061.34 2136.50 2069.44 2149.30 2082.24 2163.10 2096.04 2177.10 2110.04 2191.10 2124.04 2204.90 2137.84 2217.10 2150.04 2226.50 2159.44 2236.00 2168.94 2246.20 2179.14 2259.20 2192.14 2272.00 2204.94 2284.80 2217.74 2297.90 2230.84 2310.80 2243.74 2323.50 2256.44 2336.70 2269.64 2349.70 2282.64 2362.70 2295.64 2375.10 2308.04 2387.90 2320.84 2400.89 2333.83 2413.69 2346.63 2426.09 2359.03 2438.89 2371.83 2451.69 2384.63 2464.29 2397.23 2476.89 2409.83 2489.69 2422.63 2502.29 2435.23 2515.19 2448.13 2528.39 2461.33 2541.49 2474.43 2554.49 2487.43 2567.19 2500.13 2579.99 2512.93 2592.99 2525.93 2606.19 2539.13 2618.89 2551.83 2631.89 2564.83 2644.79 2577.73 2657.69 2590.63 2670.69 2603.63 2683.39 2616.33 2697.09 2630.03 2711.29 2644.23 2725.09 2658.03 2738.59 2671.53 2752.19 2685.13 2765.79 2698.73 2779.48 2712.42 2793.58 2726.52 _ __ N!S E!1'i' ft ft -2.92 0.20 -2.89 0.17 -2.85 0.11 -2.80 0.04 -2.76 -0.02 -2.73 -0.09 -2.69 -0.14 -2.64 -0.18 -2.60 -0.21 -2.58 -0.25 -2.55 -0.29 -2.51 -0.34 -2.47 -0.39 -2.43 -0.43 -2.40 -0.47 -2.37 -0.52 -2.34 -0.57 -2.31 -0.62 -2.28 -0.68 -2.26 -0.73 -2.24 -0.78 -2.22 -0.83 -2.21 -0.89 -2.20 -0.94 -2.18 -0.99 -2.17 -1.05 -2.16 -1.10 -2.15 -1.14 -2.13 -1.19 -2.12 -1.24 -2.11 -1.30 -2.10 -1.34 -2.07 -1.39 -2.05 -1.45 -2.03 -1.51 -2.01 -1.57 -1.99 -1.62 -1.98 -1.68 -1.97 -1.73 -1.96 -1.80 -1.94 -1.86 -1.91 -1.92 -1.89 -1.98 -1.86 -2.05 -1.85 -2.11 -1.83 -2.20 -1.82 -2.31 -1.81 -2.46 -1.79 -2.63 -1.77 -2.83 -1.76 -3.03 -1.74 -3.23 -1.73 -3.43 i11apN MapE Tool ft ft 5974901.17 652648.45 GCT-MS 5974901.20 652648.41 GCT-MS 5974901.24 652648.35 GCT-MS 5974901.29 652648.28 GCT-MS 5974901.32 652648.21 GCT-MS 5974901.36 652648.15 GCT-MS 5974901.40 652648.10 GCT-MS 5974901.44 652648.06 GCT-MS 5974901.48 652648.03 GCT-MS 5974901.51 652647.99 GCT-MS 5974901.53 652647.95 GCT-MS 5974901.57 652647.90 GCT-MS 5974901.61 652647.85 GCT-MS 5974901.65 652647.80 GCT-MS 5974901.68 652647.76 GCT-MS 5974901.71 652647.71 GCT-MS 5974901.73 652647.66 GCT-MS 5974901.76 652647.61 GCT-MS 5974901.79 652647.55 GCT-MS 5974901.81 652647.50 GCT-MS 5974901.83 652647.45 GCT-MS 5974901.85 652647.39 GCT-MS 5974901.86 652647.34 GCT-MS 5974901.87 652647.29 GCT-MS 5974901.89 652647.24 GCT-MS 5974901.90 652647.18 GGT-MS 5974901.90 652647.13 GCT-MS 5974901.91 652647.09 GCT-MS 5974901.93 652647.04 GCT-MS 5974901.94 652646.98 GCT-MS 5974901.95 652646.93 GCT-MS 5974901.96 652646.88 GCT-MS 5974901.98 652646.83 GCT-MS 5974902.01 652646.77 GCT-MS 5974902.02 652646.71 GCT-MS 5974902.04 652646.65 GCT-MS 5974902.06 652646.60 GCT-MS 5974902.08 652646.55 GCT-MS 5974902.08 652646.49 GCT-MS 5974902.09 652646.43 GCT-MS 5974902.11 652646.36 GCT-MS 5974902.13 652646.30 GCT-MS 5974902.16 652646.24 GCT-MS 5974902.18 652646.18 GCT-MS 5974902.20 652646.11 GCT-MS 5974902.21 652646.02 GCT-MS 5974902.22 652645.91 GCT-MS 5974902.23 652645.76 GCT-MS 5974902.24 652645.59 GCT-MS 5974902.25 652645.39 GCT-MS 5974902.27 652645.19 GCT-MS 5974902.28 652644.99 GCT-MS 5974902.29 652644.78 GCT-MS .. e • Halliburton Company Survey Report • DEFINITIVE Company: BP Amoco Date: 9/10!2007 Time: 17 :21:52 Page: 6 Field: Pru dhoe Bay Co-ord inete(NE) Reference: Well: F-42, True No rth Site: ' PB Well: F-4 F Pad 2 Vertica Section l (TVD) Reference: F-42A: 67.1 (VS) Reference: Web (O.OON,O.OOE,316.66Azi) Wellpath:' F-42A Survey Calculation Method: Minim um Curvature Db: Oracle Survey MD Inc! Azim TVDrr Sys TVD N/S E/W MapN MapE Tool ft deg deg,.. ft, ft ft ft ft ft ~ 2807.35 0.87 275.70 2807.28 2740.22 -1.71 -3.64 5974902.30 652644.58 GCT-MS 2820.75 0.93 282.05 2820.68 2753.62 -1.68 -3.85 5974902.33 652644.37 GCT-MS ~ 2834.15 1.12 294.26 2834.08 2767.02 -1.60 -4.07 5974902.40 652644.14 GCT-MS 2847.55 1.38 305.21 2847.47 2780.41 -1.46 -4.32 5974902.54 652643.89 GCT-MS 2861.25 1.65 312.49 2861.17 2794.11 -1.23 -4.60 5974902.77 652643.60 GCT-MS 2874.75 1.95 318.10 2874.66 2807.60 -0.92 -4.90 5974903.06 652643.30 GCT-MS 2888.85 2.17 321.55 2888.75 2821.69 -0.54 -5.23 5974903.44 652642.97 GCT-MS 2902.75 2.27 323.18 2902.64 2835.58 -0.11 -5.56 5974903.86 652642.63 GCT-MS 2916.75 2.33 324.20 2916.63 2849.57 0.34 -5.89 5974904.31 652642.29 GCT-MS 2930.65 2.35 325.55 2930.52 2863.46 0.81 -6.22 5974904.77 652641.95 GCT-MS 2944.55 2.38 327.36 2944.41 2877.35 1.28 -6.53 5974905.24 652641.63 GCT-MS 2958.15 2.40 329.11 2958.00 2890.94 1.77 -6.83 5974905.71 652641.32 GCT-MS 2971.85 2.45 330.52 2971.69 2904.63 2.27 -7.12 5974906.21 652641.02 GCT-MS 2985.35 2.48 331.23 2985.17 2918.11 2.78 -7.40 5974906.71 652640.72 GCT-MS 2999.05 2.52 331.64 2998.86 2931.80 3.30 -7.69 5974907.23 652640.43 GCT-MS 3012.85 2.55 332.13 3012.65 2945.59 3.84 -7.98 5974907.76 652640.13 GCT-MS 3026.55 2.58 332.56 3026.33 2959.27 4.38 -8.26 5974908.30 652639.83 GCT-MS 3039.95 2.57 333.85 3039.72 2972.66 4.92 -8.53 5974908.83 652639.55 GCT-MS 3053.55 2.57 335.87 3053.31 2986.25 5.47 -8.79 5974909.38 652639.28 GCT-MS 3067.05 2.62 337.43 3066.79 2999.73 6.03 -9.04 5974909.93 652639.03 GCT-MS 3080.75 2.67 338.17 3080.48 3013.42 6.62 -9.27 5974910.51 652638.78 GCT-MS 3094.15 2.68 338.05 3093.86 3026.80 7.20 -9.51 5974911.09 652638.53 GCT-MS 3107.55 2.75 339.00 3107.25 3040.19 7.79 -9.74 5974911.67 652638.29 GCT-MS 3121.05 2.98 341.24 3120.73 3053.67 8.42 -9.97 5974912.30 652638.05 GCT-MS 3134.15 3.28 342.01 3133.81 3066.75 9.10 -10.19 5974912.98 652637.81 GCT-MS 3147.55 3.67 342.41 3147.19 3080.13 9.87 -10.44 5974913.75 652637.54 GCT-MS 3160.95 4.15 343.67 3160.55 3093.49 10.75 -10.71 5974914.61 652637.26 GCT-MS 3174.75 4.57 344.60 3174.31 3107.25 11.76 -10.99 ~ 5974915.62 652636.95 GCT-MS 3188.25 4.82 345.17 3187.77 3120.71 12.83 -11.28 5974916.68 652636.64 GCT-MS 3201.65 4.93 345.46 3201.12 3134.06 13.93 -11.57 5974917.77 652636.33 GCT-MS 3215.25 5.08 345.76 3214.67 3147.61 15.08 -11.87 5974918.92 652636.01 GCT-MS 3228.75 5.28 346.16 3228.11 3161.05 16.26 -12.16 5974920.09 652635.69 GCT-MS 3242.25 5.65 346.80 3241.55 3174.49 17.51 -12.46 5974921.34 652635.37 GCT-MS 3255.65 6.10 347.76 3254.88 3187.82 18.85 -12.76 5974922.67 652635.04 GCT-MS 3268.95 6.60 348.65 3268.10 3201.04 20.29 -13.06 5974924.10 652634.71 GCT-MS 3282.35 7.32 349.39 3281.40 3214.34 21.88 -13.37 5974925.69 652634.37 GCT-MS 3295.75 8.18 349.90 3294.68 3227.62 23.66 -13.70 5974927.46 652634.01 GCT-MS 3308.95 8.98 350.04 3307.73 3240.67 25.60 -14.04 5974929.39 652633.63 GCT-MS 3322.35 9.68 349.93 3320.95 3253.89 27.74 -14.42 5974931.52 652633.20 GCT-MS 3335.75 10.20 349.87 3334.15 3267.09 30.01 -14.82 5974933.79 652632.75 GCT-MS 3349.05 10.43 349.91 3347.24 3280.18 32.36 -15.24 5974936.12 652632.29 GCT-MS 3362.85 10.52 349.89 3360.81 3293.75 34.83 -15.68 5974938.59 652631.80 GCT-MS 3390.65 10.72 349.76 3388.13 3321.07 39.87 -16.59 5974943.61 652630.79 GCT-MS 3421.95 11.08 349.08 3418.87 3351.81 45.69 -17.67 5974949.40 652629.58 GCT-MS 3453.25 11.48 348.34 3449.56 3382.50 51.69 -18.87 5974955.38 652628.26 GCT-MS 3484.25 11.83 347.93 3479.92 3412.86 57.82 -20.16 5974961.48 652626.85 GCT-MS 3515.65 12.42 347.92 3510.62 3443.56 64.27 -21.54 5974967.90 652625.34 GCT-MS 3547.05 13.07 348.34 3541.25 3474.19 71.05 -22.96 5974974.65 652623.78 GCT-MS 3577.95 13.57 348.61 3571.32 3504.26 78.03 -24.39 5974981.59 652622.21 GCT-MS 3608.55 14.43 348.36 3601.01 3533.95 85.28 -25.86 5974988.81 652620.59 GCT-MS 3639.85 15.87 348.05 3631.22 3564.16 93.29 -27.54 5974996.78 652618.75 GCT-MS 3670.75 17.40 348.01 3660.83 3593.77 101.94 -29.37 5975005.40 652616.74 GCT-MS • • Halliburton Company Survey Report Company: BP AtnoCO Date: 911'0!2007 Time: 17: 21:52 Page: 7 Wield:, Pru dhoe Bay Co-ordinate(N'E) Reference: Well: F-42, True N orth Site: PB F Pad Vertical (TVD) Refe rence: F-42A : 67.1 WeU: F-42` Sectioa {VS) Reference: Well ( O.OON,O.OOE ,316.66Azi) Weltpath: F-42A: Survey Calculation Method: Minim um Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S E!W MapN MapE Tool fY 3702.15 deg 18.83 deg 348.16 ft 3690.67 ft 3623.61 ft ' 111.49 ft -31.39 ft 5975014.91 ft 652614.53 GCT-MS 3734.55 19.70 348.39 3721.25 3654.19 121.96 -33.56 5975025.33 652612.15 GCT-MS 3766.05 20.17 348.50 3750.87 3683.81 132.48 -35.71 5975035.80 652609.78 GCT-MS 3797.25 21.02 348.38 3780.07 3713.01 143.23 -37.91 5975046.51 652607.37 GCT-MS 3827.95 22.08 348.26 3808.63 3741.57 154.28 -40.19 5975057.50 652604.86 GCT-MS 3859.45 22.95 348.42 3837.72 3770.66 166.09 -42.63 5975069.26 652602.18 GCT-MS 3890.95 23.88 348.74 3866.63 3799.57 178.36 -45.11 5975081.48 652599.46 GCT-MS 3922.25 25.22 349.30 3895.10 3828.04 191.13 -47.58 5975094.19 652596.72 GCT-MS 3953.15 26.40 349.82 3922.92 3855.86 204.36 -50.02 5975107.37 652594.02 GCT-MS 3984.05 27.47 350.15 3950.46 3883.40 218.14 -52.45 5975121.10 652591.30 GCT-MS 4015.15 28.88 350.48 3977.88 3910.82 232.61 -54.92 5975135.52 652588.54 GCT-MS 4046.45 30.28 350.86 4005.10 3938.04 247.86 -57.43 5975150.71 652585.73 GCT-MS 4077.05 31.30 351.22 4031.39 3964.33 263.33 -59.87 5975166.13 652582.97 GCT-MS 4108.35 32.12 351.49 4058.01 3990.95 279.60 -62.34 5975182.34 652580.17 GCT-MS 4141.05 32.98 351.69 4085.58 4018.52 297.00 -64.91 5975199.68 652577.24 GCT-MS 4171.45 33.85 351.69 4110.95 4043.89 313.57 -67.33 5975216.20 652574.49 GCT-MS 4202.75 34.97 351.57 4136.77 4069.71 331.07 -69.91 5975233.64 652571.56 GCT-MS 4233.25 35.87 351.49 4161.63 4094.57 348.55 -72.51 5975251.06 652568.60 GCT-MS 4264.15 36.48 351.50 4186.57 4119.51 366.59 -75.21 5975269.04 652565.53 GCT-MS 4296.25 37.08 351.64 4212.28 4145.22 385.60 -78.02 5975287.99 652562.33 GCT-MS 4327.95 37.70 351.80 4237.47 4170.41 404.65 -80.80 5975306.98 652559.17 GCT-MS 4359.45 38.40 351.89 4262.27 4195.21 423.87 -83.55 5975326.13 652556.03 GCT-MS 4390.15 39.38 351.95 4286.17 4219.11 442.95 -86.26 5975345.16 652552.93 GCT-MS 4421.25 40.72 351.87 4309.97 4242.91 462.76 -89.07 5975364.91 652549.71 GCT-MS 4452.75 42.15 351.55 4333.59 4266.53 483.39 -92.08 5975385.47 652546.29 GCT-MS 4484.45 43.37 351.20 4356.86 4289.80 504.67 -95.31 5975406.67 652542.63 GCT-MS 4515.55 44.27 350.83 4379.30 4312.24 525.94 -98.67 5975427.87 652538.83 GCT-MS 4547.15 45.18 350.02 4401.75 4334.69 547.86 -102.37 5975449.71 652534.69 GCT-MS 4578.45 46.10 348.59 4423.64 4356.58 569.85 -106.53 5975471.61 652530.08 GCT-MS 4609.05 46.75 347.47 4444.73 4377.67 591.54 -111.13 5975493.19 652525.04 GCT-MS 4639.55 47.17 347.21 4465.55 4398.49 613.29 -116.01 5975514.84 652519.72 GCT-MS 4670.45 47.57 347.25 4486.47 4419.41 635.46 -121.04 5975536.90 652514.24 GCT-MS 4701.35 47.88 347.37 4507.26 4440.20 657.76 -126.06 5975559.10 652508.77 GCT-MS 4732.25 48.07 347.55 4527.95 4460.89 680.17 -131.04 5975581.40 652503.33 GCT-MS 4763.55 48.25 347.72 4548.83 4481.77 702.95 -136.04 5975604.07 652497.87 GCT-MS 4794.85 48.42 347.84 4569.63 4502.57 725.80 -140.99 5975626.81 652492.46 GCT-MS 4825.25 48.53 347.88 4589.79 4522.73 748.05 -145.77 5975648.96 652487.22 GCT-MS 4856.85 48.57 347.73 4610.70 4543.64 771.20 -150.78 5975672.00 652481.75 GCT-MS 4888.75 48.40 347.09 4631.85 4564.79 794.51 -155.98 5975695.20 652476.07 GCT-MS j 4919.05 48.22 346.35 4652.00 4584.94 816.54 -161.18 5975717.11 652470.43 GCT-MS 4949.55 48.18 345.96 4672.33 4605.27 838.61 -166.62 5975739.07 652464.54 GCT-MS 4979.75 48.18 345.89 4692.47 4625.41 860.44 -172.09 5975760.78 652458.62 GCT-MS 5009.95 48.22 346.00 4712.60 4645.54 882.28 -177.56 5975782.51 652452.71 GCT-MS 5040.45 48.20 346.12 4732.92 4665.86 904.35 -183.04 5975804.46 652446.78 GCT-MS 5072.15 48.17 346.28 4754.06 4687.00 927.30 -188.68 5975827.28 652440.68 GCT-MS 5102.45 48.18 346.45 4774.26 4707.20 949.24 -194.00 5975849.11 652434.92 GCT-MS 5133.75 48.20 346.61 4795.13 4728.07 971.93 -199.43 5975871.68 652429.02 GCT-MS 5164.95 48.20 346.72 4815.93 4748.87 994.56 -204.80 5975894.20 652423.20 GCT-MS 5196.05 48.20 346.77 4836.65 4769.59 1017.13 -210.11 5975916.65 652417.42 GCT-MS 5226.85 48.27 346.80 4857.17 4790.11 1039.49 -215.36 5975938.90 652411.72 GCT-MS 5258.25 48.42 346.77 4878.04 4810.98 1062.33 -220.73 5975961.62 652405.89 GCT-MS 5289.55 48.37 346.65 4898.82 4831.76 1085.11 -226.11 5975984.29 652400.05 GCT-MS j 5319.65 48.02 346.44 4918.89 4851.83 1106.93 -231.33 5976006.00 652394.39 GCT-MS Halliburton Company Survey Report • - CI ompany: BP ~ d P AmoCO dh B Date: 9/10/2007 Time: 17:21:52 Page: 8 Fiel : ru oe ay -Co-ord inate(NE) Re ference: W ell: F-42, True N orth i Site: PB F Pad Vertica l (TVD) Reference: F- 42A: 67.1 i Well: F-42 Section (VS) Reference: W ell (O.OON,O.OOE,316.66Azi) Weltpath: F-42A Survey Calculation'Method: Minimum Curvature Db: Oracle --- - Survey MI) Incl Azim TVD Sys TVD N/S' F./VV MapN MapE Tool ft deg , deg ft ft ft it ft ft 5350.05 47.48 346.08 4939.33 4872.27 1128.79 -236.67 5976027.74 652388.60 GCT-MS 5380.65 47.18 345.82 4960.07 4893.01 1150.61 -242.13 5976049.45 652382.69 GCT-MS 5410.45 47.28 345.87 4980.30 4913.24 1171.83 -247.48 5976070.54 652376.91 GCT-MS 5441.65 47.20 346.17 5001.49 4934.43 1194.05 -253.02 5976092.65 652370.93 GCT-MS 5472.95 47.00 346.58 5022.79 4955.73 1216.34 -258.42 5976114.82 652365.07 GCT-MS 5503.15 47.05 346.83 5043.38 4976.32 1237.84 -263.50 5976136.22 652359.56 GCT-MS 5533.85 47.25 346.94 5064.26 4997.20 1259.76 -268.61 5976158.03 652354.01 GCT-MS 5564.55 47.43 347.00 5085.06 5018.00 1281.76 -273.70 5976179.91 652348.47 GCT-MS 5595.65 47.50 347.04 5106.09 5039.03 1304.09 -278.85 5976202.13 652342.87 GCT-MS 5626.75 47.68 347.02 5127.06 5060.00 1326.46 -284.00 5976224.40 652337.26 GCT-MS 5657.55 48.00 347.05 5147.73 5080.67 1348.71 -289.12 5976246.53 652331.69 GCT-MS 5687.65 48.22 347.11 5167.83 5100.77 1370.55 -294.13 5976268.27 652326.23 GCT-MS 5718.85 48.38 347.16 5188.59 5121.53 1393.26 -299.32 5976290.86 652320.59 GCT-MS 5749.75 48.48 347.25 5209.09 5142.03 1415.81 -304.44 5976313.30 652315.01 GCT-MS 5781.55 48.60 347.43 5230.14 5163.08 1439.06 -309.66 5976336.44 652309.31 GCT-MS 5812.05 48.73 347.65 5250.29 5183.23 1461.42 -314.60 5976358.69 652303.92 GCT-MS 5842.35 48.88 347.90 5270.24 5203.18 1483.70 -319.43 5976380.87 652298.64 GCT-MS 5873.25 49.05 348.19 5290.53 5223.47 1506.51 -324.26 5976403.57 652293.35 GCT-MS 5904.75 49.23 348.48 5311.14 5244.08 1529.84 -329.07 5976426.80 652288.06 GCT-MS 5935.95 49.33 348.74 5331.49 5264.43 1553.02 -333.74 5976449.87 652282.92 GCT-MS 5966.85 49.38 348.99 5351.62 5284.56 1576.02 -338.27 5976472.78 652277.92 GCT-MS 5998.05 49.62 349.17 5371.88 5304.82 1599.32 -342.77 5976495.98 652272.96 GCT-MS 6029.65 50.02 349.23 5392.27 5325.21 1623.03 -347.29 5976519.59 652267.95 GCT-MS 6060.95 50.10 348.86 5412.37 5345.31 1646.59 -351.85 5976543.06 652262.91 GCT-MS 6091.75 49.77 348.06 5432.19 5365.13 1669.69 -356.57 5976566.05 652257.73 GCT-MS 6122.85 49.28 347.30 5452.38 5385.32 1692.80 -361.61 5976589.05 652252.21 GCT-MS 6153.35 48.68 346.78 5472.40 5405.34 1715.23 -366.77 5976611.36 652246.60 GCT-MS 6182.95 48.27 346.42 5492.02 5424.96 1736.78 -371.91 5976632.81 652241.02 GCT-MS 6213.75 48.33 346.29 5512.51 5445.45 1759.13 -377.33 5976655.04 652235.14 GCT-MS 6243.15 48.50 346.23 5532.02 5464.96 1780.49 -382.56 5976676.29 652229.49 GCT-MS 6273.75 48.55 346.07 5552.29 5485.23 1802.75 -388.05 5976698.43 652223.55 GCT-MS 6302.15 48.62 345.80 5571.07 5504.01 1823.41 -393.22 5976718.98 652217.95 GCT-MS 6324.35 48.68 345.25 5585.74 5518.68 1839.55 -397.39 5976735.03 652213.46 GCT-MS 6345.95 48.70 344.33 5600.00 5532.94 1855.21 -401.64 5976750.59 652208.89 GCT-MS 6368.35 48.67 343.05 5614.79 5547.73 1871.35 -406.37 5976766.64 652203.83 GCT-MS 6389.65 48.72 342.05 5628.85 5561.79 1886.62 -411.17 5976781.80 652198.73 GCT-MS 6411.05 48.88 341.54 5642.94 5575.88 1901.91 -416.20 5976796.99 652193.39 GCT-MS 6433.35 49.05 341.27 5657.58 5590.52 1917.85 -421.56 5976812.82 652187.70 GCT-MS 6454.75 49.17 341.16 5671.59 5604.53 1933.17 -426.77 5976828.03 652182.18 GCT-MS 6463.00 49.18 341.13 5676.99 5609.93 1939.08 -428.79 5976833.89 652180.04 MWD+IFR+MS 6502.86 50.05 337.52 5702.82 5635.76 1967.47 -439.51 5976862.06 652168.74 MWD+IFR+MS 6597.30 51.99 329.21 5762.29 5695.23 2032.96 -472.43 5976926.86 652134.50 MWD+IFR+MS 6690.54 52.64 321.31 5819.34 5752.28 2093.50 -514.44 5976986.52 652091.27 MWD+IFR+MS 6781.82 51.71 320.58 5875.32 5808.26 2149.49 -559.87 5977041.57 652044.72 MWD+IFR+MS 6875.20 51.55 319.97 5933.28 5866.22 2205.79 -606.66 5977096.91 651996.79 MWD+IFR+MS 6968.46 52.12 317.86 5990.92 5923.86 2261.05 -654.84 5977151.17 651947.50 MWD+IFR+MS 7062.11 53.48 311.13 6047.58 5980.52 2313.25 -708.03 5977202.27 651893.27 MWD+IFR+MS 7154.66 54.01 309.68 6102.31 6035.25 2361.62 -764.86 5977249.47 651835.47 MWD+IFR+MS 7248.51 53.57 309.33 6157.75 6090.69 2409.79 -823.28 5977296.44 651776.08 MWD+IFR+MS 7341.61 52.89 307.41 6213.48 6146.42 2456.09 -881.74 5977341.53 651716.69 MWO+IFR+MS 7435.53 50.85 304.71 6271.48 6204.42 2499.58 -941.44 .5977383.80 651656.13 MWD+IFR+MS 7529.43 48.97 303.15 6331.95 6264.89 2539.69 -1001.03 5977422.68 651595.73 MWD+IFR+MS • Halliburton Company Survey Report Company: BP Amoco Date: 9/10!2007 Time: 17:21.52 Page: 9 Feld: Prudhoe Bay Co-ordinate(NE) Reference: WOII: F-42, True N orth Site: PB F Pad Vertical (TVD) Reference: F-42A: 67.1 Well: F-42 Wellpath; F-42A Section (VS) Reference: We{I (O.OON,O.OOE Survey Calculation Method: Minimum Curvatur ,316.66Azi) e Db: Oracle Survey NID ' IncL Azim' TVD Sys TVD N/Sc E/W MapN MapE Tool ft 'deg deg ft- ft fT ft ft ft 7623.45 44.97 302.92 6396.09 6329.03 2577.15 -1058.63 5977458.96 651537.39 MWD+IFR+MS 7716.37 40.87 301.33 6464.13 6397.07 2610.82 -1112.19 5977491.53 651483.16 MWD+IFR+MS 7809.57 39.75 299.82 6535.20 6468.14 2641.49 -1164.09 5977521.14 651430.65 MWD+IFR+MS 7902.68 39.55 300.28 6606.89 6539.83 2671.24 -1215.52 5977549.84 651378.63 MWD+IFR+MS ~ 7996.55 39.24 300.56 6679.43 6612.37 2701.41 -1266.89 5977578.95 651326.66 MWD+IFR+MS 8090.50 39.05 299.94 6752.29 6685.23 2731.29 -1318.12 5977607.78 651274.83 MWD+IFR+MS 8184.89 38.63 300.28 6825.81 6758.75 2760.98 -1369.33 5977636.42 651223.03 MWD+IFR+MS 8276.68 38.36 299.91 6897.65 6830.59 2789.63 -1418.76 5977664.06 651173.03 MWD+IFR+MS 8371.64 38.66 299.60 6971.96 6904.90 2818.98 -1470.10 5977692.35 651121.11 MWD+IFR+MS 8463.51 38.40 299.78 7043.83 6976.77 2847.32 -1519.81 5977719.67 651070.84 MWD+IFR+MS 8557.18 39.43 299.87 7116.71 7049.65 2876.59 -1570.86 5977747.89 651019.21 MWD+IFR+MS 8651.57 38.51 299.77 7190.10 7123.04 2906.11 -1622.36 5977776.35 650967.12 MWD+IFR+MS 8744.48 39.38 299.68 7262.36 7195.30 2935.06 -1673.08 5977804.27 650915.83 MWD+IFR+MS 8836.05 40.87 301.12 7332.37 7265.31 2964.93 -1723.96 5977833.09 650864.35 MWD+IFR+MS 8929.91 40.13 301.14 7403.74 7336.68 2996.45 -1776.14 5977863.54 650811.54 MWD+IFR+MS 9022.65 39.50 300.60 7474.98 7407.92 3026.92 -1827.11 5977892.96 650759.97 MWD+IFR+MS 9117.52 40.57 301.94 7547.62 7480.56 3058.60 -1879.26 5977923.57 650707.18 MWD+IFR+MS 9211.35 40.31 302.52 7619.03 7551.97 3091.06 -1930.75 5977954.97 650655.05 MWD+IFR+MS 9305.28 39.92 302.25 7690.86 7623.80 3123.47 -1981.86 5977986.34 650603.30 MWD+IFR+MS 9398.39 41.11 302.47 7761.65 7694.59 3155.85 -2032.95 5978017.67 650551.56 MWD+IFR+MS 9492.48 40.56 303.24 7832.84 7765.78 3189.22 -2084.63 5978049.98 650499.21 MWD+IFR+MS 9585.26 40.15 303.03 7903.54 7836.48 3222.06 -2134.94 5978081.78 650448.25 MWD+IFR+MS 9678.95 40.32 302.19 7975.06 7908.00 3254.68 -2185.92 5978113.35 650396.63 MWD+IFR+MS 9771.95 42.21 300.90 8044.96 7977.90 3286.75 -2238.19 5978144.35 650343.71 MWD+IFR+MS 9864.52 41.29 301.86 8114.03 8046.97 3318.84 -2290.82 5978175.36 650290.45 MWD+IFR+MS 9956.97 40.53 301.66 8183.89 8116.83 3350.71 -2342.29 5978206.18 650238.34 MWD+IFR+MS 10050.40 41.38 300.30 8254.46 8187.40 3382.23 -2394.80 5978236.61 650185.21 MWD+IFR+MS 10143.99 40.25 301.66 8325.29 8258.23 3413.71 -2447.24 5978267.02 650132.13 MWD+IFR+MS 10238.45 39.10 301.55 8397.99 8330.93 3445.31 -2498.61 5978297.57 650080.14 MWD+IFR+MS 10331.63 38.95 299.00 8470.38 8403.32 3474.88 -2549.26 5978326.10 650028.90 MWD+IFR+MS 10424.39 39.71 295.13 8542.14 8475.08 3501.61 -2601.60 5978351.75 649976.03 MWD+IFR+MS 10517.70 40.17 290.76 8613.70 8546.64 3524.94 -2656.74 5978373.95 649920.43 MWD+IFR+MS 10560.31 39.72 290.32 8646.37 8579.31 3534.54 -2682.36 5978383.03 649894.63 MWD+IFR+MS 10600.28 39.84 288.15 8677.09 8610.03 3542.96 -2706.50 5978390.96 649870.32 MWD+IFR+MS 10630.42 40.61 287.20 8700.10 8633.04 3548.87 -2725.05 5978396.49 649851.66 MWD+IFR+MS 10663.00 41.67 284.69 8724.64 8657.58 3554.75 -2745.66 5978401.95 649830.94 MWD+IFR+MS 10693.04 41.80 282.97 8747.05 8679.99 3559.53 -2765.07 5978406.33 649811.43 MWD+IFR+MS 10723.48 42.05 281.02 8769.70 8702.64 3563.76 -2784.96 5978410.15 649791.46 MWD+IFR+MS 10755.33 41.60 278.79 8793.44 8726.38 3567.41 -2805.88 5978413.38 649770.47 MWD+IFR+MS 10785.88 42.67 277.06 8816.09 8749.03 3570.24 -2826.18 5978415.79 649750.12 MWD+IFR+MS 10816.24 43.76 275.32 8838.22 8771.16 3572.47 -2846.85 5978417.61 649729.41 MWD+IFR+MS 10847.91 44.35 273.26 8860.98 8793.92 3574.12 -2868.81 5978418.80 649707.43 MWD+IFR+MS 10881.29 45.50 270.82 8884.62 8817.56 3574.95 -2892.36 5978419.16 649683.86 MWD+IFR+MS 10909.77 46.23 268.97 8904.45 8837.39 3574.91 -2912.80 5978418.70 649663.43 MWD+IFR+MS 10942.20 47.54 266.68 8926.62 8859.56 3574.01 -2936.45 5978417.32 649639.80 MWD+IFR+MS 10973.02 49.32 264.20 8947.07 8880.01 3572.17 -2959.43 5978415.01 649616.87 MWD+IFR+MS 11003.33 50.73 262.00 8966.54 8899.48 3569.38 -2982.49 5978411.75 649593.88 MWD+IFR+MS 11036.25 53.12 259.38 8986.84 8919.78 3565.17 -3008.05 5978407.03 649568.40 MWD+IFR+MS 11066.54 55.35 257.19 9004.55 8937.49 3560.18 -3032.11 5978401.54 649544.45 MWD+IFR+MS ~ 11096.95 57.64 255.15 9021.33 8954.27 3554.11 -3056.73 5978394.98 649519.96 MWD+IFR+MS 11129.70 59.58 252.50 9038.39 8971.33 3546.32 -3083.57 5978386.64 649493.29 MWD+IFR+MS 11160.43 60.57 249.93 9053.73 8986.67 3537.74 -3108.78 5978377.55 649468.26 MWD+IFR+MS 11190.99 61.20 246.63 9068.60 9001.54 3527.86 -3133.58 5978367.17 649443.67 MWD+IFR+MS • Halliburton Company Survey Report Company: BP Amoco Date: 9/10/2007 Time: 17:21:52.. Page: 10 ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: WeU: F-42, True North I ~ Site: PB F Pad Vertical (TVD) Reference: F-42A: 67.1 i Well: F-42 Section (VS) Reference: Well (O.OON,O.OOE,31 .66Azi) ~ Wellpath: F-42A Survey CalculatioaMet6od; Minimum Curvature I)lr: Oracle Survey MD Incl Azim TVD Sys TVD N/S FJW MapN MapE Tool ft deg deg ft ft ft ft ft' ft ~ 11283.87 61.49 241.42 9113.16 9046.10 3492.18 -3206.81 5978330.00 649371.18 MWD+IFR+MS 11312.65 61.02 241.62 9127.00 9059.94 3480.14 -3228.99 5978317.52 649349.26 MWD+IFR+MS 11360.00 61.02 241.62 9149.94 9082.88 3460.46 -3265.43 5978297.10 649313.22 PROJECTED to TD Digital Well File ~ • Page 1 of 1 Well: F-42 Well History Well Date Summary F-42A 11/15/2007 "`WELL S/I ON ARRIVAL"' (post sdtrk) PULLED BALL & ROD FROM 10,406' SLM. PULLED BK-DGLV FROM STA #4 @ 6306' SLM. PULLED BK-DCR GLV FROM STA #5 @ 3597' SLM. SET BK-LGLV (1/4" PORT-1500#) IN STA #5 @ 3597' SLM. SET BK-OGLV (5/16" PORT) IN STA #4 @ 6306' SLM. PULLED 4-1/2" RHC PLUG BODY FROM 10,412' SLM. DRIFTED TO 11,269' MD W/ 10' x 3-3/8" DMY GUN. SAMPLE OF CEMENT RECOVERED ***WELL LEFT S/I ON DEPARTURE, TURNED WELL OVER TO PAD OPER.*** F-42A 11/26/2007 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 900!1050/250. RIH WITH 5' GUN 6 SPF 60 DEG PHASING POWERJET 2906. ***CONTINUED ON 27-NOV-2007*** JOB INCOMPLETE. F-42A 11/27/2007 *'*CONTINUED FROM 11-26-2007"" WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 900/1050/250. RIH WITH 5' x 2 7/8" 6 SPF 60 DEG PHASING POWERJET 2906. PERFORATED 4.5" LINER AT 11 152'-11 157' ITH 25' x 60 DEG PHASING POWERJET 2906. PERFORATED 4.5" LINER AT 11 030'-11 055' WELL LEFT SHUT-IN. FINAL T I 9 *** JOB COMPLETE *** Print Date: 12/20/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/20/2007 "TREE = 41116" CAMERON UUELLHEAD= McEVOY ACTUATOR = OT1S KB. ELEV = 64.48 8F. ELEV = 37.11 KOP = 2800' Max Angle = 60 Datum MD = Datum TV D = 10857' ~ $800 SS F-42A DRLG DRAFT 113-3/8" CSG, 68#, NT-80-CY HE, ID = 12.415" H 2692' TOP OF WHIPSTOCK H -6345' 2135" -141!2" HES X NtP, ~ = 3.813" "6308' 7", 26# TCII TIEBACK-CMT TO -2800 GAS 1 IFT MA Nf]ftFl S ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3614 3606 15 KBG2 DOME BK 16 11/15!07 4 6325 5586 49 KBG2 50 BK 20 11/15/07 3 8323 6934 39 KBG2 OMY BK 0 08/20/07 2 9525 7858 40 KBG2 DMY BK 0 08/20/07 1 10263 8417 39 KBG2 DMY BK 0 08/20/07 6299' 9-5/8" x 7" BAKERZXPLTPw/TIEBACK 5LV MILLOUT WINDOW (F-42) 6463' -6480' ¢sv H 6485' 19-5/8" CSG, 47#, NT-80S, ID = 8.681" I 4-1/2" TBG, 12.6#, 13CR, ID = 3.958" 7" CSG, 26#, L-80, ID = 6.726" PERFORATION SUMMARY REF LOG: MWD/ GR ON 08119/07 ANGLEATTOPPERF: 53° @ 11030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 11030 - 11055 O 11!27/07 2-7/8" 6 11152 - 11157 O 11/27/07 PBTD 4-112" LNR, 12.6#, L-80, ID = 3.958" I 10600' I 11274' 11360' 10332' -~4-1(2" X NIP, ID = 3.813" 10353' T' x 41Y2" Baker S-3 9Cr 10376' 4112" X NIP, ~ = 3.813" 10439' 41 /2" X N NIP, ID = 3.725" 10446' 7" x 4112" BAKER ZXP LTP 10464' ~ 7" X 4-1/2" BKR HMC LNR HGR, I ID = 4.41" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/91 ORIGINAL COMPLETION 08/25!07 SIDETRACK 08/25/07 SV DRLG CORRECT~NS 11/19/07 JLJ/PJC GLV GO (11115/07) 11/28/07 SRB/PJC INTf1AL PERFORATIONS PRUDHOE BAY UNfT 1lIIELL: F-42 PERMIT No: 1901580 API No: 50-029-22108-00 5EC 2, Ti 1 N, R13E, 1910' FNL 8 2173' FEL BP 6cpbratian (Alaska) 11-Sep-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well F-42A Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 6,454.75' MD Window /Kickoff Survey 6,463.00' MD (if applicable) Projected Survey: 11,360.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 V'Ll~~~! date ~ Siyned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~ - v~ • Date 09-20-2007 Transmittal Number:92904 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have anv Questions, please contact llouglas llortch at trie YllC: at Jb4-4y I S elivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 09-15A ao~'v9~ " ~S~l~rO _ _ _ __ AGI-10A~o~-~3S # ~S~I~Sa F-O1A ao(o-t0~. ~ ~S<l~3 4t5`/~`! F-01 AP61--___ _._ ___- --- - __..___ _ F-09Bao~-~-3 ~ ~Sy~5 F-42A c7U~- U93 ti i SLl`Sly L-204L1 a~-vei3 ~ t5~/~~ L-204L3 a(~-OqS ~t5~/~ L-204L4 a U(o-p4 ~, '~ l Sal ~ ~ N-22B c7U(o -!!o / ~ /5 ~/9 / V-205L1 ~UCo-l?fl ~'IS~l9a V-205L2 ap(o_f eta ~ t S~i3 W-204L1_c2U(o-lS9 _'~ cSS~°i_~/ . W-204L2_av~-LloO t' 1~L~45 WG__I-09 _U_IC SQL - IL/(o ~ ~S K9~ ~~ D Please Sign 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 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 i 6' Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, September 20, 2007 10:06 AM To: 'Hubble, Terrie i.' Cc: 'Stephen F Davies'; 'Arthur C Saltmarsh'; Stewman, Sondra D Subject: RE: Got another question... Page 1 of 1 ao~-~~~ Hi Terrie, I spoke with Steve Davies and it is appropriate to "start the clock" when the perfs are shot. You correctly state that the well is not completed since the perfs have not been shot. However, that operation is imminent. In this case the time involved (between rig release and perfing) does not appear to be long. If the shots were planned say more than 60 days from now, it likely would have been appropriate to file the 407 with the well suspended. will place a copy of this note in the file. It is probably appropriate to check with us like here if similar situation were to be encountered. Call or message with any questions. Tom Maunder, PE AOGCC From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Thursday, September 20, 2007 9:44 AM To: Maunder, Thomas E (DOA) Subject: Got another question... Hi Tom, Got another problem... this is the first time that this has come up since we were asked to quit sending revised Completion Reports except where necessary. F-42A (207-093) was recently drilled, but the well was not perfd before the rig released. I spoke with the pad engineer and his best guess as to when it will be perfd is early October. I don't want to miss my 30 day deadline, so... do I submit the Completion Report now? Or do start the 30 day countdown from the day it is perfd as that is when it is actually completed. Your help is appreciated. Thanks! Terrie 9/20/2007 • ~~Q~C~ 0~ ~~~~~`~C~{~~,~~~ ALASSA OLL A11TD G~-S C011TSERQA7'I011T COMI-'II5SIOI~T Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 C SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-42A BP Exploration Alaska, Inc. Permit No: 207-093 Surface Location: 1910' FNL, 2173' FEL, SEC. 02, T11N, R13E, UM Bottomhole Location: 1431' FSL, 291' FEL, SEC. 34, T12N, R13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill 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. ti'Vhen providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 6~-3607 (pager). DATED this ~d day of July, 2007 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~I~~~ STATE OF ALASKAy~~ ALASIL AND GAS CONSERVATION COMMI~N y~s" '-~~)N ~ 8 ZOO7 PERMIT TO DRILL `" ~pa;ka Oil ~ Gas Cons. Cammissi 20 AAC 25.005 0~ /lnrhnrenn 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 - 11. Well Name and Number: PBU F-42A - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11439 TVD 9179 12. Field !Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: T11 N R13E UM ' FE SEC ' 7. Property Designation: ADL 028278 ^ Pool ' , , 1910 FNL, 2173 L, . 02, Top of Productive Horizon: 1491' FSL, 55' FEL, SEC. 34, T12N, R13E, UM - 8. Land Use Permit: 13. Approximate Spud Date: August 1, 2007 Total Depth: 1431' FSL, 291' FEL, SEC. 34, T12N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7900' 4b. Location of Well (State Base Plane Coordinates): Surface: x-652648 y-5974904 Zone-ASP4 10. KB Elevation (Height above GL): Plan 64 feet 15. Distance to Nearest Well Within Pool: 253' 16. Deviated Wells: Kickoff Depth: 6495' feet Maximum Hole An le: 60 _ de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3747 - Surface: 2882 18. a in Pr ram: S eciticatio ns To - Settin D th -Bottom uanti of ement .f. 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 4230' 6345' 5599' 10575' 8650' 723 cu ft LiteCrete 106 cu ft Class 'G' Tieback 7" 26# L-80 TCII 6345' Surface Surface 6345' 5599' 511 cu ft Class'G' 6-1/ " 4-1/2" 12.6# 13Cr80 VamTo 1014' 1042 ' 8 3 ' 11439' 9179' 152 cu ft Clas ' 1g. PRESE NT WELL CONDITION S UMMARY (To be completed forRedrill and Re-entry Operations) Total Depth MD (ft): 11650 Total Depth TVD (ft): 9177 Plugs (measured): 11257 Effective Depth MD (ft): 11301 Effective Depth TVD (ft): 8963 Junk (measured): None Casing Length Size ement Volume MD D Conductor /Structural 110' 20" 110' 110' Surface 2692' 13-3/8" 3673 cu ft Permafrost 2692' 2692' Intermediate 10853' 9-5/8" 2310 cu ft Class'G' 10853' 8654' Pr ti n Liner 1063' 7" 258 cu ft Class 'G' 10587' - 11650' 8469' - 9177' Perforation Depth MD (ft): 11155' - 11350' Perforation Depth TVD (ft): 8866' - 8995' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoinglis true and correct. Contact Kris Honas, 564-x338 Printed Name Greg b~ Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-4191 Date - > ~ ~ ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: O 30 API Number: 50-029-22108-01-00 Permit Approv I See cover letter for Date: - ~'~~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me_th/ane, gas hydrates, or gas contained shales: ~SC~ ~ \ ~® Samples Req'd: ^ Yes LrJ No Mud Log Req'd: ^ Yes Ld No ` ' ~ ~'~`~~ HZS Measures: [Yes No ire Tonal Survey Req'd: Yes ^ No Other: h'~ ~`~.~t~ c' CMS @ E'er ~ L~, R ~. a S , 03~ `~~UIC / APPR D BY THE COMMISSION Date ~'"(~ "'~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 O V ~ / Submit In Duplicate RlGINAL ~./ ~~ • • To: Alaska Oil & Gas Conservation Commission From: Kristopher E. Honas __ -y Date: June 27, 2007 - ~ ' Re: F-42A Sidetrack Permit to Drill _ The F-42A sidetrack is scheduled to be drilled by Nabors 2ES with an estimated move onto the location date of August, ls` 2007. The sidetrack plan is to exit the parent F-42A wellbore from the 9-5/8" casing at 6495' NID with an 8-1/2" BHA. An 8-1/2" hole will then be drilled to the top of the Sag River formation where a 7" drilling liner will be run and cemented. A 6-1/8" hole will then be drilled building to 60° and targeting the zone 3 and 2C sands. The planned well will drill at a 60° inclination to an estimated TD of 11439' NID. This is 200' past the point of oil/water contact. A solid 4-1/2", 13Cr-80 production liner will be run and cemented from TD to 150' back into the 7" drilling liner. A 4-1/2" chrome tubing string is the planned completion for this well. F-42A Wellplan Summary Well F-42A Well Sidetrack / Target Zone 3/2C T e Slant Producer Ob'ective AFE Number: PBD API Number: 50-029-22108-01 Surface Northin Eastin Offsets TRS Location 5974904 652648 1910 FNL / 3106' FWL 11 N, 13 E, 2 Target Northin Eastin Offsets TRS Location 5978240 649415 3789' FN V5225' FWL 12 N, 13 E, 34 Bottom Northin Eastin Offsets TRS Location 5978175 649180 3849' FNU3989 FWL 12 N, 13 E, 34 Planned KOP: 6495' MD Planned S ud: 08/01/07 Ri Nabors 2ES Planned TD: 11,439' MD Planned TVD: 9179' TVD G L: 38.5' RTE: 64' Directional Program A roved Well Ian: W P05 Exit oint: 6495' and / 5697' tvd Maximum Hole Inclination: Original well 49° at KOP. Hold a 40.3° inclination though the 8-1/2" section buildin to 60 m the 6-1/8 section. Proximit Issues: No pre-ri ro required. No anti-collision issues on this well. Surve Pro ram: Standard MWD+IIFR+MS Nearest Well: Well F-21,with acenter-to-center distance of --253' at 9281" md. Nearest Property Line 7900' F-42A Sidetrack Page 1 Lopping Program Hole Section: Required Sensors /Service 8-1/2" intermediate: MWD DIR/GR/RES/PWD throu hout the interval all in real-time mode. " 6-1/8" roduction: DIR/GR/RES/DEN/NEU throu hout the interval all in real-time mode. - Cased Hole: None tanned O en Hole: None tanned Mud Program Fresh water LSND Hole Section / o eration: 8-1/2" Intermediate Hole HTHP Density PV YP API FL Drill Fluid Depth (ft) (ppg) (cp) (Ib/100ft2) (mU30min) pH Solids MBT Loss (%) (mU30mi n 6495' M D window 8.8 16 -30 30 < 8.0 9.0 -10 <6.0 N/C N/C millin 6495' M D- 8471' MD (150' above 8 8 -9 6 15 -25 22 - 30 5.0 - 7.0 9.0 -10 <6.0 <15 N/C TH RZ 8471' MD - 10575' MD 11.0 15 - 22 26 -30 4.0 - 6.0 <9 - 20 <6.0 <15 <10.0 Hole Section /operation: 6-1/8" Production Interval Type Density (ppg) PV YP LSRV API FL pH FloPro SF 8.4-8.5 8 -12 22 - 28 > 20,000 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8.5" 7" 26.0# L-80 BTC-M 4230' 6345' / 5599' 10575' / 8650' Tieback 7" 26# L-80 TCII 6345' Surface 6345' / 5599' 6-1/8" 4-1/2" 12.6# 13CR-80 VamTo 1014' 10425'/ 8539' 11439' / 9179' Tubin 4-1 /2" 12.6# 13Cr-80 VamTo 10425' Surface 10425' / 8539' Cementing Program Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Lead slurry: 12.0 ppg LightCRETE, 3580' of 7", 26# liner x 8-1/2 open hole plus 40% excess, 150' of 7", 26# liner x 9-5/8" 47# casing, 200' of 4" drillpipe Slurry Design Basis: x 9-5/8", 47# casing. Tail slurry: 15.8 ppg class `G', 80' of 7", 26# shoe track, plus 500' of 7" x 8- 1/2" o en hole with 40% excess. Pre-Flush None Planned Fl id /V l S S acer 20bbls MudPUSH II at 11.5 u s equence ume: o Lead Slur 128.7 bbls / 1.60 ft /sk / 450.4 sks 12.0 Li htCRETE Tail Slur 18.9 bbls / 1.16 ft /sk / 91.3 sks 15.8 class `G' BHST: 199° fl t ill b i d fh C ° y w e m xe on e emen BHCT: 133 F-42A Sidetrack Page 2 • • Casin Strin 7", 26#, L-80, TCII, Tieback Slurry Design Basis: Lead slurry: None Tail slurry: 15.8 ppg class `G', 3495' of 7", 26# casing x 9-5/8", 47" casing, lus 40' of 7", 26# shoe track Pre-Flush None Planned Fl id /V S l S acer 85 bbls diesel u s equence o ume: Lead Slur None Tail Slur 91 bbls / 1.16 ft /sk Class `G' with as block BHST: 150° Cement will be mixed on the fly Casin Strin 4-1/2", 12.6#, 13Cr-80, VamTo solid production liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 864' of 4-1/2" X 6-1/8" annulus with 40% excess, plus 80' of 4- 1/2", 12.6# shoe track, plus 150' of 7" X 4-1/2" liner lap, plus 200' of 7" X 4" drill i e annulus. Pre-Flush 15bbls CW 100 Fl id S /V l S acer 20bbls MudPUSH II at 10.5 u s equence ume: o Lead Slur None tanned Tail Slur 27 bbl / 1.16 tt /sk 15.8 Class `G' BHST: 199° i t ill b b t h i d b f C BHCT: 136° ore pump ng emen w a c m xe e e Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9-5/8" window 20' be and mid-window FIT 12.0 EMW 7" casing to surface Landing collar to surface Casing Test 30 min recorded 3,500psi surface 7" shoe 20' be and shoe FIT 10.1 EMW 4-1/2" liner Landing collar to surface Casing Test 30 min recorded 3,500 psi surface Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 Yz" intermediate interval Maximum antici ated BHP: 3747 si at 8606' sstvd. Maximum surface ressure: 2881.6 psi (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 115 bbls with 11.0 ppg mud and a maximum poor pressure gradient of 9.5 EMW FIT TO 12.0 PPG EMW Planned ROPE test pressure: 250psi low / 3,500psi high - 7 day test cycle until a window is milled in 9-5/t3" casing. Once a window is milled a 14 day test cycle can commence. BOPS configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams Liner while running the 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. F-42A Sidetrack Page 3 Well Interval: 6-1/8" production liner section Maximum antici ated BHP: 3,180psi at 8,800' sstvd. Maximum surface ressure: 2,300 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.4 EMW FIT FIT to 10.1 EMW Planned BOPE test ressure: 250 si low / 3,500psi hi h Planned com letion fluid: 8.4p seawater / 7.Op Diesel Planned BOPE test ressure: 250 si low / 3,500 si hi h -14 da test c cle. 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 (7) Formation To s(TVDss) and Estimated Pore Pressures Est. Formation Tops Uncertainty Commercial Hydrocarbon Bearing Est. Pore Press. Formation (TVDss) (eet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV4 2960 SV3 3307 SV2 3462 SV1 3838 UG4 4278 UG3 4513 UG2 NA UG1 5020 WS2 5596 Kickoff 5633 6495 CM3 6025 CM2 NA CM1 NA THRZ 7213 BHRZ 7353 TJF 7690 TJE 7844 TJD 8048 TJC 8296 TJB 8431 Sa River 8606 Yes Shublik 8650 10 Yes TSAD / TZ46 8722 20 Yes 3180 si CAB 8800 TZ4A/42N 8781 20 Yes F-42A Sidetrack Page 4 • TCGL / TZ3 8843 20 Yes PGOC 8848 20 Yes BCGLITZ2 8901 20 Yes POWC 8912 20 NA 25N / T2B 8956 30 Possible MHO/HOT 8995 10 Yes/HO 22N / T26 9040 20 Yes/HO OOWC 9047 10 No 21 N 9079 20 No TZ16 9108 30 No TD Criteria TD Criteria Well is planned to drill to TD 200' below oil/water contact. TD of well will be shortened _(horizontal): or lengthened if oil/water contact comes in high Fault Prognosis Formation where Est. MD SSTVD Throw encounter the Fault Intersect Intersect Est. Throw Direction Uncertainty No significant faults antici ated. F-42A Operations Summary scope - Cut and pull the existing 4-1/2" CR-80 tubing from 6855' MD. - Sidetrack the well from -6495' MD drilling -4080' of 8-1/2" intermediate hole to the top of the Sag River formation. - Drill --864' of 6-1/8" production hole, building to a max. inclination of 60° targeting zone 2C and zone 2 sands. - Drill 200' past the oil/water contact. - Run a 7", 26#, L-80, BTC-M intermediate liner, a 4-1/2", 12.6#, 13Cr-80 production liner, a 7", 26#, L- 80, TCII tieback, and 4-1/2", 12.6#, 13Cr-80, Vam Top Completion. Pre-Rig Operations: 1. Fluid Pack the tubing and inner annulus w/seawater. 2. P&A the perfs in the 7" liner from the IBP at 11257' MD to 10587' MD. RIH with coil. Lay in 26.5 bbls of 15.8 ppg cement squeezing ~2 bbls into the open perfs. Cement Calculations: 7" liner = 11257' -10641' (23.6 bbls) 4-1/2" tubing = 10641' -10587' (0.8 bbls) Perforation squeeze = (2 bbls) Total = 26.5 bbls 3. RU E-line. Drift the 4-1/2" tubing. Tag TOC. 4. Jet cut the 4-1/2" tubing in the middle of the first full joint of tubing at -6855' MD. 5. Circulate the well to seawater through the tubing cut. Freeze protect the IA and tubing with diesel to 2200' M D 6. Bleed the OA, IA & TBG to zero psi. CMIT - T X IA to 3000 psi for 30 minutes. MIT - O.A. to 2000 psi for 30 minutes. If the MIT fails, obtain LLR. F-42A Sidetrack Page 5 • • 7. PPPOT - IC (9-5/8") 3,000 psi, PPPOT-T (4-1/2") 5,000 psi. Function all lock-down screws. 8. Bleed all casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 9. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Rig Operations: 1. MI / RU Nabors rig 2ES. 2. Pull the BPV. Circulate out diesel freeze protection and displace the well to seawater. Set and test the TWC from below to 1000 psi. 3. Nipple down the tree. Nipple up and test the BOPE to 3,500 psi. Pull the TWC. 4. R/U, pull and lay down the 4~/z", 12.6#, 13Cr-80 tubing from the jet cut at 6855' MD. 5. RU E-line and run a full gauge 8.5" GR/JB & CCUGR to confirm access to set an EZSV (CIBP) and to run the BOT 9-5/8" whipstock assembly. (If the GR/JB run passes, proceed with this wellplan. If GR/JB indicates a scraper run is needed, PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to below the EZSV setting depth at 6518' MD. 6. RIH and set an EZSV (CIBP) at 6518' MD. 7. Pressure-test the casing to 3,500psi for 30 minutes. Record test. 8. If the pre-rig PPPOT - IC (9-5/8" casing) passed, continue with the program. If it fails, change out the 9-5/8" pack-offs by pulling them through the BOP stack. 9. PU a 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Swap well over to 8.8 ppg fresh water LSND millin fluid. 10. Mill a window in the 9-5/8" casing plus 20' of formation from mid-window. Verify that the mud weight is 8.8 ppg prior to cutting the window. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POOH. ~'~~ 12. M/U an 8'/i" Dir/GR/Res/PWD assembly. RIH, kick off and drill --2226' to the top of the HRZ with an ~~ 8'h" bit. Before drilling into the HRZ (8500' MD) circulate bottoms up and weight up to 11.0 ppg LSND milling fluid to drill the HRZ and Kingak shales. Continue holding a 40.25° degree inclination and drill ahead to the top of the Sag River formation at 10,575' MD. 13. Clean and circulate the hole. POOH. 14. Run and fully cement a 7", 26#, L-80, BTC-M drilling liner throughout the 8-1/2" hole and 150' back inside the 9-5/8" casing to 6345' MD. Set hanger /liner top packer and displace cement with mud. POOH. 15. RU and run a 7", 26#, L-80, TCII tieback from the top of the 7" liner to surface. Set the 7" tieback in the old tubing spool with slips. Cement the 7" tieback to -2850' MD with -91 bbls of cement. The top 2200' of 7" x 9-5/8" annulus will be freeze protected to surface. 16. NU a new 13-3/8", 5000psi tubing spool above the existing tubing spool. NU the BOPE and test. 17. MU a 6-1/8" drilling assembly with DIR/GR/RES/NEU/DEN for real-time logging. RIH to the 7" tieback landing collar. 18. Pressure test the 7" tieback to 3500 psi for 30 minutes. 19. Drill out the 7" tieback float equipment. Continue running in hole to the 7" drilling liner landing collar. 20. Pressure test the wellbore to 3500 psi for 30 minutes. 21. Drill out the shoe track. Swap over to 8.4 ppg FloPro mud. Drill 20' of new formation and perform an FIT to 10.1 ppg. 22. Drill ahead to TD building to 60°. Use real-time logging to locate the point of oil/water contact. TD will be called -200' past oil/water contact. Estimated TD is 11,439' MD. 23. CBU, short trip, circulate until clean. POOH. 24. Run and cement a 4-1/2", 12.6#, 13Cr-80, solid production liner through the 6-1/8" wellbore from TD to 150' inside the 7" shoe (10,425' MD). Displace the cement with a pert pill (well will be perforated with E-line post rig). 25. Set the liner top packer. Circulate the well from above the 4-1/2" liner with clean seawater. 26. R/U and run 10,425' of 4'/z", 12.6#, 13Cr, VamTop tubing completion. Sting into the 4'h" liner tie back sleeve. 27. Reverse circulate with seawater and corrosion inhibitor. 28. Drop the ball and rod, set packer. 29. Test the tubing and annulus separately to 3500 psi for 30 minutes. Record each test. 30. Install a TWC, and test. Nipple down the BOPE. 31. Freeze protect to 2,200' TVD 32. Install a BPV. F-42A Sidetrack Page 6 • • 33. Secure the well. RDMO. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. RU E-line. Perforate the well per geologist's recommendation. 3. Install the well house and instrumentation. F-42A Sidetrack Page 7 • • F-42A Potential Drilling Hazards (Post on Rig) • Pre-job HAZOP's and Safety meetings are recommended when there is a clear change in workscope. If at any time things don't feel or look right, STOP the job and discuss the situation before making the next move. • Flash Points o Dead Crude= <40degF o Methanol (neat)= 52degF o Diesel=100degF • Hydrogen Sulfide o F-Pad is not an H2S pad. However, Standard Operating Procedures for H2S precautions should still be followed at all times. o Closest SHL Well: F-24 - 100 ppm / F-33 - no data o Max H2S reading: F-24 & F-39 w/100 ppm on 06/15/98 • Bottom Hole Pressure 0 3180 psi (7.0 ppg) @ 8800'ss o The 8.4 ppg drilling fluid will provide a 700 psi static overbalance in the reservoir. • Maximum anticipated wellhead pressure: 0 2880 psi w/full column of gas • Potential for loss circulation o Low • Faults - (F-42A is not expected to cross/intersect any mapped faults.) • Close Approaches o F-06 - 928" ctr - ctr 10454' MD o F-06A - 862' ctr - ctr 9312' MD o F-14 - 457' ctr - ctr 6504' MD o F-19 -1057' ctr - ctr 6509' MD o F-21 - 254' ctr - ctr 9280' MD o F-24 - 1341' ctr - ctr 7500' MD o F-33 - 688' ctr - ctr 6497' MD o F-34A -1040' ctr - ctr 6499' MD o F-34 -1040' ctr - ctr 6499' MD o F-37 -1084' ctr - ctr 11,387' MD F-42A Sidetrack Page 8 TREE = 4-1 M 6" CNV WvELLHEAD = McEVOY ACTUATOR = OTIS VfB. ELEV = ..................................... 66.61' .................................. BF. ELEV = 37.11' .................................... KOP = .................................... .................................. 3299' ................................... Max Angle = .................................... i4 ~ 10088' ................................... Datum MD = ................................... 11156' ....... Datum TVD = ........................... 8800' SS I ~ 13-318" CSG, 68#, NT-80-GYRE, ID =12.415" ~-) 369F' Minimum ID =3.725" ~ 10629' 4-1~" PARf(ER SWN NIPPLE ' I-14-1 f2" PARKER SWS NIP. ID = 3.813" 70548' ~9-Sat3" 7C 4-102" TNU HBBP PKR WaLATCH 9CR-7 MO. ID = 4.0" OF 7" NT 1]-CRrlU LNR ~-~ 70587' 4-1 t2" TBG,12.8#, NT h]-CRrSO I 7064 7' .0152 bpf, ID = 3.958" 9-51'8" CSG, 47#, NT-845, ID = 8.ss1° ~~ 70853' PERFORATION SUMMARY REF LOG: HLS BRCS ON 12029P30; SWS CBT ON 02M 4191 ANGLE AT TOP PERF: 47 ~ 11155' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgx DATE 3-318" 6 11155 -11215 O 03f20195 3-318" 6 11215 -11225 O 10f20196 3-31'8" 6 11225 -11240 O 09M 5194 3-318" 6 11240 -11250 O 10020/93 3-318" 6 11260 -11285 0 100201'93 3-31'8" 4 11265 -11280 O 02!24191 3-318" 4 11330 -11350 O 02(241'91 PBTD 77608' 7" LNR, 28#, NT 1]-CR-00, 77647' NSCC, .0383 bpf , ID = 6.276" ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3109 3042 2 9CR-1 M0 DMY RK 0 07/25102 4 6298 SSD2 49 9CR-1M0 DMY RK 0 07125/02 3 8581 7086 46 9CR-1M0 DMY RK 0 07!25102 2 10324 8228 50 9CR-1M0 DMY RK 0 1 10509 8349 48 9CR-1M0 DMY RK D 70608' ~~4-1 f2" PARKER SWS NIP, ID = 3.813" 70629' 4-1 I2" PARKER S1+VN NIP, fD = 3.725" 70647' 4-102" PARKER WLEG 10663' ELMD TT LOGGED 02024/91 ~ 7157' ~-iIBP, ELMD, TOP OF FISHING NECK ~ 11251' 71307' TOP OF CEMENT 71375' IBP DATE REV BY COMMENTS DATE REV BY COMMENTS 07I44I91 ORIGINAL COMPLETION 09021/03 CMO/TLP DATUM MD CORRECTION 09N9aD1 RNlTP CORRECTIONS 01 M 6106 COMIPAG WAIVER SFTY NOTE DELETED 07125/02 JBh(AK GLV CIO 10M 7102 BMITP WAIVER SAFETY NOTE 02120/03 ITCH WAIVER SAFETY NOTE 07M 3103 CMOITLP MA}C ANGLE CORRECTION PRUDHOE BAY UNIT WELL: F-42 PERMIT No: 1901580 API No: 50-029-22108-00 SEC 2, T11N, R13E, 1910' FNL 8 2173' FEL BP Explorrtion;Alosko~ • • TREE = 4-1x96" CNV WELLHEAD = .. McEVOY . . . . . ...................................... ACTUATOR = ............ .. ....... .. .. ... OTIS KB. ELEV = 66.61' BF. ELEV = 37.11' KOP = ..................................... 3299' ................................. Max Angle = ...... . i4 ~ 10088' ................ Datum MD - ...... .................... 11156' ............................... Datum TVD = 8800' SS F -42 13-318" CSG, 68#, NT-80-GYRE, ID =12.415" 2692' 41T~°°Twing 6855° Minimum ID = 3.~~5" ~ 'IIlB29' d-'I~" PARM[ER 5WN NIPPLE 4-112" PARKER SVvS NIP, ID = 3.813" 105+48' 19-518" }{ 4-112" TNV HBBP PKR WxLATCH 9CR-1 MO, ID = 4.0" OF 7" NT 1]-CR-00 LNR I~ 10587' 4-1 l2" TBG,12.6#, NT 1]-CRrlO 1D641' .D152 bpf , ID = 3.958" 9-518" CSG, 47#, NT-805, ID = 8.681" 10853' PERFORATION SUMMARY REF LOG: HLS BRCS ON 12!29190; SWS CBT ON 02M4191 ANGLE AT TOP PERF: 47 @ 11155' Note: Refer to Production DB far historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 3-318" 6 11155 -1 1215 O 03120195 3-318" 6 11215 -1 1225 O 10120x56 3-318" 6 11225 -11240 O 09M 5194 3-318" 6 11240 - 11250 O 10!20x'33 3-318" 6 11260 -11265 O 10120x33 3-318" 4 11265 -112$0 O 42124x31 3-318" 4 11330 -11350 O 02124!'91 PBTD H 11608' 7" LNR, 26#, NT 7]-CR-00, I~ 11647. NSCC , .0383 bpf , ID = 6.276' SAFETY NOTES: "' 13 CHROME T9G AND LNR DO MOT ACIOIZE!! "' 2098' ~4-112" OTIS H3C0 SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE S 3109 3D42 2 9CR-1 MO DMY RK 0 07l25xD 4 629$ 5542 49 9CR-1 M0 DMY RK 0 07125A] 3 $581 70$6 46 9CR-1M0 DMY RK 0 07125x0 2 10324 8228 50 9CR-1 M0 DMY RK 0 1 10509 8349 48 9CR-1 MO DMY RK 0 7 0608' 4-1 !2" PARKER SUVS NIP, ID = 3.813" 10629' 4-112" PARKER SUMJ NIP, ID = 3.725" 10641' 4-112" PARKER WLEG 70662' ELMD TT LOGGED 02124x'91 P~rforotacsa PIA"a _~.5 !€bt~ tiff Ctnr~trt. Plup led is ] 500 p 11~ ~p~ 11315' DATE REV BY COMMENTS DATE REV BY COMMENTS U1IU4I91 ORIGINAL CdMPLETIdN 09121x103 CMOITLP DATUM MD CORRECTION 09109x101 RN1TP CORRECTIONS 41M 6106 COMIPAG WAIVER SFTY NOTE DELETED 07025102 JBx}{AK GLV C10 1 DM 7x102 BMITP WAIVER SAFETY NOTE 02120x03 ITLH WAIVER SAFETY NOTE 07M 3x03 CMO/TLP MAH ANGLE CORRECTION ITOP OF CEMENT I PRUDHOE BAY UNIT WELL: F-42 PERMIT No: 9901580 API No: 50-029-22108-00 SEC 2, T1 1 N, R13E, 1910' FNL & 2173' FEL BP Exploration (Alrakr! IIBP, ELMD. TOP OF FISHING NECK fao 11251' • TREE = 4-1116" CNV WELLHEAD = McEVOY ..................................... ACTUATOR = .................................... ................................ DTIS ................................. ttB. ELEV = ..................................... 66.61' ................................ BF. ELEV = ......... ~~~~~. ~ ~ ..............._31:1.1' t{OP - .................................... 3299' ................................. Max Angle = ..................................... i0 @ 11127' ................................. Datum MD = ....................... ............. . . ............................ . Datum TV D = . . F-4A • SAFETYNOTES: "' 73 CHROME TBG DO NOT I ACIOIZE!! "' 4-1r2" X NIP, ID = 3.813" ~ 13.3P8" GSG, BS#. NT•SO-GYRE, ID = 12.415" 6 6 rec 6495 KoP 6340 ~ 7" 26# TCII Tieback - cemented to -2850' and FP to surface 3 0' 7"HCM Liner hanger and Z}{P packer with G ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3201 tCBG-2 4 6316 ttBG-2 3 8200 F[BG-2 2 9400 KBG-2 1 10300 F{BG-2 6518 9518"Whipstock 10305 ~41C2" X NIP, ID = 3.813" 10315' 7° x a-1 r2° Baker s-3 9cr 10340 4112" X N IP, ID = 3.813" 10400 4102" XN NIP, ID = 3.725" 70410 4112" 12.6# 13Cr-80 V amTOP Tubing, 104~0~ 4.112" W LEG 4-1l2"HCM Liner hanger and ZXP packer with 10425' receptacle 10575 7" 26# L-80 BTC-M Liner fury cemented 77349 PBTD 11439 41f2" 12.6# L-80 13Cr•$0 Liner- TD DATE REV BY COMMENTS DATE REV BY COMMENTS 0110499 ©RIGINAI COMPLETION D9021N3 CMOITLP DATUM MDCORRECTION 09A09~U1 RNITP CORRECTIONS D1 M 6106 COMlPAG WAIVER SFTY NOTE DELETED 07025A02 JBMA1{ GLV C10 10M7/02 BMITP WAIVER SAFETY NOTE 02020/03 ITLH WAIVER SAFETY NOTE 07/13/03 CMO(TLP MAX ANGLE CORRECTION PRUDHOE BAY UNIT WELL: F-42 PERMIT No: '1901580 API No: 50-029-221 08-0 0 SEC 2. T11 N. R13E. 1910' FNL & 2173' FEL 8P E~lorotion ijAloakol COMPANY DETAILS ~/~y, 8P Amoco 1 f19 ' ~~F Icula[ion Method: Minimum CurvaNre Error System: ISCWSA Scan Method: Trav Cylinder North Ertor Surface: Elliptical+Casing REFERENCE INFORMATION Co-ordinate (N,'EI Reference: Well Centre: F-42, True North th Vertical (TVD)Reference: 3N.SGL+2%.SKB fi4.(N) Section (VS)Reference: Slot-42 (QOIIN,O.IHIE) 495.( Measured Depth Reference: 3R.SGL+28.SKB 64.W Calculation Method: Minimum Cunanue TARGET DETAILS Name TVD +N,'-S +E,=W Northing Fasting Shape F-02A TI 8654.00 3536.71 -2691.94 5978385.00 649885.00 Paint F-42A T2 8912.00 3429.26 -3064.24 5978270.00 649515.00 Point F-42A T3 8979.00 3401.30 -3164.83 5978240.00 649415.00 Point F-42A Geopoly 8979.00 3401.30 -3164.83 5978240.00 649415.00 Polygon HALLIBURTON perry Grilling 8ervicesa' \., -__ - _._. _ _. I FORMATION TOP DETAILS ___ _ ______ . _. I No. TVDPath MDPath Formation 1 0.00 0.00 UG4 ' -. .___ _ 2 , 0.00 0.00 UG3 3 0.00 0.00 UG 1 '~ 4 0.00 0.00 WS2 _ ~, 5 5864.00 6755.95 WSl I _ ~ S Dir LTF 85° 12°%100' : 49 6 6064.00 7087.86 CM3 Stan Dir 4°,-100' :6515' `~ 7 7239.00 8721.24 THRZ - 8 7409.00 8943.98 LCU/BHRZ T ~ 6WS~`. 9 7409.00 8943.98 LCU/Iop Kingak , - - 10 7756.00 9398.64 TJF ~~ II 7919.00 9612.20 TJE ~, j ~ ~ -- - - C 0 12 8117.00 9871.63 TJD ! I \~ End it 13 8364.00 10195.26 TJC - _ 14 8496.00 10368.21 TJB --' -' 7500 IS 8654.00 10574.68 Sag River ' j -' '~ 16 8726.00 10669.22 Shublik - 17 8774.00 10733.75 TSAD / T24B - 18 8829.00 10810.17 TZ4A/42N -- ------- ~-r-~-~ - 8000 19 8894.00 10905.64 TCGL / TZ3 - -- - 20 8912.00 10933.45 PGOC - 21 8944.00 10984.80 BCGL/TZ2 r -- --, ----- 22 8979.00 11044.55 POWC -~- -r-~-- -- 8 00 23 9003.00 11088.35 25N / T26 -rt --;----- T 24 9059.00 11199.13 MHO/HOT LCU~B6]rl _ _. _ I -' F 1 SURVEY PROGRAM Fm Depth To Survey/Plan Tool Plan: F-02A WP 5 (F-02/Plan F-42A) NI 11439.13 Planned: F-42A WP S V22 MWD+IFR+MS Created By: Sperry Drilling Date: I%2212007 WELL DETAILS Name +N/-S +E/-W Northi ng F asting latitude Longitude Slot F- 42 2342.53 1739.10 5974904. 09 652648.18 70°20'IN.320N 148°45'411.790W 42 Sec MD Inc Azi TVD SE TION +Ni-S DETAILS +E/-W DLeg TFace VSec Target I 6495.00 49.32 341.07 5696.82 1964.20 -437.39 0.00 0.00 1703.51 2 6515.00 49.57 337.93 5709.83 1978.43 -442.71 12.00 -85.00 1717.36 3 7215.00 57.22 304.13 6134.79 2398.83 -793.41 4.00 -85.00 2262.85 4 7643.25 40.25 300.96 6416.26 2572.30 -1063.09 4.00 -173.02 2575.86 S 10398.21 40.25 300.96 8518.90 3487.92 -2589.63 0.00 0.00 4300.57 6 10574.68 40.00 290.00 8654.00 3536.71 -2691.94 4.00 -96.22 4407.23 F-42AT1 7 10599.68 40.00 290.00 8673.15 3542.20 -2707.05 0.00 0.00 4421.76 8 11127.14 60.00 240.00 9023.00 3483.30 -3081.21 8.00 279.00 4643.16 9 11299.13 60.00 240.00 9109.00 3408.82 -3210.20 0.00 0.00 4681.00 10 11439.13 60.00 240.00 9179.00 3348.20 -3315.20 0.00 0.00 4711.80 CASING DETAILS ~ ~ _,- . No. TVD MD Name 5' MD, 5696.82'TV , 5709.83'TVD D ~ ~ '~ -- ~ { -I -- ~ ~-- - - 1 ~ 8654.00 9179.00 10574.66 7" 11439.13 4 lit" D )-r--- _: _L~L1 Size zooo 4.500 s • ..-. ___ ' -~_ i 10000 - - -_-___- -_.-_.._-.._ .__-_- -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 Vertical Section a[ 315.28° [IOOOft/in] COMPANY DETAll.S REFERENCE INFORMATION SURVEY PROGRAM BP Amoco Co-ordinate (N. E) Reference: Well Centre: F-42, True North D epth Fm Depth To Survey/Plan Tool Plan: F-02A WP 5 (F-02/Plan F-02A) Vertical (TV DI Reference: 3%.SGL+2N.5KB fi4.(81 Calculation Method: Minimum Curvature Section (VS) Reference: Slot - 42 (l1.UUN,0.l1UE) 64 95. W 11439.13 Planned: F-02A WP 5 V22 MWD*IFR+MS Created By: Sperry Drilling Daze: 1/22/2W7 Error System: 1SCWSA Measured Depth Reference: 38.SGL+2%.SKB 64.0(1 Scan Method: Trav Cylinder North Calculation Method: Minimum Curvature WELL DETAll S Ertor Surface: Elliptical + Casing . Warning Method: Rules Based Name +N/-S +&-W Northing Fasting Latitude Longitude Slot A ' ~ ~ Z Q ~ F-02 2342.53 1735.10 5974904.119 fi5264%.1% 711"20'1%.320N 148"45'4U.790W 42 H ~ ~ ~ SP9rry ar~[~iAg BBPVIC~B TARGET DETAILS - "- - - - Name TVD +N/-S +E.~-W Northing Fasting Shape - --__. __- -- --. F-02A TI 8654.00 3536.71 -2691.94 5978385.00 649885.00 Point __ i~~ F-42A T2 8912.00 3429.26 -3064.24 5978270.00 649515.00 Point ~ ~ ~ F-02A T3 8979.00 3401.30 -3164.83 5978240.00 649415.00 Point -_ _ ~ ' ~ F-42A Geopoly 8979.00 3401.30 -3164.83 5978240.00 649415.00 Polygon I~ F-42A T4 9109.00 3341.09 -3401.13 5978175.00 649180.00 Point 3918 End Du : 10 74.68' MD, 8654' TVD _ _T _ _ _ _ _ SECTION DETAH-S Start Dv 8°/100' :10599. 8' MD, 8673.15TVD 1 Sec MD lnc Azi TVD +N.-S +E,!-W DLeg TFace VSec Target _ - l -- <__ ~"-r ---- I 6495.00 49.32 341.07 5696.82 196410 -437.39 0.00 0.00 1703.51 ~; 2 6515.00 49.57 337.93 5709.83 1978.43 -442.71 12.00 -85.00 1717.36 _ ___-. 3 7215.00 57.22 304.13 6134.79 2398.83 -793.41 4.00 -85.00 2262.85 -_ _ Il 4 7643.25 40.25 300.96 6416.26 2572.30 -1063.09 4.00 -173.02 2575.86 -` -- - ,~. F-02A TI - _ _ -~ --~ ~- 5 10398.21 40.25 300.96 8518.90 3487.92 ?589.63 0.00 0.00 4300.57 _ , ~ ' 1 _ . _- 6 10574.68 40.00 290.00 8654.00 3536.71 -2691.94 4.00 -96.22 4407.23 F-42AT1 - 95 % coot- ~ -_-- ---- ' ,~ - - ~ ~-_-_--' 7 10599.66 40.00 290.00 8673.15 3542.20 -2707.05 0.00 0.00 4421.76 3027 ' ' 8 I 1127.14 60.00 240.00 9023.00 3483.30 -3081.21 8.00 279.00 4643.16 End Dir : I I R 14 MD, 9023 TVD - _ ~~... \ -- ----- 13 60.00 240.00 9109.00 3408.82 -3210.20 0.00 0.00 4681.00 9 11299 ~ - . 10 11439.13 60.00 240.00 9179.00 3348.20 -3315.20 0.00 0.00 4711.80 4112" 9~----- - F-02A T F-02A T3 8500 - Plan F-42A,;, Start Dir /100' :10398.21' MD, 8 51 ..... .9'TVD - ---__. .. ^ T F- th :11439 13' MD al De A W P 5 - 179' TVD F-02A 4, - " ~ ~ - - - . , p Bono ° 70 . 3135 , o N -:_..__._. .-. - _.. __T--~ ._ -. -. --- -rr-- ---. -. -. ._-. - _- _..___. 7500 ^-- _... _ -fir-- ... _-- _. T-..__ +~ -~---- -- _. i_.. .. ---- _. -.- _ - - -~- 7000 2743 \_ -~- FORMATION TOP DETAILS - ~ ~ ~ - ~ - - - .- 6500 No. TVDPath MDPath Formation _. _ T- -- -. T~ .__~ -,... ~_ _.. _ ___ - .- I ~, i .. _ End Dir :7643 - 5' MD, 6416.26' TVD _- 0.00 0.00 UG4 -`_" ~'~ ~ - ---r-~-~- ~ ~`1- " I--'- ~ ~ 6500 . 2 0.00 0.00 UG3 ~?- -' - --'T-" - - ~ " -~ -~- ' ' __ - 3 0.00 0.00 UGI ----_ _.---.__-. -.._ _.-.. . __~_+__~_ -.. ~ ~ ~ ~~' 4 0.00 0.00 WS2 ._.. __._ _'_ . - - _._-- ... _-.--~- -. ' -- ' -- .__ 5 5864.00 6755.95 WSI - _. _ ..-~ __..- - --- __. . _. .. _. ~ ~ 00 7067 BG CM3 6 6064 . . 7 7239.00 8721.24 THRZ ___._.- __._..... . - '..' 8 7409.00 8943.96 LCU,BHRZ _ - - ----'~ -- _ .-.._. __ -- 9 7409.00 8943.96 LCU/Top Kingak . _._. ... - . - ._ ~_ 10 7756.00 9398.64 TJF --- -... _. ---..- ..-. 6000'6000 . _ _. - ~ 7919.00 9612.20 T1E _ _- . _ -... - - - ~- - - ___ _ -_ _._ - _--- ~ ~~ T 12 8117.00 9871.63 TJD -~ -~- r- --•- - - ~_-~ --- - ~-_. ~ 13 8364.00 10195.26 TJC _. _ . ` -`1-'-. _. _ .. . - .~- ~-_'-_ -- -,~~.-'-I-*_ __ _ 14 8496.00 10368.21 TJB - --- - ~ ~ --+- - ~ - - --- - - ---- ~ - -~- S Dir 4°1100' :6515' MD 709 83TVD `-~ 15 6654.00 10574.68 Sag River , . __ ,~- ~-~ _ ~ -f ~ ~ 16 8726.00 10669.22 Shublik - - - -. - - .-- -- - 6495' MD 5696 D LTF 85° 2°/100' 2'TVD 17 8774.00 10733.75 TSAD / TZ4B tr : , . --. __ ~,,, Start - ~"~-~ _ IB 8829.00 10810.17 TZ4A,'42N ~ _ 19 8894.00 10905.64 TCGL / TZ3 20 8912.00 10933.45 PGOC ~ 21 8944.00 10984.80 BCGGTZ2 CASING DETAILS 22 8979.00 11044.55 POWC 23 9003.00 11088.35 25N /T2B -3135 -2743 -2351 -1959 -1567 -1176 No. TVD MD Name Size 24 9059.00 11199.13 MHO/HOT I 8654.00 10574.68 7" 7.000 ' West(-)!East(+) [ft] 2 9179.00 11439.13 4 I ~_ 4.500 • Sperry-Sun BP Planning Report 'Company: BP AMOCO Date: 1/22/2007 Time: 15:13:24 Page: 1 Field: Prudhoe Bay Co-ordinate(1VE) Reference: Well: F-42, True North Site: PB F Pad Vertical (TVD) Reference: 38.5GL+28.5K6 64.0 Well: F-42 Section (V5) Reference; Well (O.OON,O.OOE,315.28Azi) Wellpath: Plan F-42A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: F-42A WP 5 Date Composed: 1 /1 212 0 0 7 Version: 22 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNfTED STATES Map SysteniiS State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumiJAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea Level Geomagnetic Model: bggm2006 Site: PB F Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5972527.29 ft Latitude: 70 19 55.283 N From: Map Easting: 650960.70 ft Longitude: 148 46 31.468 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.15 deg Well: F-42 Slot Name: 42 F-42 Well Position: +N/-S 2342.53 ft Northing: 5974904.09 ft Latitude: 70 20 18.320 N +E/-W 1735.10 ft Easting : 652648.18 ft Longitude: 148 45 40.790 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Ho-e Size Name ft ft in in 10574.68 8654.00 7.000 8.500 7" 1 11426.69 9172.78 4.500 6.000 41/2" Formations MD TVD Formations Lithology D'ip'Angle Dip Direction ft ft deg deg._. 0.00 SV4 0.00 0.00 0.00 SV3 0.00 0.00 0.00 SV2 0.00 0.00 0.00 SV1 0.00 0.00 0.00 UG4 0.00 0.00 0.00 UG3 0.00 0.00 0.00 UG1 0.00 0.00 0.00 WS2 0.00 0.00 0.00 Kickoff 0.00 0.00 6755.95 5864.00 WS1 0.00 0.00 7087.86 6064.00 CM3 0.00 0.00 8721.24 7239.00 THRZ 0.00 0.00 8943.98 7409.00 LCUBHRZ 0.00 0.00 8943.98 7409.00 LCU/Top Kingak 0.00 0.00 9398.64 7756.00 TJF 0.00 0.00 9612.20 7919.00 TJE 0.00 0.00 9871.63 8117.00 TJD 0.00 0.00 10195.26 8364.00 TJC 0.00 0.00 10368.21 8496.00 TJB 0.00 0.00 10574.68 8654.00 Sag River 0.00 0.00 10669.22 8726.00 Shublik 0.00 0.00 10733.75 8774.00 TSAD / TZ46 0.00 0.00 10810.17 8829.00 TZ4A/42N 0.00 0.00 10905.64 8894.00 TCGL / TZ3 0.00 0.00 10933.45 8912.00 PGOC 0.00 0.00 10984.80 8944.00 BCGL/TZ2 0.00 0.00 11044.55 8979.00 POWC 0.00 0.00 11088.35 9003.00 25N / T2B 0.00 0.00 11199.13 9059.00 MHOMOT 0.00 0.00 Sperry-Sun BP Planning Report Company: BP Amoco Date: 1!22/2007 Time: 15:13:24 Page: 2 Field: Prudhoe Bay... Co-ordinate(NEJ Reference: WeII:F-42, True North Site: PB F Pad Vertical (TVD) Reference: 38 .5GL+28.5K6 64 .0 W e1L F-42 s S ection (VS) Reference: Wel{ (O.OON,O.OOE,315.28Azi) Wellpath: Plan F-42A S urvey Calculation Method: Minimum'Curvature Db: Oracle Targets Map Map ~---- Latitude ----> <--- Longitude --- Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg M in Sec .Dip..: Dlr. #t ft ft ft ft F-42A T1 8654. 00 3536. 71 -2691. 94 5978385.00 649885.00 70 20 53.098 N 148 46 59.453 W -Plan hit target F-42A T2 8912. 00 3429. 26 -3064. 24 5978270.00 649515.00 70 20 52.040 N 148 47 10.330 W -Plan out by 173. 01 at 8912. 00 3545. 20 -2935. 83 5978388.53 649641.01 70 20 53.181 N 148 47 6.579 W F-42A T3 8979. 00 3401 .30 -3164. 83 5978240.00 649415.00 70 20 51.765 N 148 47 13.270 W -Plan out by 184. 97 at 8979. 00 3515 .15 -3019. 06 5978356.79 649558.41 70 20 52.885 N 148 47 9.011 W F-42A Geopoly 8979. 00 3401 .30 -3164. 83 5978240.00 649415.00 70 20 51.765 N 148 47 13.270 W -Polygon 1 8979. 00 3594 .71 -3427. 97 5978428.00 649148.00 70 20 53.666 N 148 47 20.961 W -Polygon 2 8979. 00 3109 .82 -3292. 80 5977946.00 649293.00 70 20 48.898 N 148 47 17.005 W -Polygon 3 8979. 00 3350 .10 -2615. 72 5978200.00 649965.00 70 20 51.263 N 148 46 57.223 W -Polygon 4 8979. 00 3755 .78 -2741. 50 5978603.00 649831.00 70 20 55.253 N 148 47 0.903 W -Plan out by 184 .97 at 8979. 00 3515 .15 -3019. 06 5978356.79 649558.41 70 20 52.885 N 148 47 9.011 W F-42A T4 9109. 00 3341 .09 -3401. 13 5978175.00 649180.00 70 20 51.172 N 148 47 20.173 W -Plan out by 202 .58 at 9109. 00 3408 .82 -3210. 20 5978246.60 649369.49 70 20 51.839 N 148 47 14.595 W Plan Section Information MD Inc! Azim TVD +N/-S +E/-W l)LS Build Turn TFO Target ft deg ,deg ft ft ft degl1 OOft deg/100ft deg/100ft deg 6495.00 49.32 341.07 5696.82 1964.20 -437.39 0.00 0.00 0.00 0.00 6515.00 49.57 337.93 5709.83 1978.43 -442.71 12.00 1.26 -15.71 -85.00 7215.00 57.22 304.13 6134.79 2398.83 -793.41 4.00 1.09 -4.83 -85.00 7643.25 40.25 300.96 6416.26 2572.30 -1063.09 4.00 -3.96 -0.74 -173.02 10398.21 40.25 300.96 8518.90 3487.92 -2589.63 0.00 0.00 0.00 0.00 10574.68 40.00 290.00 8654.00 3536.71 -2691.94 4.00 -0.14 -6.21 -96.22 F-42A T1 10599.68 40.00 290.00 8673.15 3542.20 -2707.05 0.00 0.00 0.00 0.00 11127.14 60.00 240.00 9023.00 3483.30 -3081.21 8.00 3.79 -9.48 279.00 11299.13 60.00 240.00 9109.00 3408.82 -3210.20 0.00 0.00 0.00 0.00 11439.13 60.00 240.00 9179.00 3348.20 -3315.20 0.00 0.00 0.00 0.00 Survey MD Inc! Azim TVD Sys TVD VS NIS E/W DLS MapN MapE Tool/Co fit deg. deg, ft ft ft ft ft deg/100ft ft ft 6495.00 49.32 341.07 5696.82 5632.82 1703.51 1964.20 -437.39 0.00 5976858.83 652170. 93 Start Dir L 6500.00 49.37 340.28 5700.08 5636.08 1706.93 1967.78 -438.64 12.00 5976862.39 652169.60 MWD+IFR 6515.00 49.57 337.93 5709.83 5645.83 1717.36 1978.43 -442.71 12.00 5976872.95 652165. 32 Start Dir 4 6600.00 49.95 333.50 5764.75 5700.75 1778.14 2037.55 -469.39 4.00 5976931.51 652137. 45 MWD+IFR 6700.00 50.61 328.37 5828.67 5764.67 1852.17 2104.73 -506.75 4.00 5976997.91 652098. 73 MWD+IFR 6755.95 51.08 325.55 5864.00 5800.00 1894.65 2141.09 -530.40 4.00 5977033.78 652074. 35 WS1 6800.00 51.49 323.36 5891.55 5827.55 1928.58 2169.06 -550.38 4.00 5977061.33 652053. 80 MWD+IFR 6900.00 52.58 318.47 5953.09 5889.09 2007.00 2230.21 -600.08 4.00 5977121.45 652002. 87 MWD+IFR 7000.00 53.87 313.74 6012.97 5948.97 2087.06 2287.88 -655.61 4.00 5977177.98 651946. 18 NNVD+IFR 7087.86 55.15 309.72 6064.00 6000.00 2158.43 2335.47 -708.99 4.00 5977224.47 651891. 85 CM3 7100.00 55.33 309.18 6070.92 6006.92 2168.35 2341.81 -716.69 4.00 5977230.64 651884. 02 MWD+IFR 7200.00 56.96 304.78 6126.64 6062.64 2250.48 2391.71 -783.03 4.00 5977279.18 651816. 69 MWD+IFR 7215.00 57.22 304.13 6134.79 6070.79 2262.85 2398.83 -793.41 4.00 5977286.10 651806. 16 MWD+IFR 7300.00 53.84 303.62 6182.89 6118.89 2331.53 2437.89 -851.58 4.00 5977323.96 651747. 22 MWD+IFR 7400.00 49.88 302.96 6244.64 6180.64 2408.45 2481.06 -917.31 4.00 5977365.78 651680. 63 MWD+IFR 7500.00 45.92 302.21 6311.67 6247.67 2480.82 2521.02 -979.80 4.00 5977404.46 651617. 34 MWD+IFR 7600.00 41.96 301.36 6383.67 6319.67 2548.28 2557.59 -1038.76 4.00 5977439.81 651557. 65 MWD+IFR 7643.25 40.25 300.96 6416.26 6352.26 2575.86 2572.30 -1063.09 4.00 5977454.02 651533. 03 End Dir 7700.00 40.25 300.96 6459.57 6395.57 2611.39 2591.16 -1094.53 0.00 5977472.24 651501. 21 MWD+IFR 7800.00 40.25 300.96 6535.89 6471.89 2673.99 2624.40 -1149.94 0.00 5977504.34 651445. 14 MWD+IFR 7900.00 40.25 300.96 6612.21 6548.21 2736.59 2657.63 -1205.35 0.00 5977536.43 651389. 07 MWD+IFR 8000.00 40.25 300.96 6688.53 6624.53 2799.20 2690.87 -1260.76 0.00 5977568.53 651333. 00 MWD+IFR 8100.00 40.25 300.96 6764.85 6700.85 2861.80 2724.10 -1316.18 0.00 5977600.63 651276. 92 MWD+IFR 8200.00 40.25 300.96 6841.18 6777.18 2924.41 2757.34 -1371.59 0.00 5977632.73 651220. 85 MWD+IFR 8300.00 40.25 300.96 6917.50 6853.50 2987.01 2790.57 -1427.00 0.00 5977664.83 651164. 78 MWD+IFR Went Sperry-Sun BP Planning Report Company: BP Amoco Date: 1/22/2007.. "time: 15:13:24 Page: 3 ''Field: Prudhoe Bay C o-ordi nate( NE) Reference: Well: F-42, Tr ue No rth Site: PB FPad V ertical (TVU) Refe rence: 38 .5GL+28.5K6 64. 0 WetL F-42 Section (VS) Reference: WeU (O.OON,O .OOE,315.28Azi) Wellpath : Plan F-42A Survey Calculation Me thod: Minimum Curvature Ub: Oracle Survey MD incl Azim 1'VD Sys TVl) VS N/S E!W DLS MapN MapE Tool/Go ft deg deg ` ft ft ft ft ft deg/1OOft ft ft 8400. 00 40.25 300. 96 6993. 82 6929. 82 3049. 61 2823. 81 -1482. 41 0.00 5977696. 93 651108.71 MWD+IFR 8500. 00 40.25 300. 96 7070. 14 7006. 14 3112. 22 2857. 04 -1537. 82 0.00 5977729. 02 651052.64 MWD+IFR ~ 8600. 00 40.25 300.96 7146. 46 7082. 46 3174. 82 2890. 28 -1593. 23 0.00 5977761. 12 650996.57 MWD+IFR ~ 8700. 00 40.25 300. 96 7222. 79 7158. 79 3237. 43 2923. 52 -1648. 64 0.00 5977793. 22 650940.49 MWD+IFR ~ 8721. 24 40.25 300. 96 7239. 00 7175. 00 3250. 72 2930. 58 -1660. 41 0.00 5977800. 04 650928.58 THRZ 8800. 00 40.25 300. 96 7299. 11 7235. 11 3300. 03 2956. 75 -1704. 05 0.00 5977825. 32 650884.42 MWD+IFR 8900. 00 40.25 300. 96 7375. 43 7311. 43 3362. 63 2989. 99 -1759. 46 0.00 5977857. 42 650828.35 MWD+IFR 8943. 98 40.25 300. 96 7409. 00 7345. 00 3390. 17 3004. 60 -1783. 83 0.00 5977871. 53 650803.69 LCU/Top 9000. 00 40.25 300. 96 7451. 75 7387. 75 3425. 24 3023. 22 -1814. 87 0.00 5977889. 51 650772.28 MWD+IFR 9100. 00 40.25 300. 96 7528. 08 7464. 08 3487. 84 3056. 46 -1870. 28 0.00 5977921. 61 650716.21 MWD+IFR 9200. 00 40.25 300. 96 7604. 40 7540. 40 3550. 45 3089. 69 -1925. 69 0.00 5977953. 71 650660.14 MWD+IFR 9300. 00 40.25 300. 96 7680. 72 7616. 72 3613. 05 3122. 93 -1981. 10 0.00 5977985. 81 650604.06 MWD+IFR 9398. 64 40.25 300. 96 7756. 00 7692. 00 3674. 80 3155. 71 -2035. 76 0.00 5978017. 47 650548.76 TJF 9400. 00 40.25 300. 96 7757. 04 7693. 04 3675. 65 3156. 16 -2036. 51 0.00 5978017. 91 650547.99 MWD+IFR 9500. 00 40.25 300. 96 7833. 36 7769. 36 3738. 26 3189. 40 -2091. 92 0.00 5978050. 01 650491.92 MWD+IFR 9600. 00 40.25 300. 96 7909. 69 7845. 69 3800. 86 3222. 63 -2147. 34 0.00 5978082. 10 650435.85 MWD+IFR ' 9612. 20 40.25 300. 96 7919. 00 7855. 00 3808. 50 3226. 69 -2154. 10 0.00 5978086. 02 650429.01 TJE 9700. 00 40.25 300. 96 7986. 01 7922. 01 3863. 46 3255. 87 -2202. 75 0.00 5978114. 20 650379.78 MWD+IFR ' 9800. 00 40.25 300. 96 8062. 33 7998. 33 3926. 07 3289. 11 -2258. 16 0.00 5978146. 30 650323.71 MWD+IFR ' 9871. 63 40.25 300. 96 8117. 00 8053. 00 3970. 91 3312. 91 -2297. 85 0.00 5978169. 29 650283.54 TJD 9900. 00 40.25 300. 96 8138. 65 8074. 65 3988. 67 3322. 34 -2313. 57 0.00 5978178. 40 650267.63 MWD+IFR ' 10000. 00 40.25 300. 96 8214. 97 8150. 97 4051. 28 3355. 58 -2368. 98 0.00 5978210. 50 650211.56 MWD+IFR ' 10100. 00 40.25 300. 96 8291. 30 8227. 30 4113. 88 3388. 81 -2424. 39 0.00 5978242. 59 650155.49 MWD+IFR ' 10195. 26 40.25 300. 96 8364. 00 8300. 00 4173. 52 3420. 47 -2477. 17 0.00 5978273. 17 650102.08 TJC 10200. 00 40.25 300. 96 8367. 62 8303. 62 4176. 48 3422 .05 -2479. 80 0.00 5978274. 69 650099.42 MWD+IFR ' 10300. 00 40.25 300. 96 8443. 94 8379. 94 4239. 09 3455 .28 -2535. 21 0.00 5978306. 79 650043.35 MWD+IFR 10368. 21 40.25 300. 96 8496. 00 8432. 00 4281. 79 3477 .95 -2573. 01 0.00 5978328. 69 650005.10 TJB 10398. 21 40.25 300. 96 8518. 90 8454. 90 4300. 57 3487 .92 -2589. 63 0.00 5978338. 32 649988.28 Start Dir 4 10400. 00 40.24 300. 85 8520. 26 8456. 26 4301. 69 3488 .52 -2590. 62 4.00 5978338. 89 649987.27 MWD+IFR ' 10500. 00 39.98 294. 65 8596. 77 8532. 77 4363. 06 3518 .49 -2647. 58 4.00 5978367. 69 649929.73 MWD+IFR ' 10574. 68 40.00 290. 00 8654. 00 8590. 00 4407. 23 3536 .71 -2691. 94 4.00 5978385. 00 649885.00 F-42A T1 10599. 68 40.00 290. 00 8673. 15 8609. 15 4421. 76 3542 .20 -2707. 05 0.00 5978390. 19 649869.79 Start Dir 8 10600. 00 40.00 289. 96 8673. 40 8609. 40 4421. 94 3542 .27 -2707. 24 8.06 5978390. 26 649869.59 MWD+IFR ' 10669. 22 41.18 281. 64 8726. 00 8662. 00 4461. 05 3554 .48 -2750. 50 8.00 5978401. 57 649826.10 Shublik 10700. 00 41.88 278. 08 8749. 05 8685. 05 4477. 68 3557 .96 -2770. 60 8.00 5978404. 65 649805.93 MWD+IFR ' 10733. 75 42.78 274. 30 8774. 00 8710. 00 4495. 30 3560 .41 -2793. 19 8.00 5978406. 63 649783.30 TSAD / TZ 10800. 00 44.89 267. 27 8821. 82 8757. 82 4527. 95 3560 .98 -2839. 01 8.00 5978406. 27 649737.48 MWD+IFR 10810. 17 45.25 266. 24 8829. 00 8765. 00 4532. 72 3560 .57 -2846. 20 8.00 5978405. 72 649730.30 TZ4A/42N 10900. 00 48.80 257. 69 8890. 29 8826. 29 4571. 78 3551 .26 -2911. 12 8.00 5978395 .09 649665.59 MWD+IFR 10905. 64 49.04 257. 19 8894. 00 8830. 00 4574. 05 3550 .34 -2915. 28 8.00 5978394 .08 649661.45 TCGL / TZ 10933. 45 50.27 254. 75 8912. 00 8848. 00 4584 .85 3545 .20 -2935. 83 8.00 5978388 .53 649641.01 F-42A T2 10984. 80 52.67 250. 49 8944. 00 8880. 00 4603 .27 3533 .18 -2974. 14 8.00 5978375 .73 649602.95 BCGL/T22 11000. 00 53.41 249. 28 8953. 14 8889 .14 4608 .33 3529 .00 -2985. 54 8.00 5978371 .32 649591.64 MWD+IFR 11044 .55 55.64 245. 86 8979. 00 8915 .00 4622 .07 3515 .15 -3019 .06 8.00 5978356 .79 649558.41 F-42A T3 11088 .35 57.92 242. 68 9003. 00 8939 .00 4633 .98 3499 .24 -3052 .06 8.00 5978340 .22 649525.75 25N / T26 11100 .00 58.54 241 .87 9009 .13 8945 .13 4636 .87 3494 .63 -3060 .82 8.00 5978335 .43 649517.08 MWD+IFR 11127 .14 60.00 240 .00 9023 .00 8959 .00 4643 .16 3483 .30 -3081 .21 8.00 5978323 .68 649496.93 End Dir 1 11199 .13 60.00 240 .00 9059 .00 8995 .00 4659 .00 3452 .12 -3135 .20 0.00 5978291 .42 649443.59 MHO/HOT 11200 .00 60.00 240 .00 9059 .43 8995 .43 4659 .19 3451 .75 -3135 .86 0.00 5978291 .03 649442.94 MWD+IFR 11299 .13 60.00 240 .00 9109 .00 9045 .00 4681 .00 3408 .82 -3210 .20 0.00 5978246 .60 649369.49 F-42A T4 11300 .00 60.00 240 .00 9109 .43 9045 .43 4681 .19 3408 .45 -3210 .86 0.00 5978246 .21 649368.85 MWD+IFR 11400 .00 60.00 240 .00 9159 .43 9095 .43 4703 .19 3365 .15 -3285 .86 0.00 5978201 .40 649294.75 MWD+IFR lent ak i 2 Sperry-Sun BP Planning Report Company: BP AmoCO Da e: 1/22!2007 'Cime: 15:13:24 Page: 4 Field: , ; Prudhoe Bay Co-ordinate(NE) Reference: Well: F-42, True North Slte: PB F Pad Vertical (TVll) Reference: 38.5GL+28.5K6 64.0 Well: F-42: - Section (VS) Reference: Well (O.OON,O.OOE,315.28Azi) Wellpat6: Plan F-42A Survey Calculation"Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD' VS N/S E/W DLS MapN MapE Tool/Co ft deg deg ft ft ` #t ft ft deg/1pOft ft ft 11426.69 60.00 240.00 9172.78 9108.78 4709.06 3353.59 -3305.87 0.00 5978189.44 649274.97 41/2" 11439.13 60.00 240.00 9179.00 9115.00 4711.80 3348.20 -3315.20 0.00 5978183.86 649265.75 Total Dep rent wLU.IxrAUS ANTI-COLLISION SEiTW G5 c'OMPANV E>erAUS 8111EVtiY PRExiRnM Interpolation Method:MD Interval. 511.(1(1 ~n4N-3 I]Fs-U s'>avllna r~i es.ws~_tx ]u-zo.ww~de w~umo smt Hr nm raym Fm rknlo T" saf~y/rt~o root - 1 . 2uN 14e 4s'4nrMw 4z Depth Range From: 64v5.(MI To: 1143Y.13 raL la M ma m r' ~;mw ra'n1a 1 wni.ll 1,.,~ .~: r-sn wr s v„ Mwu~ u~R~MR Maximum Rmge: 1341.116 Reference: Plan: F-42A WP 5 1 vy 7w. Ixrwxn t.,w Me1hUd. Ira« (Ylwilu N•~M I:UUr xmlasc. IJLtvW ~ t'aswg Wuuwg Mcth~d: Rules HmcJ 160 150 100 0 'ololu To MD - 6500 - 6750 - 7000 - 7250 7500 - 7750 8000 - 8250 8500 - 8750 - 9000 -- 9250 - 9500 - 9750 • 00 25 50 60 Removed. ;an for Plans ` le @ No Errors wuJ.PnTU uerAlu Pfau r-02A Par~vl WcRIWt Y-02 1 ie ou MU: 69YSA]0 Rig: ReE. fArum: 3RSGL+283KR W.Wfl V k W«e rkigm rxFO 5Wheg nogi ~w;; .Hr-w FrUm TVu ns.zx o.W o.W zxso - u16Iw61, nlarrr wsk F4N (FLLA4 Maf11r Risk F-141h-14A Mapr Nsk F-I`1 IF-1')1. Maprt lEisk F-_'1 Ih-_'1), Mi1X~I Risk - F-_'l rtll (F-_'1I'HII_MaNrr Risk Fa41r-241, nfan•r Rut r-r aa21. Map•r wst h-n Ire r-nnl. Mayer tad F-?4A IF-i4A1, Mayer RUk F-i4APH1 (F-34APPI1. MaF'r Rrck F-?i 1F-141. Mawr Riak F-341E-?4N I. Maher RUk F-?fi IF-iGl, Mar'r Risk E'-?] lF-3]F Alay~r Risk F-41 1F-411. Mayv Risk F-0IrHI IF-0IPHII. Maier Risk F-4'_ (F-4'_I, NOIiRRORB Plau Grassnuitl l(-uasm~uls), Maprt Risk Plan F-42A - F-42A WP5 loc Aa NU .N/-8 ~H'-W day TFa~:u VSa Targn 4) i2 t41 p] 56v6.x2 1'164'_0 d371'I U.q) HW 170351 dU.S] 3?7!)3 5711Y.R3 1'1]R.43 -4d~71 12.W -85.W 171]16 57.22 304.13 6134.70 2308.81 -'ry3.41 4.W -85W 3262.85 40.'5 3W.Y6 Li1626 _'57210 -10(rl,W 4.W -173.0_' '_575.8fi 411.25 3110 lM 8518.W 3487.Y2 ?SN)_Ll U.W U.W S1W.5] 4U.W 2SU.W W.W 2W.W 8654.W 8(73.15 3536.71 3542 _'U ~L 11.V4 +]11].05 4.W +M 2'_ U.W O.W NU'!.'_3 F-0'_A'rl d4'_I ]( N).W 24U.g1 W23.IIU 348330 -108121 8.W '_7'1.W 4W1.16 W.W '_W.ql YI W.W 3408%'_ -3?Ill2U O.W U.W 4(dlW IU 1143`1.13 W.W 240.W Y17'/.ql 3348.+0 -1315.'_0 U.W U.W 4711 AU Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] Sperry-Sun Anticollision Report `.Company: BP Amoco Date: 1/22/2007 Time: 15:06:16 Page: 1 Field: Prudhoe Bay Reference Site: PB'F Pad Co-ordinate(NE) Reference: Well: F-42, True North Reference Well: F-4Z Vertical (TVD) Reference: 38.5GL+28.5KB 64.0 Reference WellpatlPJan F-42A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - TReie~aaec'FIGHT ~fl+ihcipakRlarfi~lBLANNED PROGRAM Interpolation MethodMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 6495.00 to 11439.13 ft Scan Method: Trav Cylinder North Maximum Radius1341.06 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/4/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 33.49 6495.00 1 : Schlumberger GCT multishot (33.49-118~78~11D Schlumberger GCT multishot 6495.00 11439.13 Planned: F-42A WP 5 V22 MWD+IFR+MS MWD + IFR + Mufti Station Casing Points MD TVD Diameter' Hole Size Name fY ft in in 10574.68 8654.00 7.000 8.500 7" 111426.69 9172.78 4.500 6.000 41/2" Summary ~----°--- ----------- Offset Wellpath ----------------------> Site Weft. Wellpath.. PB F Pad F-06 F-06 V1 PB F Pad F-06 F-06A V2 PB F Pad F-14 F-14 V1 PB F Pad F-19 F-19 V4 PB F Pad F-21 F-21 V1 PB F Pad F-21 P61 F-21 P61 V1 PB F Pad F-24 F-24 V1 PB F Pad F-32 F-32 V1 PB F Pad F-33 Plan F-33A VO Plan: F- PB FPad F-34A F-34A V1 PB F Pad F-34APB1 F-34APB1 V1 PB F Pad F-34 F-34 V1 PB F Pad F-34 F-348 V3 PB F Pad F-36 F-36 V1 PB F Pad F-37 F-37 V1 PB F Pad F-41 F-41 V1 PB F Pad F-41P61 F-41PB1 V2 PB F Pad F-42 F-42 V1 PB F Pad Plan Grassroots Grassroots V1 Plan: Gr __-_ Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deevjation Warning ft ft ft ft ft 10454.36 10650.00 927.55 484.40 443.15 Pass: Major Risk 9312.35 9300.00 861.79 207.58 654.21 Pass: Major Risk 6503.96 6550.00 457.32 151.09 306.23 Pass: Major Risk 6508.71 7050.00 1057.13 140.18 916.95 Pass: Major Risk 9280.57 9300.00 253.89 146.86 107.03 Pass: Major Risk 7925.83 8150.00 276.71 188.65 88.06 Pass: Major Risk 7500.00 6850.00 1340.90 151.03 1189.88 Pass: Major Risk Out of range 6495.97 6400.00 687.78 129.69 558.09 Pass: Major Risk 6498.74 7000.00 1040.00 114.81 925.20 Pass: Major Risk 6498.74 7000.00 1040.00 114.81 925.20 Pass: Major Risk 6498.73 7000.00 1040.42 114.82 925.60 Pass: Major Risk 6499.17 7000.00 1041.07 114.82 926.25 Pass: Major Risk Out of range 11387.33 10150.00 1083.51 148.22 935.29 Pass: Major Risk Out of range Out of range 6497.39 6500.00 0.01 0.65 -0.64 FAIL: NOERRORS Out of range Site: PB F Pad Well: F-06 Rule Assigned: Major Risk Wellpath: F-O6 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/HBistanceArea Deviation Warning ' ft ft ft ft ft ft deg deg in ft ft ft 8144.28 6798.65 7850.00 6972.13 17.21 113.38 198.80 257.84 9.625 1336.82 349.80 987.01 Pass 8189.78 6833.38 7900.00 7016.73 17.29 114.41 198.03 257.07 9.625 1326.46 349.41 977.05 Pass 8235.26 6868.09 7950.00 7061.03 17.38 115.44 197.26 256.30 9.625 1315.74 348.93 966.81 Pass 8280.71 6902.78 8000.00 7105.07 17.47 116.52 196.48 255.53 9.625 1304.72 348.43 956.30 Pass 8326.11 6937.42 8050.00 7148.91 17.56 117.61 195.70 254.75 9.625 1293.49 347.79 945.71 Pass 8371.44 6972.03 8100.00 7192.51 17.66 118.74 194.92 253.96 9.625 1282.00 347.08 934.92 Pass 8416.72 7006.58 8150.00 7235.84 17.75 119.88 194.12 253.17 9.625 1270.21 346.23 923.97 Pass 8461.87 7041.04 8200.00 7278.92 17.85 121.06 193.32 252.36 9.625 1258.08 345.25 912.84 Pass 8506.84 7075.36 8250.00 7321.78 17.95 122.25 192.50 251.54 9.625 1245.62 344.05 901.57 Pass 8551.60 7109.53 8300.00 7364.35 18.06 123.48 191.66 250.70 9.625 1232.73 342.64 890.10 Pass 8596.16 7143.53 8350.00 7406.58 18.16 124.71 190.80 249.85 9.625 1219.35 341.00 878.35 Pass 8640.48 7177.36 8400.00 7448.46 18.27 126.00 189.93 248.97 9.625 1205.47 339.13 866.34 Pass 8684.54 7210.99 8450.00 7489.97 18.38 127.30 189.03 248.07 9.625 1191.11 336.99 854.11 Pass 8728.39 7244.45 8500.00 7531.09 18.49 128.66 188.11 247.16 9.625 1176.28 334.62 841.66 Pass 6050000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 Alaska Department of Naturalources Land Administration System :r~;~ ._~,~r,~.~ ,°. ~ ;is ~ ~°:'er' Search State Cabins Page 1 of 2 ~i~tur~all~~ur~es Alaska DNR Case summary File Type ADS File Number 28278 o~- Printable Case F. le Summary See Township, Range, Section and Acreage? New Search_~ Yes ~3 No -- - _ . ___ I bS itnensa ~ Case Abstract ~ Case Detail ~ Land Abstract ., File: :1UL. 28278 ~ "' Search for Status Piat Updates ,~ cal lUiO~'?007 Customer: 00010? 7? 13P L;XPLORATION (<1.L,1SKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Ti~pe: r~~ OIL &GAS LEASE COMP DNR Unit: 780 OILAND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 ~fflCP Of Prln2ary ReS~0ilSlblltly: DOCi DIV I II. AND GAS Last Transaction Date: 12/04/2006 Case SubtyTe : ~~S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED a~Jel'lljlall: 1_~~ 1~)lt'11S~11C~.~ ~)~~~ RCUl~'~e: O1_~E: ,~~'CllOil: ~~ ~SeC'Ii0/1,-ICl'N,S: 640 SBBrCh f='{atS 11'1"l~~lclll.~ ~_~ I Ull'ni'{ll~): 0~ ~~ ~~C]i7~re.~ ~) ~ ~ f~ .~~NCIlU71: ~'S .~~eC~lU1Y . ~CPE.~': ~)~~) Mrt~i~Iiw~.~ U 7uic~r.clti~>: 012N Ru»~re.~ UI ;1. .S'e~criun: ~3 .5'rctrun ~lcrcr~~: 640 111e~rrdiurl: [ ~ 7~nti~n.chi~~: 012N 1~~o~;~c': 013E .1'c~ctior~: >-1 ,~'r~clrnn ~Jcres: 640 Leal I)cscription OS-28-1965 * * * SALE NOTICE LEGAL DESCRIPTION C14- 89 T12N, R13E, UM27, 28, 33, 34 2,.560.00 ~r~d 4 Case Summary Last updated on 07/05/2007. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28278&... 7/5/2007 • Terri L. Hubble BP Exploration AK Inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF "Mastercard Check" 89-6/1252 343 DATE ' ~ -~ .s I ~~. °~ DOLLARS First National Bank Alaska Anchorag~K~5~ MEMO ~~_ ~:L25200060~:99Lti6227L556~1' 0343 • • T~4~YS1~TI~'TAL L,E~'~'ETd CHECKLIST WELL NA 1~tE ~~~ ~- '71v~,q P't'D# 0~0 ~Dy~30 = Development Service Ex local iYoa-Conventional Wet[ p ory. Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included is Transmittal Letter CHECK w'HAT APPLIES ADD-ONS (OPTIONS) MliLTt LATERAL j (If fast two digits ~ API number ;between 60-69) PILOT HOLE ' i I SPACIIYG EXCEPTION DRY DITCH SA!~IPLE i The permit is for a new wet(bore segment of existing ~ well j in ~ Permit No. are , AP[ No. 50- _ _ Production should continue to be reported as a function of the ;~ original API number stated above. In accordance with 20 A..4C 25.005 ~~ acquired for the pilot hate must be c early differentated~n both well name (50~ Pt-I) and AP[ number acquired for well --~ fr°m records, data and logs The permit is approved subject to full compliance with 20 AAC I 25.055. Approval to perforate and oroduce /infect is contingent upon issuance of a conservation order approving a spacing exception. tiabi[ity of any protest to the spacing exception that may occurs the I ~ Alt dry ditch sample sets submitted to the-Eommission must be in i no greater than 30' sample intervals from below the permafrost or I from where samples are first caught and t 0' sample intervals j through target cones. i i Non-Conventional j Well i TEXT FOR APPROVAL LETTER j Please note the following special condition of this i permit: ~ production or production testing of coal bed methane is not allowed for (name of welh until after (Cotnpanv Name} has designed and I implemented a water well testing program to provide baseline data on water quality and quantity. (Comnanv Name) must contact the Commission to obtain advance approval of such water well testing grogram. 1 Rev: ! 23/U6 C:'jody~transmittat_checkl ist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 Well Name: PRUDHOE BAY UNIT F-42A .Program DEV Well bore seg ^ PTD#:2070930 C°mpany BP EXPLORATION (ALASKA) INC Initial Class/Type DEV! PEND GeoArea 89D Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Pe[mitfee attached- - - - - - - YeS - - - - - 2 Lease number appropriate______- ---------------------------- Yes - _________________ - - - 3 Unique well-name andnumbe[ -- --- - - -- -- - - -- Yes--- - -- ----- --- - -- ------- -- --- --- --- -- - ---- -- -- 4 Well located in.a_defined pool - - Yes 5 Well locatedp[operdistancefromdrillingunit_bounda_ry________________ ______ Yes______ ___---_..__-.__---_--__--__--__-_-.--._--.-___-_--__-_--_-_--..--- 6 Well located proper distance from other wells- - - - - - - - - - - - - - - _ _ - . - _ _ _ - - - - _ Yes - - - - _ _ _ - - 7 Suffcientacreage_avail_ablein_drillingunit________________________- .-... Yes______ ---...._--_-_-_--_---___-.__.-_---_ -__--__--__--_---- - 8 If deviated,is_wellboreplat_included__________-..-_-----__-__. _-__ Yes------ ---------------------------_-_--_--__ 9 Operator only affected party- - - - - Yes - - - - - - - 10 T Operator has appropra]e-bondin force-_________-- •______________ ______ Yes_______ BlanketBond#6194193----------_____--.---_--_--__.__.._. 11 Permitcanbeissuedwithoutconsen!ationorder---------------------- - ----Yes_----- -_-________________-___-__------_---_--__--__- ---------------------- Appr Date 12 Permit can be issued _w_ithout administrative_approyal - Yes _ - - - - ACS 7/5/2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_Injection Order# (put_1O# in.comments)_(F°r_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ ..... _ _ _ _ _ - - - - . - - . 15 All wells-within 114-mile area-ofreyiewidentified(For service well only)--_--__- ------ NA-------- ----------------------___._________.___________....--_.__..____._. 16 Pre-produced injector; durati°n_of pr_e production less than 3 months-(For service well only) _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ - - .... _ _ - _ - _ _ _ _ - - 17 Nonconyen, gas conforms to A$31.05,030Q.1-.A).(1.2.A-D) - NO - - - - Engineering 18 --- Canductorstring_p_rovided---------------------_-_______-_-. ---___ NA_____--- Conductor_setinF-42(1.90-158).-----------____ _______-___ 19 Surfacecasingprotectsall-knownUSDWs____________________--.- --.--- NA_______- All aquifers exempted,AEO1.__-___-_--___ ----_______--_-----__..-..--..--. 20 CMT-voladequate tocircul_afe-on conductor&surf_csg__ ______________ _-...-NA_______ Surface casing set inF-42. ___________---.- .--------____________-__-_ 21 CMT_voladeguate_totie-in.longstringtosurfcsg________________-.. -_ -__ NA_____--- Intermediate casing set in_F-42.----------____ _------.------- 22 CMT-willcoyer_allknow_n_productiye horizons_______________________ Yes_______ _____ __--._-_-.-----_____---_--.-... __.___--_--__ __-_------ --_ 23 Casing designs adequate for C,-T,B&-permafrost----- -------------- -- ---Yes------ ----- ---------.--.----------- ------------.------ -------------- 24 Adequate tankage:or reserve pit - Y_es - - Rig is-equipped with steel_pits. No reserve-pR-planned, All waste to_approved disposal well(s).- - - - - - - - 25 Ifa_re-drill,has-a10-403 for abandonment been approved_-_____--__ __ --_ Y_es------- 307-224____________________________________________________________ __ ' 26 Adequate wellboreseparation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - _ _ _ - _ Proximity analysis performed, Traveling cylinder path calculated, - _ - - - _ - - - _ - - _ - - - - - - _ _ . _ - - _ - 27 If_diverterrequired,doesitrneetregulations_________________________ __ ___ NA--______ BOf?st_ack_willalready-be-in place,____________-.--- -_-___..-_.--.__-__--_-- --- Appr Date 28 Drilling fluid_ program schematic-& equip list_adequate_ - - - - - - - Yes Maximum expected formation pressure 8.4_ EMW in 8-1/2".hole, Planned-MW up to 11.0 ppg in 8-112"_ hole_and 8._ TEM 71512007 29 BOPEs,_tl_otheymeetregulation_______________________----__ ______Yes_-_--- ---RP9inzone.__________---------________________________--__-_..--._.. . ~A/~ ~ 30 BOPS-press rating appropriate; test to-(pu_t prig i_n comments)- - - - - - - - - - - - - - - - - - - -Yes - _ _ _ _ _ _ MASP calculated-at 2882psi, 3500_psi_ BOP testproposed.- - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ /- r 1 131 Choke-manifold complies w/APL Rf?-53 (May 84) Yes - - - - - - (J j32 WorkwilLoccurwith_outoperationshutd°wn------------------------- ------Yes------ ----------------. ------------------------------------------------ ~33 Is presence of H2S gas_ probable- - - . - - _ Yes - H2S is reported-on F-pad.- Mud should preclude H2S on_ rig, Righas sensors and alarms._ 34 Mechanical-condition of wells within AOR verified (For service wel_I only) NA - - - - Geology ~35 - Permit can be issued w/o hydrogen sulfide measures No_ Well F-24=100ppm H2S;Max reading F-24 & F-391DOppm H2s on 6115!98. F-pad is not a_H2S_pad. - - - - - - - - 36 Data-presented onpotentia_IoverPressur_ezones_-___-_ ------------- NA____ ___------.-____-______-.....---____________________ ____ Appr Date 37 Seismic-analysis of shallowgas_zones. - - NA - - -- ACS 71512007 38 Seabed condition survey-(if off-share) NA j39 Contact name/phone forweekly_progress reports-[exploratory only] Yes - _ _ Kris-Honas 564-4338 Geologic Commissioner: Engineering Public Date: Commissioner: Date Co Date pis 0617 C>G~~-~6~~~ ~-6-d~ • Well I-iistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special-effort has been made to chronologically . organize this category of information. ~ ~ f-42a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 12 11:05:57 2008 Reel Header service name .............LISTPE Date . ...................08/05/12 Ori9in ...................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 . ...................08/05/12 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: F-42A API NUMBER: 500292210801 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 12-MAY-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: Mw0005193678 Mw0005193678 Mw0005193678 LOGGING ENGINEER: SHAWN POLAK SHAWN POLAK SHAWN POLAK OPERATOR WITNESS: BILL DECKER BILL DECKER BLAIR NEWLAN MWD RUN 4 MAD RUN 4 JOB NUMBER: Mw0005193678 Mw0005193678 LOGGING ENGINEER: SHAWN POLAK SHAWN POLAK OPERATOR WITNESS: BLAIR NEWLAN BLAIR NEWLAN SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 13E FNL: 1910 FSL: FEL: 2173 FWL: Page 1 t ~ f-42a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 67.06 GROUND LEVEL: 38.56 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 6463.0 2ND STRING 6.125 7..000 10598.0 3RD STRING PRODUCTION STRING REMARKS: 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 EXITS THE F-42 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 6463'MD/5677'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). ONLY SROP AND SGRC DATA ARE PRESENTED FOR MWD RUN 1. MWD RUNS 1,2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 3,4 ALSO INCLUDED AT-BIT INCLINATION (ABI), COMPENSATED THERMAL NEUTRON (CTN), AND AZIMUTHAL LITHO- DENSITY (ALD). UPHOLE MAD SGRC TIE-IN DATA ACQUIRED WHILE POOH AFTER RUN 2 WERE MERGED WITH RUN 1 MWD DATA. ROTATED MAD PASS POROSITY DATA ACQUIRED WHILE POOH AFTER REACHING FINAL TD ARE PRESENTED SEPARATELY. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A HALLIBURTON CASED-HOLE GAMMA RAY LOG RUN IN F-42 ON 7 JANUARY 1991. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D. DORTCH ON 23 APRIL 2008, QUOTING AUTHORIZATION .FROM ROGER SELS (BP). THE SHIFTED MWD DATA ARE CONSIDERED PDC FOR F-42A. 6. MWD RUNS 1-4 REPRESENT WELL F-42A WITH API#: 50-029-22108-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11360'MD/9150'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA Page 2 ~ ~ f-42a.tapx 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 (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4-8.5 PPG MUD SALINITY: 3700-4700 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 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 6331.5 11286.5 FET 6439.0 11293.5 RPD 6439.0 11293.5 RPX 6439.0 11293.5 RPS 6439.0 11293.5 RPM 6439.0 11293.5 ROP 6457.5 11352.5 FCNT 10499.5 11258.0 NCNT 10499.5 11258.0 NPHI 10499.5 11258.0 RHO6 10514.0 11273.5 Page 3 f-42a.tapx DRHO 10514.0 11273.5 PEF 10514.0 11273.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 6331.5 6338.5 6333.5 6340.5 6336.5 6343.5 6339.0 6347.0 6342.5 6350.5 6353.5 6361.0 6366.0 6373.5 6370.0 6378.5 6390.5 6398.0 6394.5 6401.5 6402.5 6410.0 6416.0 6425.0 6421.5 6429.0 6430.5 6439.0 6451.0 6458.5 6455.5 6463.0 6457.0 6464.5 11352.5 11360.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 6338.5 6499.0 MwD 2 6499.0 10600.0 MWD 3 10600.0 10919.0 MwD 4 10919.0 11360.0 REMARKS: MERGED MAIN PASS. 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 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 Page 4 f-42a.tapx PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD Pu-s 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6331.5 11352.5 8842 10043 6331.5 11352.5 FCNT MWD CP30 111.9 3073.11 721.047 1518 10499.5 11258 NCNT MWD CP30 14266.4 49083.5 28115.8 1518 10499.5 11258 RHOB MWD G/CC 0.718 3.502 2.37279 1520 10514 11273.5 DRHO MWD G/CC -3.047 1.052 -0.0365888 1520 10514 11273.5 RPD MWD OHMM 0.5 2000 26.1054 9710 6439 11293.5 RPM MWD OHMM 0.62 2000 15.748 9710 6439 11293.5 RPS MWD OHMM 0.67 1863.09 6.07471 9710 6439 11293.5 RPX MWD OHMM 0.66 1862.87 5.67525 9710 6439 11293.5 FET MWD HR 0.27 133.37 3.24324 9710 6439 11293.5 GR MWD API 5.97 524.28 103.035 9911 6331.5 11286.5 PEF MWD B/E 1.31 15.15 3.74118 1520 10514 11273.5 ROP MWD FPH 0.03 260.75 102.189 9791 6457.5 11352.5 NPHI MWD Pu-s 5.74 59.32 24.4829 1518 10499.5 11258 First Reading For Entire File..........6331.5 Last Reading For Entire File...........11352.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 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.......08/05/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI PEF and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10568.0 10568.0 10568.0 10584.0 STOP DEPTH 11144.0 11144.0 11144.0 11162.0 Page 5 • f-42a.tapx DRHO 10584.0 11162.0 RHOB 10584.0 11162.0 GR 10597.0 11170.5 FET 10604.0 11177.0 RPx 10604.0 11177.0 RPS 10604.0 11177.0 RPM 10604.0 11177.0 RPD 10604.0 11177.0 RAT 10662.0 11228.5 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS N0. MERGE TOP MERGE BASE MwD 4 1 10575.5 11236.0 S REMARKS: MERGED MAD PASS. Data Format specific ation Record Data Record Type. .. ..... .....0 Data specificatio n Block Type .....0 Logging Direction ............ .....DOwn optical log depth units...... .....Feet Data Reference Po int ......... .....undefined Frame Spacing.... ... ....... .....60 .lIN Max frames per re cord ........ .....undefined Absent value ..... ............ .....-999 Depth units. .. .. ..... Datum specificati on Block sub -type...0 Name service order units size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10568 11228.5 10898.3 1322 10568 11228.5 FCNT MAD CP30 115.67 3849.65 867.338 1153 10568 11144 NCNT MAD CP30 14616.4 52341.6 30856.2 1153 10568 11144 RHOB MAD G/CC 1.775 3.435 2.4404 1157 10584 11162 DRHO MAD G/CC -0.843 0.581 0.0770804 1157 10584 11162 RPD MAD OHMM 0.24 2000 41.5241 1147 10604 11177 RPM MAD OHMM 0.2 1557.01 29.9397 1147 10604 11177 RPS MAD OHMM 0.27 1261.53 23.7454 1147 10604 11177 RPx MAD OHMM 0.31 146.46 17.4863 1147 10604 11177 FET MAD HR 8.18 51.02 29.6307 1147 10604 11177 GR MAD API 5.14 234.5 27.2286 1148 10597 11170.5 PEF MAD B/E 1.3 13.2 2.8986 1157 10584 11162 Page 6 f-42a.tapx RAT MAD FPH 0.23 1678.8.4 249.964 NPHI MAD PU-S 4.48 60.94 21.4683 First Reading For Entire File..........10568 Last Reading For Entire File...........11228.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSL2B.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.002 comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6338.5 ROP 6465.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 1134 10662 11228.5 1153 10568 11144 header data for each bit run in separate files. 1 .5000 3 STOP DEPTH 6431.5 6499.0 09-AUG-07 Insite 72.13 Memory 6499.0 6463.0 6499.0 49.2 49.2 TOOL NUMBER 143126 Page 7 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): f-42a.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........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 • 8.500 6463.0 Fresh water Gel 8.80 53.0 9.7 1000 11.0 .000 .0 .000 60.0 .000 .0 .000 .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 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6338.5 6499 6418.75 322 6338.5 6499 GR MWDO10 API 36.33 75.28 51.0359 187 6338.5 6431.5 ROP MWDO10 FPH 0.03 71.5 12.8717 69 6465 6499 First Reading For Entire File..........6338.5 Last Reading For Entire File...........6499 File Trailer Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Page 8 • • f-42a.tapx Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/05/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6432.0 RPM 6447.0 RPS 6447.0 FET 6447.0 RPX 6447.0 RPD 6447.0 ROP 6499.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 STOP DEPTH 10555.0 10547.5 10547.5 10547.5 10547.5 10547.5 10600.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): Page 9 12-AUG-07 Insite 10919 Memory 10600.0 6499.0 10600.0 38.4 54.0 TOOL NUMBER 143126 96540 8.500 6463.0 Polymer 11.00 f-42a.tapx MUD VISCOSITY (S): 52.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.590 69.4 MUD AT MAX CIRCULATING TERMPERATURE: .710 163.0 MUD FILTRATE AT MT: 1.320 72.0 MUD CAKE AT MT: 1.720 69.7 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 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6432 10600 8516 8337 6432 10600 RPD MWD020 OHMM 0.88 2000 9.80564 8202 6447 10547.5 RPM MWD020 OHMM 0.83 2000 5.31654 8202 6447 10547.5 RPS MWD020 OHMM 0.86 1863.09 3.13267 8202 6447 10547.5 RPX MWD020 OHMM 0.83 1862.87 3.14333 8202 6447 10547.5 FET MwD020 HR 0.27 32.15 1.48147 8202 6447 10547.5 GR MWD020 API 36.27 373.25 114.465 8247 6432 10555 ROP MWD020 FPH 0.85 260.75 114.589 8202 6499.5 10600 First Reading For Entire File..........6432 Last Reading For Entire File...........10600 File Trailer Service name .............STSLIB.004 Page 10 f-42a.tapx service sub Level Name... version Number. ........1.0..0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EoF File Header Service name... .......STSLIB.005 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 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 NPHI 10507.0 10825.0 FONT 10507.0 10825.0 NCNT 10507.0 10825.0 PEF 10521.5 10841.0 RHOB 10521.5 10841.0 DRHO 10521.5 10841.0 RPX 10548.0 10861.0 FET 10548.0 10861.0 RPS 10548.0 10861.0 RPD 10548.0 10861.0 RPM 10548.0 10861.0 GR 10555.5 10854.0 RoP 10600.5 10919.0 LOG HEADER DATA DATE LOGGED: 19-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 10919 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10919.0 TOP LOG INTERVAL (FT): 10600.0 BOTTOM LOG INTERVAL (FT): 10919.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.8 MAXIMUM ANGLE: 44.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 CTN COMP THERMAL NEUTRON 184467 Page 11 f-42a.tapx EWR4 Electromag Resis. 4 159436 ALD Azimuthal Litho-Dens 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10598.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 40.0 MUD PH: 9,$ MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .830 78.2 MUD AT MAX CIRCULATING TERMPERATURE: .550 122.0 MUD FILTRATE AT MT: .830 77.4 MUD CAKE AT MT: .870 78.1 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 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 cP30 4 1 68 8 3 RHOB MWD030 G/CC 4 1 68 12 4 DRHO MWD030 G/CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 oHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Page 12 • f-42a.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10507 10919 10713 825 10507 10919 FONT MWD030 CP30 111.9 3073.11 620.862 637 10507 10825 NCNT MWD030 CP30 14266.4 49083.5 25606.1 637 10507 10825 RHOB MwD030 G/CC 0.718 3.483 2.32731 640 10521.5 10841 DRHO MWD030 G/CC -3.047 1.052 -0.174595 640 10521.5 10841 RPD MWD030 OHMM 0.5 1960.97 221.002 627 10548 10861 RPM MWD030 OHMM 0.62 2000 131.336 627 10548 10861 RPS MWD030 OHMM 0.67 336.19 24.8302 627 10548 10861 RPX MWD030 OHMM 0.66 1591.81 26.417 627 10548 10861 FET MWD030 HR 1.85 133.37 24.7122 627 10548 10861 GR MWD030 API 20.02 524.28 97.262 598 10555.5 10854 PEF MwD030 B/E 1.33 15 5.61084 640 10521.5 10841 ROP MWD030 FPH 0.15 216.77 30.7338 638 10600.5 10919 NPHI MwD030 PU-S 5.74 59.32 30.5578 637 10507 10825 First Reading For Entire File..........10507 Last Reading For Entire File...........10919 File Trailer service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FONT 10825.5 11265.5 NPHI 10825.5 11265.5 NCNT 10825.5 11265.5 DRHO 10841.5 11281.0 RHOB 10841.5 11281.0 PEF 10841.5 11281.0 GR 10854.5 11294.0 RPS 10861.5 11301.0 RPM 10861.5 11301.0 RPx 10861.5 11301.0 Page 13 • f-42a.tapx FET 10861.5 11301.0 RPD 10861.5 11301.0 ROP 10919.5 11360.0 LOG HEADER DATA DATE LOGGED: 20-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 10919 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11360.0 TOP LOG INTERVAL (FT): 10919.0 BOTTOM LOG INTERVAL (FT): 11360.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.5 MAXIMUM ANGLE: 61.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 CTN COMP THERMAL NEUTRON 184467 EWR4 Electromag Resis. 4 159436 ALD Azimuthal Litho-Dens 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10598.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 40.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 10000 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .860 78.3 MUD AT MAX CIRCULATING TERMPERATURE: .530 132.0 MUD FILTRATE AT MT: .890 76.4 MUD CAKE AT MT: .920 78.2 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 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Page 14 • f-42a.tapx Absent value .... ............. .....-999 Depth Units. .. .. ..... Datum specificat ion Block sub -type...0 Name service order units size N sam Rep co de offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CP30 4 1 68 4 2 NCNT MwD040 CP30 4 1 68 8 3 RHOB MWD040 G/CC 4 1 68 12 4 DRHO MWD040 G/CC 4 1 68 16 5 RPD MwD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MwD040 OHMM 4 1 68 28 8 RPX MwD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MwD040 B/E 4 1 68 44 12 RoP MwD040 FPH 4 1 68 48 13 NPHI MwD040 PU-5 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10825.5 11360 11092.8 1070 10825.5 11360 FCNT MWD040 CP30 491.79 1682.64 793.486 881 10825.5 11265.5 NCNT MWD040 CP30 25391.5 39279.9 29930.5 881 10825.5 11265.5 RHOB MwD040 G/CC 2.133 3.502 2.40586 880 10841.5 11281 DRHO MWD040 G/CC -0.323 0.524 0.0637795 880 10841.5 11281 RPD MWD040 OHMM 0.59 2000 36.9192 880 10861.5 11301 RPM MWD040 OHMM 0.66 1934.22 30.6246 880 10861.5 11301 RPS MWD040 OHMM 0.8 1370.03 20.1314 880 10861.5 11301 RPX MWD040 OHMM 0.71 706.09 14.4961 880 10861.5 11301 FET MwD040 HR 0.98 18.63 4.33508 880 10861.5 11301 GR MwD040 API 5.97 53.66 10.8798 880 10854.5 11294 PEF MwD040 B/E 1.31 15.15 2.38143 880 10841.5 11281 ROP MWD040 FPH 0.44 191.3 45.554 882 10919.5 11360 NPHI MwD040 PU-S 10.55 27.9 20.0906 881 10825.5 11265.5 First Reading For Entire File..........10825 Last Reading For Entire File...........11360 File Trailer service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 Page 15 • • f -42a.tapx File Type. ............LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FONT 10575.5 11151.5 NCNT 10575.5 11151.5 NPHI 10575.5 11151.5 PEF 10591.5 11169.5 DRHO 10591.5 11169.5 RHOB 10591.5 11169.5 GR 10604.5 11178.0 RPx 10611.5 11184.5 RPS 10611.5 11184.5 RPM 10611.5 11184.5 FET 10611.5 11184.5 RPD 10611.5 11184.5 RAT 10669.5 11236.0 LOG HEADER DATA DATE LOGGED: 20-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 10919 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11236.0 TOP LOG INTERVAL (FT): 10575.5 BOTTOM LOG INTERVAL (FT): 11236.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.5 MAXIMUM ANGLE: 61.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 CTN COMP THERMAL NEUTRON 184467 EWR4 Electromag Resis. 4 159436 ALD Azimuthal Litho-Dens 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10598.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 40.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 10000 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) Page 16 • f-42a.tapx MUD AT MEASURED TEMPERATURE (MT): .860 78.3 MUD AT MAX CIRCULATING TERMPERATURE: .530 132.0 MUD FILTRATE AT MT: .890 76.4 MUD CAKE AT MT: .920 78.2 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 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 FONT MAD041 CP30 4 1 68 4 2 NCNT MAD041 CP30 4 1 68 8 3 RHOB MAD041 G/CC 4 1 68 12 4 DRHO MAD041 G/CC 4 1 68 16 5 RPD MAD041 OHMM 4 1 68 20 6 RPM MAD041 OHMM 4 1 68 24 7 RPS MAD041 OHMM 4 1 68 28 8 RPX MAD041 OHMM 4 1 68 32 9 FET MAD041 HR 4 1 68 36 10 GR MAD041 API 4 1 68 40 11 PEF MAD041 B/E 4 1 68 44 12 RAT MAD041 FPH 4 1 68 48 13 NPHI MAD041 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10575.5 11236 10905.8 1322 10575.5 11236 FCNT MAD041 CP30 115.67 3849.65 867.338 1153 10575.5 11151.5 NCNT MAD041 CP30 14616.4 52341.6 30856.2 1153 10575.5 11151.5 RHOB MAD041 G/CC 1.775 3.435 2.4404 1157 10591.5 11169.5 DRHO MAD041 G/CC -0.843 0.581 0.0770804 1157 10591.5 11169.5 RPD MAD041 OHMM 0.24 2000 41.5241 1147 10611.5 11184.5 RPM MAD041 OHMM 0.2 1557.01 29.9397 1147 10611.5 11184.5 RPS MAD041 OHMM 0.27 1261.53 23.7454 1147 10611.5 11184.5 RPX MAD041 OHMM 0.31 146.46 17.4863 1147 10611.5 11184.5 FET MAD041 HR 8.18 51.02 29.6307 1147 10611.5 11184.5 GR MAD041 API 5.14 234.5 27.2286 1148 10604.5 11178 PEF MAD041 B/E 1.3 13.2 2.8986 1157 10591.5 11169.5 RAT MAD041 FPH 0.23 1678.84 249.964 1134 10669.5 11236 NPHI MAD041 PU-5 4.48 60.94 21.4683 1153 10575.5 11151.5 Page 17 • f-42a.tapx First Reading For Entire File..........10575.5 Last Reading For Entire File...........11236 File Trailer Service name... .......STSLI6.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/12 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................08/05/12 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical services Physical EoF Physical EOF End Of LIS File Page 18
