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Home My WebLink About202-166 Image P~ject Well History File CtJer 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:Q - L & 0 Well History File Identifier Page Count from Scanned File: ð':3 (Count does include cover sheet) . Page Count Matches Number in Scanning Preparation: V YES, NO Hele~ Date: II~ Ds- Is! If NO in stage 1, page(s) discrepancies were found: YES NO Organizing (done) 0 Two-sided 1111111111111111111 RESCAN DIGITAL DATA ~iskettes, No.1 0 Other, No/Type: 0 Color Items: 0 Greyscale Items: 0 Poor Quality Originals: 0 Other: NOTES: BY: Helen [Maria) ( Project Proofing BY: Helen~ Scanning Preparation BY: Helen ~ I x 30 = 3tJ Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: 0 Rescan Needed I OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds: 0 Other::, , Date: J ~~. OS I Isl mp I Date: I ()..~ OS Is/ VV10 + ~ = TOTAl; PAGES 5d- (Count, does n. ot. '2!u~cover sheet) till.!J Date: I ~ c; O~ Isl Jt' ~ I LJ JIl;t Date: 151 I I' Date: 151 Quality Checked 1111111111111111111 ~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~.~~t~ `~ ~;' :' ;~: `~ ~~~~ a~~~'~a~k~' ~ bp ~~~E~~~~ OCT 0 ~ 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~(8 0l) 8t ~83 ~OnS. ~Of[IfrlifORinn Anchar~a~ a~~.- l~O~ ~~ ~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 207i410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-t00 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10l2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 5002923083ot00 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11l2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-t21 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 v-122 2061470 5002923328000o NA 1.5 NA 6.8 5/10/2009 v-201 2012220 50029230540000 SC leak NA 4 NA so.s 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 1828 1/9/2009 V-2t0 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "~ 2080200 50029233830000 NA 1.75 NA #b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9!7/2008 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc êA r- l)Åt.-, ~ '1 DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2021660 Well Name/No. PRUDHOE BAY UN BORE V-108 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23112-00-00 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 8/12/2002. 25 Blu 3200 9582 Open 11/1/2002 Quadrant tif/) 25 Blu 108 9582 Open 11/1/2002 Mb 0 9625 Open 10/2/2002 ~ 25 Blu 108 9582 Open 11/1/2002 rilb 25 Blu 3200 9582 Open 11/1/2002 Quadrant iff I) MD 9625 ..... TVD 7184 ",./ Completion Date 11/25/2002 r- Completion Status 1-01L -_._-__-___n____~~~~--- - --. _.~ ------~---~-------"~-~~- REQUIRED INFORMATION Mud Log No Samples No ----_._--------------~------- _.~.---_._--~------------ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, RES, DEN, NEU, AZM DENS Well Log Information: Log/ Electr Data Digital Dataset TYJ:~e Med/Frmt Number Name 1:' en ---~252 ~::S~~tes Log Log Run Scale Media No 25 Blu 1 Rpt i}og Jtóg ~ Directional Survey I nd uction/Resistivity 25 Blu 25 Blu 25 Blu I nd uction/Resistivity Neutron ~ ¡Log, £i6" ~g t)1)9 Neutron I nd uction/Resistivity D Directional Survey Induction/Resistivity Density ---- ---------~-- ----~~~ Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01L UIC N Directional Survey (~".)_._.. ~ ~,--~ ,""~ (data taken from Logs Portion of Master Well Data Maint) --../ Interval OH/ Start Stop CH Received Comments 3200 9582 Open 11/1/2002 Quadrant 1'1 1) 108 9624 Open 11/1/2002 Open hole edit of MWD logs 0 9625 Open 10/2/2002 3200 9582 Open 11/1/2002 M'b 3200 9582 Open 11/1/2002 ,.. ì/ Þ 3200 9582 Open 11/1/2002 Quadrant ~ß Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2021660 Well Name/No. PRUDHOE BAY UN BORE V-108 Operator BP EXPLORATION (ALASKA) INC MD 9625 TVD 7184 Completion Date 11/25/2002 Completion Status 1-01L ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Chips Received?" .¥.LN..- Formation Tops Analysis Received? YJ-r;;r-' --- --'---------~---~-------'-------~- ------_._- - -------.------ -----~ Comments: - --_.._-_._----_._--'--~ í I f~ ! _._---~----~.._-,----------~--- Compliance Reviewed By: Current Status 1-01L .r-, 'J/í N G)¡N Date: API No. 50-029-23112-00-00 UIC N .~ (b .J CAr-. 4"-0 t-' '--- ) STATE OF ALASKA ~\ ALASKKOIL AND GAS CONSERVATION COIv",ÆSSION ~ECE'VED REPORT OF SUNDRY WELL OPERATIOI\S 1. Operations Performed: 0 C T 0 5 2004 AbandonD Repair Well 0 PluQ PerforationsD Stimulate 00 Ot!1e~ Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Ti~la~~~nqlbn . as Cons. Commission chorage Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development Œ] Stratigraphic 0 9. Well Name and Number: V-108 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool ExploratoryD Service D 5. Permit to Drill Number: 202-1660 6. API Number 50-029-23112-00-00 82.30 8. Property Designation: ADL-0028241 11. Present Well Condition Summary: Total Depth measured 9625 feet true vertical 7183.7 feet Plugs (measured) Junk (measured) None Effective Depth measured 9531 feet true vertical 7090.6 feet None Casing Conductor Production Surface Length 80 9587 3150 Size 20" 94# H-40 7" 26# L-80 9-5/8" 40# L-80 MD TVD Burst 1530 7240 5750 Collapse 520 5410 3090 29 109 29.0 109.0 26 - 9613 26.0 - 7171.8 28 - 3178 28.0 - 2637.2 Perforation decth: Measured depth: 9103 - 9140,9142 - 9152,9156 - 9165 True vertical depth: 6667.6 - 6704.09,6706.07 - 6715.93,6719.88 - 6728.76 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 4-1/2" Baker Premier Packer @ 24 @ 48 @ 8894 @ 8925 @ 48 8894 8925 8971 8906 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9103 - 9165 Treatment descriptions including volumes used and final pressure: 1206 Bbls YF125LG System, 222 K Lbs 16/20 Carbo lite @ 6100 psig Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 1.1 0 300 1.5 154 500 13 Prior to well operation: Subsequent to operation: Oil-Bbl 658 2342 Tubing Pressure 326 333 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas D DevelopmentŒ] Service D Signature Garry Catron Garry Catron JJ~{~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. EXémpt: 302-390 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 9/27/04 n n , ,f'. , i~', "~~i 1 Øf'f., 0\,\ \b 6 lUU~ Form 10-404 Revised 4/2004 01/27/03 BBLS 1748 130 1878 ") ') V-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY Frac1d perfs 91031-91651w/YF125LG sys and 239k# of 16/20 CL. Ramped from 10-12 ppga @ 180 bbls 10# away, placed 147 bbls of 12 ppga in perfs at job completion. Underflushed job to completion with78 bbls, placed 219.8 K# of prop behind pipe. Max treat - 6528 psi, Avg treat - 4450 psi. Load to recover - 1394 bbls. All treesaver cups recovered. Well only freeze protected to 11501 with diesel. 2127 # prop left in csg, est TOS if packed is 90651 MD. FLUIDS PUMPED Fresh Water Diesel TOTAL Page 1 TREE = 4-1/16" CIW WELLHEA D = FMC ~ACtlji.\'TOR ; ""'""'-"'-NA KB~""'a:BT;-"~-'""----82~3' 13F:ELË\Ï~; , """''''-'-'''''''NJ\ 'RoP =......"---,,,,3õÕ' ".,"'" '"' "~".'.","..,............. ...m . . ~"'.'.'.'."""'''''''''','','''.'.'.',''.Y'' . n.- ,~,~,,~,~~I,~, ":,..?~,~,~,,,~,?,!:, Datum rvD = 9118' """""".......,....................,.......... ...........,........................' Datum TVD = 6600' SS ) I 9-5/8" CSG, 40#, L-80, ID = 8.835" H 3178' Minimum ID = 2.813" @ 2190' 3-1/2" HES X NIPPLE 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 8970' PERFORATION SLMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 10 @ 9103' Note: Refer to Production DB for historical perf data SIZE SPF IN1ERVAL OpnlSqz DA1E 2-1/Z' 6 9103 - 9140 0 11/25/02 2-1/Z' 6 9142 - 9152 0 11/25/02 2-1/2" 6 9156 - 9165 0 11/25/02 I PBTD H 9531' 17" CSG, 26#, L-80, ID = 6.276" H 9613' DATE REV BY COMrvENTS 09/22102 lWA/KK ORIGINAL COMR..ET10N 10/05102 GO'BSlKk ADD XOs 11/23102 DTRlTP Gl V UPIY>.1E 01/25103 J MITP Gl V UPIY>. 1E 01/31/03 JMltlh GlV UPIY>.1E 04/10/03 DRSlTP TVD/rvD CORRECTIONS ~ V-108 I - --.J ) I SAFETY NOTES: ~ 955' H 9-5/8" TAM PORT COLLAR I 1 2190' H 3-112"I-ESX NIP, ID =2.813" I ~ I I )& \ ~ DATE REV BY COM'v1ENTS ST MD 3 4750 2 7666 1 8820 8880' 8905' 8906' 8910' GAS LIFT fv1A. NDRB...S TVD DEV TY Æ VL V LA Ta-J 3502 57 MrvIG DOME RK 5293 30 MrvIG DOME RK 6389 12 MrvIG SO RK PORT DATE 1 6 01/30/03 1 6 01/30103 20 01/30/03 8937' 8959' l-þ-1/Z' BKR CMD SLIDING SLV, ID = 2.813" 1 1-i3-1/Z' X4-1/2" XO, ID = 2.940" 1 J-17' X4-1/Z' BKR PREMIER PKR, ID = 3.875" 1-i4-lIZ' X 3-1/2" XO, ID = 2.930" I 1-13-1/2" I-ES XNIP, ID = 2.813"1 1-13-lIZ' I-ES XNIP, ID = 2.813"1 8971' 1-13-lIZ' WLEG, ID = 2.905" 8976' I-1ELMD 1T LOGGED 11/25/02 I 9039' H2O' MARKERJTW/ RA TAG 1 9306' H2O' MARKERJTW/ RA TAG I BOREALIS Uf\IT WB...L: V-108 ÆRMT No: 2021660 API No: 50-029-23112-00 SEC 11, T11 N, R11 E 4805' NSL & 1906' WEL 8P Exploration (Alaska) \l-i6A-.. 12-/ ~ C /61 '1- ~ 11/~~ /fA /-, 12../ ':1 'iD '2. 63 /z/JI/c>2- APPLICATION FOR SUNDRY APPROVALS ~ /~f~¡lð?- Re-enter suspended well - Time extension - Stimulate - X Variance - Perforate- 6. Datum elevation (OF or KB feet) RKB 82.3 feet 7. Unit or Property name ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) 1. Type of request: FRAC Abandon- Suspend- Alter casing - Repair well - Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 474' FNL, 1907' FEL, Sec. 11, T11N, R11E, UM At top of productive interval 348' FNL, 2010' FEL, SEC 10, T11N, R11E, UM At effective depth 337'FNL,2025'FEL,Sec.10,T11N,R11E,UM At total depth 335' FNL, 2087' FEL, Sec 10 T11 N, R11 E, UM 12, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 108' 20" Surface 3150' 9-5/8" Production 9587' 7" Perforation depth: Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service- (asp's 590394, 5970051) (asp's 585010, 5970114) (asp's 584945, 5970125) (asp's 584933, 5970127) 9625 feet 7184 feet 9531 feet 7091 feet Plugs (measured) Junk (measured) Other - Prudhoe Bay Unit 8. Well numb;V V-108 9. Permit numbe~pproval number 202-166 10. API number 50-029-23112-00 11. Field / Pool Prudhoe Bay Field / Borealis Pool Measured Depth 136' 3178' True vertical Depth 136' 2637' Cemented 260 sx Arctic Set (Aprox) 511 sx PF 'L', 342 sx Class 'G' 298 sx Class 'G', 195 sx Class 'G' 9613' 7172' RECEIVED measured Open Perfs 9103'-9140',9142'-9152',9156'-9165' DEC 192002 Alaska Oil & Gas Gons. CommlssJoo Anchorage 3-1/2",9.2#, L-80 TBG @ 8905' MD. 3-1/2" x 4-1/2" XO @ 8905', 4-1/2" x 3-1/2" XO @ 8910', 3-1/2",9.2# L-80 Tubing Tail @ 8971.' Packers & SSSV (type & measured depth) 7" x 4-1/2" BAKER Premier Packer @ 8906'. 3-1/2" HES X Nipple @ 2190' MD. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation 15. Status of well classification as: January, 2003 16. If proposal was verbally approved true vertical Open Perfs 6660'-6704', 6706'-6716', 6720'-6729' Tubing (size, grade, and measured depth Oil_X Name of approver Date approved Service 17, I hereby certify that the foregoing is tru and correct to the best of my knowledge. ~~ Signed Bruce Smith BOP sketch - Gas- Suspended - Questions? Call Bruce Smith, (907) 564-5093. Title: Borealis Development Petroleum Engineer Date December 19. 2002 Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - \.~P Test - Location clearance- , MeChan;callntegri~~ Æ.. ....'.. S... Ubsequ. ent form.. f.eqUired. 10.:.:.- Approved by order of the eommission ~' / (': ' '^ 't Form 10-403 Rev 06/15/88 . c.Jo'-Ì I Approval no,. ' ~c--'::J- - 3 9 ò Commissioner Date f'L( S( /0 ~ SUBMIT IN TRIPLICATE bp December 19, 2002 ) ) ..\t~-l. ..'~ ~~. .~; ¡:. .Î~$¡\. BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for V-1 08 Fracture Stimulation Program BP Exploration Alaska, Inc. proposes to fracture stimulate well V-108. / Attached is the Fracturing procedure, which consists of 1500 bbls of water for diagnostics and fracturing with 200 Mlbs of 16/20 and 50 Mlbs of 12/18 ,-- Carbo Lite proppant. See pump schedule for details. The pump schedule is subject to change; fluid and proppant volumes should be adequate to address any contingencies. The procedure includes the following major steps: The procedure includes the following major steps: Category NaB STEP Description S 4500 1 Set Downhole Shut-in Tool & Dual Gauges, Run 4 day PBU. S 4500 0 4500 0 4500 C 4500 S 4500 T 4500 T 4500 Last Test: Max Deviation: Perf Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: BHT & BHP: Pull Downhole Shut-in Tool & Gauges, pull & dummy GJ:-Y~ 3 éM'~yV / 4 Perform Data Frac & Frac. Shut-in. 2 5 6 FCO. Freeze protect. Shut-in. Install GLV's. Frac, Flowback, HOT tubing, Simultaneously POP. Mobile Test Separator Test schedule. / 7 8 New Completion, never tested 58° @ 3551' MD 9.50 @ 9117' MD 2.813" SSSVN at 2190' 9531'RKB MD New Well / Static survey / 0 ppm 12/02 Schlumberger PEX 6/27/02 estimated 1580 F & 3236 psia @ 6600' TVDSS 1. Slickline ) ) a) Report well conditions, WHP, WHT, lA, OA, Production rate. b) Run Downhole shut-in device with dual Petrodata or Halco pressure gauge setting in XN nipple at 8959 MD.. c) Set pressure gauge for: 0 One reading every 15 min until the following day. (example: is tool is set at 8 pm on a Monday. Gauge would change to next setting (15 sec setting) one hour prior (such as 11 am Tuesday) to downhole tool closing, downhole tool would shut on the hour, (such as noon on Tuesday)). 0 One reading every 15 see for 48 hours 0 One reading every 1 min for remaining time. d) Freeze protect well with gas lift, freeze protect flowline with dead crude. Tent heater on tree as required. e) Report final well conditions, WHP, WHT, lA, OA, Production rate. f) Pull Downhole shutin tool and dual gauges; during same slickline rigup pull and dummy gas lift valves. 2. Fracture Treatment a) Load Frac tanks with - 100 of seawater; - 1500 bbls are required (excluding tank bottoms). /- b) RU the tree-saver/isolation tool for 3~ "- 9.3 #/ft. tubing (see attached tubing detail). PT backside to 4000 psi and maintain 3500 psi throughout treatment (set inner annulus pop-off at 4000 psi). Note this well has a 10' floating seal assembly and maintenance of 2500 psi on IA is required to stay in the PBR. Pressure test treating lines to 8500 psi. Set Nitrogen pop-off valve at 7500 psig. Set pump trips afterwards to 7500 psi. This well is expected to treat at :t 6000 psi. It is recommended that 4 pumps be on location (1 backup). c) Breaker tests will be performed on fluids prior to frac. The breaker schedule will be designed to ensure fluid stability at end of pump time with complete break with-in one hour of shut down. A minimum of 100 cp @ 100 sec^-1 is required at shut down. d) Begin pumping Data Frac, initial rate will be 5 bpm while displacing wellbore fluid, after spotting Data Frac fluid a few feet above top perf increase rate to 25 bpm and displace data frac. Shut down for ISI P, monitor for closure time, calculate efficiency and re-design frac schedule as necessary (Pad size, fluid loss additive, etc.) e) Additional diagnostic tests may be perforl11ed after data frac analysis. Consult with engineer before proceeding with frac. /' f) Re-establish injection, when add rates are lined out start counting PAD. Pump the proppant schedule as detailed in the attached pump schedule. Flush with linear fluid. g) Bleed off excess annulus pressure. Rig down Service Company. 3. Post Fracture a) Perform CTU fill cleanout to original PBTD (-9500' MDRKB corr): / 1 Perform a )erbalanced pressure fill clean-out, ci,~ting gel and sand to a tank. A connection to a flowline will not be available. 2 Use filtered seawater to clean-out. If gel sweeps are required to clean-out, have lab verify that breaker loading is adequate to break polymer & mix water at 1500 F. 3 Freeze protect to 3000' with 50/50 diesel/ neat MEOH. a. Slickline to install gas lift design to lift from bottom. b. Shut-in pending frac flowback. 4. Frac Flowback a) As soon as possible flowback through portable flow-back separator: ~ 1 For analog Kuparuk frac flowback, see L-110 & L-107 well files. /' 2 Kuparuk wells tend to hydrate-off, HOT oillA with 100 bbls of hot diesel follpwed by 20 bbls of neat MEOH. Kick off wellsimultaneouslv with POP well. / 3 Expect FWHTs of 50 - 60°F and watercuts of 100% to begin with. Treat gas lift with methanol to prevent freezing. Attempt to quantify returned proppant flushed to tank. / 4 Unload the well with 0.5 MMSCFGPD. 5 Conduct 4 hour well tests. If after 12 hours, solids are <0.1 %, then increase GL T to 1 MMSCFGPD. 6 Conduct 4 hour well tests. If after 12 hours, solids are <0.10/0, then increase GL T to 1.8 MMSCFGPD. 7 Do not surge well to flowback p~pant. Surging could cause formation failure and sand production. 8 Continue producing to the flowback separator until the gel load has been recovered or watercut <10% and the solids production <0.1 %. 9 Schedule wellbore for Pad Separator test. b) Place well on production at gas lift rate °.!Jß MMSCFPD, Place well on normal 15 day AOGCC required testing schedule. c) Service tree. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW@BP.com Sincerely, ~~~ Bruce W. Smith GPB Borealis Development Engineer ) TREE = 4 1/16" CMf W ELLHEA D = F tt£ ""~,'-v.,,,,,,,,,..,,........,,,,,~.,,,,-,^",,_.~.,,u ."... ACTUATOR = NA 'KB:ECBï;;"'''-"_m'-~''~ê2~3' Êj'F~-ELêr; "'^'^^~-~'-NA I<OP;~-----"'- -- '-300' MaxÅ ng iî!;;""5SÔ"@ 3551' DatiÎm MD ;"^-----'~-'-- D:ôlltum T\/6:; --~'ãiOOím&S' I ~518" CSß, 40#, l:80, ID = e.835" H 3178" Minimum ID = 2.813" @ 2190' 3-11211 HES X NIPPLE I 3.112" T6G. 9.2#, l: 80. .Oca7 I:J pf, ID = 2.992" H 8970" PERF ORA TION SUMt.M RY REF LOG: TCPPffiF ANGLE AT TOP PERF: 10 @9103' Note: R&fer to Production DB for hist~rictll perf dat.. SIZE SPF INlERVAL OpnlSqz: DATE 2-112" 6 Q100 . Q14::J 0 11f251D2 2-1/2' 6 Q142 - Q152 0 11f25102 2-1/2' 6 Q156 . Q166 0 11f25102 I PBTD H 9531" 17" eSG, 26#, l:8D, ID= 6.276" H 0013" DA lE RBI BY CO~8HS OQ/22.(:;2 lWA/KK 0 RIG INA L C OMPLETIO N 101Q5,():2 ß(;fBSlKI< ADD XOs 11/23K1:2 DTRlTP ßLV ClO ~ V-10S/ = I - ..L!.. ) I SAFETY NOTES: =~ 955' H 9-5/S" TAM PORT COLLAR I I 219D" H 3-112" HES X NIP.ID = 2.813" I ~ - ----.! )& ST MD 3 475D 2 7666 1 882D 888D" 8905" 8906" 891 D" 893r 8959" ~A S LIFT tJI6. ND R ELS TVD DEV TYPE VLV LATCH 3502 57 MMG DOME RK 52B3 30 MMG DOME RK 6389 12 MMG SO RK PORT DATE 16 11123102 16 11f23102 2D 11123102 1-+~.1/2" BKR CMD SUDING SLV. ID = 2.813" I H3-1/2" X 41/2" XO, ID = 2.940" I ~7" X 41f2" BKR PR8v1IER PKR. ID = 3.875" I H4112" X 3-112" XO, ID = 2.930" I H3-112" HES X NIP, ID = 2.813" I H3-112" HES X NIP, ID = 2.813" I \ I 8971" H 3-1/2" W LEG, ID = 2.905" I I 8976' H ELIvD IT LOG~ED 11/25132 I [ ~ DA TE REV BY COM~NTS 9039" H 2D' M6.RKER J T W / RA T A (? I 9306" H2D' M6.RKER JTW/ RA TA~ I ~PB BOREALIS WELL.: V -1 D8 PffiMT No: 2021660 APt No.: 5a-02S-23112-ao SEC 11. T11N. R11E 4806' N5L&1006'WEL BP Expl.ratien (Alaska) ) STATE OF ALASKA 'iALA9~;QtL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 23. CASING SIZE 20" 9-5/8" 1. Status of Well aD Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface e""1(:Y"iý¡j'1J"V."~ 4805' NSL, 1906'.W~L, SEC. 11, T11N, R11E, UM ~...tG.\èA1~., .J~.~... At top of productive Interval ~; "~,. . ., ' 4930' NSL, 2006' WEL, SEC. 10, T11N, R11E, UM ': ..11~~.,P1- :"":1. : '.~. 10. Well Number At total depth . ,i . .." '~. -. ., , 4945' NSL, 2088' WEL, SEC. 10, T11 N, R11 E, UM :- ~- 'Jþ- '~'.:;,~~.:. .;:~;;,' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designatiòri and Serial No. KBE = 82.3' ADL 028241 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 9/11/2002 . 9/18/2002 . 11/25/2002 ' 17. Total Depth (MD+TVD) ,18. Plug Back Depth (MD+TVD) 19. Directional Survey 9625 7184 FT 9531, 7091 FT aD Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, PWD, RES, DEN, NEU, AZM DENS CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD ¡SUrface 108' 42" ,260 sx Arctic Set (Approx.) , 28' 3178' 12-1/4" 511 sx PF 'L', 342 sx Class 'G' 9613' 8-3/4" 298 sx Class 'G', 195 sx Class 'G' Classification of Service Well 7. Permit Number 202-166 8. API Number 50-029-23112-00 9. Unit or Lease Name Prudhoe Bay Unit V-108 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2190' MD 1900' (Approx.) WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 L-80 AMOUNT PULLED 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD 9103' - 9140' 6668' - 6704' 9142' - 9152' 6706' - 6716' 9156' - 9165' 6720' - 6729' 25. SIZE 3-1/2",9.2#, L-80 TUBING RECORD DEPTH SET (MD) 8971' PACKER SET (MD) 8906' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 230 Bbls of Diesel 27. Date First Production November 28, 2002 Date of Test Hours Tested 12/11/2002 2 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR! OIL-BBL TEST PERIOD 867 Flow Tubing Casing Pressure CALCULATED Press. 315 24-HoUR RATE OIL -BBL GAs-McF 1,161 GAs-McF WATER-BBL -0- WATER-BBL CHOKE SIZE GAS-OIL RATIO 1,339 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit coreRif eEl V E D No core samples were taken. DEe 2 3 RBDMS BFL DEC 1 9 2002 . ~~' ~~ Alaska Oil & Gas Cons. Commission Anchorage ~ f Form 10-407 Rev. 07-01-80 Submit In Duplicate ) 29. I '1~ l':';'f ,'. Geologic Markers Marker Name Measured True Vertical Depth Depth Schrader Bluff N Sands 6105' 4244' Schrader Bluff 0 Sands 6397' 4410' Base Schrader I Top Colville 6964' 4764' HRZ 8790' 6360' Kalubik 8970' 6537' Kuparuk D 9074' 6639' Kuparuk C 9103' 6668' Kuparuk B 9241' 6804' Kuparuk A 9373' 6934' Miluveach 9448' 7008' ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECErVED DEC 1 9 2002 31. List of Attachments: Summary of DailY <Drilling Reports and Post Rig Work, Surveys Alaska Oil & Gas Cons. Commission Anoooragt 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie HUbbíé"'"'~. '~ Title Technical Assistant V-108 Well Number 202-166 Permit No. I Approval No. INSTRUCTIONS Date \~.. \q.OA Prepared By Name/Number: Terrie Hubb/e, 564-4628 Drilling Engineer: James Franks, 564-4468 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: V-108 Common Name: V-108 Test Date 9/14/2002 Test Type LOT Test Depth (TMD) 3,178.0 (ft) BP AMOCO Leak-Off Test SumnJ~[~ Test Depth (TVD) 2,637.0 (ft) AMW 9.70 (ppg) Suñace Pressure 680 (psi) Leak Off Pressure (BHP) 2,009 (psi) Page 1 of 1 EMW 14,66 (ppg) ~ -....-r' . Printed: 9/25/2002 4:13:33 PM ) ) BP AMOCO Operations Summary Report Page 1 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-108 V-108 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/10/2002 Rig Release: 9/22/2002 Rig Number: 9ES Spud Date: 9/11/2002 End: 9/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2002 08:00 - 16:00 8.00 MOB P PRE Mob rig from V-105i to V-108. Exception Rig Move. 16:00 - 18:00 2.00 RIGU P PRE Accept rig @ 16:00 hrs, 09/10/2002. Take on water in pits & mix spud mud. Load pipe shed with BHA & strap. 18:00 - 21 :00 3.00 DRILL P SURF PU BHA #1 & stand back in derrick. 21 :00 - 21 :30 0.50 DRILL P SURF Pre-spud meeting with rig crew & contractors. 21 :30 - 23:00 1.50 DRILL P SURF PU bit, motor, & MWD, 23:00 - 00:00 1.00 DRILL P SURF Function Test Dirverter System. Witness Test waived by Lou Grimaldi, AOGCC. Fill conductor and check for leaks. 9/11/2002 00:00 - 02:00 2.00 DRILL P SURF Pressure Test Surface lines. Spud well. Drill from 108' - 333'. 02:00 - 02:30 0.50 DRILL P SURF POOH w/ 2 stands HWDP. MU Jar stand. TIH. 02:30 - 12:30 10.00 DRILL P SURF Directionally Drill f/ 333' -1469'. 35 K WOB, 650 gpm, 2060 psi, 80 rpm. TQ: 3.5 K on btm, 1.1 K off btm. KOP @ 447'. 12:30 - 13:00 0.50 DRILL P SURF Circulate weighted sweeps and hole clean. 220 spm, 650 gpm, 1885 psi, 80 rpm. 13:00 - 14:00 1.00 DRILL P SURF Flow check. POOH for bit #2. PU wt = 90 K, SO wt = 75 K. 14:00 - 15:00 1.00 DRILL P SURF TIH. Tight f/ 867' - 904', 1110', & 1120'. Worked thru tight spots. 15:00 - 00:00 9.00 DRILL P SURF Wash / Ream last stand to bottom. Directionally drill f/1469' - 2890'. 30 -35 WOB ,650 gpm, 2850 psi off btm, 3150 psi on btm, SO wt = 72 K, PU wt = 98 K, Rot wt = 80 K, TQ: 2 K off btm, 8 K on btm. AST: 9.10 hrs, ART: 4.77 hrs, ADT: 13.87 hrs. 9/12/2002 00:00 - 01 :00 1.00 DRILL P SURF Directionally drill f/ 3054' - 3236'. TD Surface Hole. 30 -35 WOB ,650 gpm, 2850 psi off btm, 3150 psi on btm, SO wt = 72 K, PU wt = 98 K, Rot wt = 84 K, TQ: 2 K off btm, 8 K on btm. AST:0.60 hrs, ART: 0,8 hrs, ADT: 1.4 hrs. 01 :00 - 02:30 1.50 DRILL P SURF Pump weighted sweeps. Circulate and condition mud for wiper trip. 650 gpm, 2850 psi. 02:30 - 04:30 2,00 DRILL P SURF Flow check. POOH f/ 3236' - 1900'. 25 - 30 K over pull. Pulling tight to 1900'. 04:30 - 05:30 1.00 DRILL P SURF Back ream f/1900' - 1470'. 650 gpm, 2250 psi. 05:30 - 06:30 1.00 DRILL P SURF POOH to 816'. 06:30 - 08:30 2.00 DRILL P SURF TIH f/ 816' - 1469'. Tight @ 1490'. Attempt to work through WIO success. Wash & Ream through @ 60 rpm, 60 spm, 680 psi. TIH pushing obstruction ahead. Wash, Ream, & work pipe to bottom @ 3236'. 08:30 - 10:30 2.00 DRILL P SURF Circulate and condition mud for 9 5/8" casing. 10:30 - 12:30 2.00 DRILL P SURF Flow check. POOH. Hole slick. 12:30 - 13:30 1.00 DRILL P SURF Drain mud motor. LD MWD, Stab, Lead DC, & Mud Mtr. Stand back HWDP, Jars, & 1 DC stand. 13:30 - 15:30 2.00 CASE P SURF Clear rig floor. Make dummy hanger run. RU 9 5/8" casing equipment. 15:30 - 21 :30 6.00 CASE P SURF PJSM. MU 9 5/8" Shoe track (Float shoe, 2 jts 9 5/8" casing, float collar, 1 jt 9 5/8" casing), . Test float equipment. TIH w/ 76 jts 9 5/8", 40 #/ft, L-80, BTC-M casing. 21 :30 - 00:00 2.50 CASE N DPRB SURF Tag up @ 3182'. Work pipe & circulate with Fill-up tool attempting to get to casing point @ 3224'. 9/13/2002 00:00 - 01 :30 1.50 CASE N DPRB SURF Continue to work pipe w/o success. Made -1.5'. 01 :30 - 02:30 1.00 CASE N DPRB SURF Lay down 2 jts 9 5/8" casing. PU 1 shorter joint of 9 5/8" casing. 02:30 - 03:00 0.50 CASE P SURF PU landing joint and 9 5/8" casing hanger. Land in starter head. 95/8" casing shoe @ 3178'. 03:00 - 04:30 1.50 CEMT P SURF NU cement head & circulating equipment. Circulate and Printed: 9/25/2002 4:13:39 PM ) ) BP AMOCO Operations Summary Report Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 08 V -108 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/10/2002 Rig Release: 9/22/2002 Rig Number: 9ES Spud Date: 9/11/2002 End: 9/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/13/2002 03:00 - 04:30 1.50 CEMT P SURF condition mud prior to cement job. 04:30 - 07:00 2.50 CEMT P SURF Test lines. Mix & pump cement as per well plan. Pmp 5 BW. Test lines to 3500 psi. Pmp 15 BW. Drop Btm plug. Pmp 50 bbls 10.7 ppg Alpha spacer @ 6 bpm, 378 psi. Mix & pmp 378 bbls (511 sxs) 10.7 ppg, 4.15 ft^3/sx Lead Permafrost L cement @ 8 bpm, 380 psi. Mix & pmp 70 bbls (341 sxs "G") 15.8 ppg, 1.15 ft^3/sx Tail cement @ 6 bpm, 212 psi. Drop top plug. Pmp 10 BW with Halliburton. Switch to rig pump for displacement. Pump 225 bbls 9.6 ppg mud @ 8 bpm, 1000 psi. Bump plug to 1700 psi. Bleed off pressure. Floats ok. 100% returns during job. Reciprocated pipe. (60 bbls uncontaminated cement to surface) 07:00 - 08:30 1.50 CEMT P SURF ND cement head & circulating equipment. Back out landing jt. RD casing equipment. 08:30 - 10:30 2.00 BOPSURP SURF ND Diverter System. 10:30 - 14:00 3.50 BOPSUR P SURF NU Well head. NU BOP. 14:00 - 15:00 1.00 DRILL P PROD1 Re-Ievel rig. Settled to off drillers side due to soft location. 15:00 - 19:00 4.00 BOPSUR P PROD1 RU Test equipment. Install plug in head. Fill lines & stack. Test BOPE to 250 psi low / 5 min & 4500 psi high I 5 min. Test Annular to 250 psi low /5 min & 3500 psi high / 5 min. RD test equipment. Pull test plug and install Wear bushing. Blow down lines. 19:00 - 00:00 5.00 DRILL P PROD1 Move HWDP to off drls side, PU 4" DP from pipe shed. RIH and rack back in derrick. Rabbit all joints. 9/14/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to pick-up DP and rack back in derrick. 01 :30 - 05:00 3.50 DRILL P PROD1 PU BHA #3. TIH with HWDP. Surface Test MWD. Tools not responding. 05:00 - 05:30 0.50 DRILL P PROD1 Prep to POOH to change out MWD I ADN tools. LD Porcupine reamer. 05:30 - 07:00 1.50 DRILL P PROD1 Slip & Cut drilling line. Service Top Drive, Crown, & Draw works. 07:00 - 08:30 1.50 DRILL N DFAL PROD1 POOH. Stand back HWDP, Jar stand, & DC's. Unload RA source and LD ADN & MWD. 08:30 - 10:30 2.00 DRILL N DFAL PROD1 PU new ADN & MWD. Load RA source. TIH with BHA #3. Surface test MWD. OK. 10:30 - 13:00 2.50 DRILL P PROD1 TIH picking up 4" DP from pipe shed. Rotate thru TAM port collar @ 955'. Test casing to 1000 psi after passing thru TAM. Continue TIH to 3000'. 13:00 - 14:00 1.00 EVAL P PROD1 Test casing to 3500 psi I 30 min. Record on chart. 14:00 - 15:30 1.50 DRILL P PROD1 Continue in hole & Drill Float collar, shoe track, float shoe and clean old hole to 3236'. 15:30 - 16:00 0.50 DRILL P PROD1 Drill 20' new formation to 3256' @ 80 rpm, 600 gpm, 1650 psi. 16:00 - 17:00 1.00 DRILL P PROD1 Displace mud in hole with new 9.7 ppg LSND. Get slow pump rates. 17:00 - 17:30 0.50 DRILL P PROD1 Pull into casing shoe. Perform LOT. TVD: 2637', MW: 9.7 ppg, LO pressure: 680 psi, EMW = 14.66 ppg. 17:30 - 18:00 0.50 DRILL P PROD1 Obtain benchmark ECD = 10.16 ppg. 18:00 - 20:00 2.00 DRILL P PROD1 Directionally drill f/3256' - 3715'. 80 rpm, 600 gpm, 2146 psi on, 1775 psi off bottom. Pumping Hi I Low sweeps @ 200' intervals, back reaming full stand on connections. 20:00 - 21 :00 1.00 DRILL P PROD1 Circulate for ECD control. Calc ECD = 10.2 ppg, real time ECD = 10.9 ppg. 21 :00 - 00:00 3.00 DRILL P PROD1 Directionally drill f/ 3715' - 4088'. WOB: 10 - 20 K, RPM: 80, Printed: 9/25/2002 4:13:39 PM ) ) BP AMOCO Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-108 V-108 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/10/2002 Rig Release: 9/22/2002 Rig Number: 9ES Spud Date: 9/11/2002 End: 9/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/14/2002 21 :00 - 00:00 3.00 DRILL P PROD1 SPM: 235, Pmp pressure: 2146 psi on btm, 1943 psi off btm. TQ: 5.8 K on, 4 K off. AST: 0.3 hrs, ART: 1.95 hrs, ADT:2.25 hrs. ECD calc = 10.2 ppg, ECD real time = 10.8 ppg. 9/15/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Directionally drill f/ 4088' - 4371'. WOB: 10 - 20 K, RPM: 80, SPM: 235, Pmp pressure: 2146 psi on btm, 1943 psi off btm. TQ: 5.8 K on, 4 K off. PU wt = 110, SO wt = 80 K, RT wt = 91 K. ECD calc = 10.3 ppg, ECD real time = 10.9 ppg. 01 :30 - 02:30 1.00 DRILL P PROD1 Circulate Hi I Low sweep around and hole clean. Prep for wiper trip. ECD real time = 10,6 ppg. 02:30 - 03:00 0.50 DRILL P PROD1 POOH to 3715'. Tight from 3900' pulling 25 K - 35 Kover. 03:00 - 04:30 1.50 DRILL P PROD1 Back ream f/ 3715' to 9 5/8" casing shoe due to swabbing and tight hole. "Porcupine reamer" down to 3554'. 04:30 - 05:00 0.50 DRILL P PROD1 Service Top Drive. 05:00 - 06:30 1.50 DRILL P PROD1 TIH. Tag up @ 3765'. Wash / ream to 3809',40 rpm, 300 gpm. TIH. Wash last stand to bottom. No fill. 06:30 - 19:30 13.00 DRILL P PROD1 Directionally drill f/ 4371' - 6331'. Back reaming full stands on connections. Sweeps /200'. Control drill w/ 360 ROP max from 5488' for LWD. WOB: 10 - 20 K, RPM: 80, SPM: 235, Pmp pressure: 3000 psi on btm, 2770 psi off btm. TQ: 7.8 K on, 7.1 K off. PU wt = 145 K, SO wt = 86 K, ROT wt = 110 K. ECD calc = 10.2 ppg, ECD real time (rt) = 10.7 ppg. Daily total AST: 1.75 hrs, ART: 5.72 hrs, ADT: 7.42 hrs. 19:30 - 20:30 1.00 DRILL P PROD1 Circulate Low I High sweep around @ 600 gpm, 2675 psi. ECD (rt) = 10.5 ppg. 20:30 - 21 :00 0.50 DRILL P PROD1 Flow check. POOH. Tight @ 6040' & could not work through @ 5800'. 21 :00 - 21 :30 0.50 DRILL P PROD1 Back ream f/ 5850' - 5480'. Circulate for ECD's during backream. 21 :30 - 22:30 1.00 DRILL P PROD1 POOH fl 5480' - 4182'. Hole slick. "Porcupine Reamer" down to 5511'. 22:30 - 23:30 1.00 DRILL P PROD1 RIH to bottom. Hole slick. Wash last stand down. No fill. 23:30 - 00:00 0.50 DRILL P PROD1 Circulate sweep around & ECD down (10.8 ppg @ start of circulation) to 10.5 ppg. 9/16/2002 00:00 - 00:00 24.00 DRILL P PROD1 Directionally drill f/7078' - 8023'. Backreaming full stands on connections. Sweeps /200'. WOB: 25 K, RPM: 90, SPM: 230, Pmp pressure: 3360 psi on btm, 2950 psi off btm. TQ: 10.5 K on, 9 K off. PU wt = 197 K, SO wt = 100 K, ROT wt = 130 K. ECD calc = 10.2 ppg, ECD real time (rt) = 10.6 ppg. AST: 5.85 hrs, ART: 10.25, ADT: 16.1 hrs. 9/17/2002 00:00 - 05:30 5.50 DRILL P PROD1 Directionally drill fl 8023' - 8479'. Backreaming full stands on connections. Sweeps 1200'. WOB: 25 K, RPM: 100, SPM: 230, Pmp pressure: 3360 psi on btm, 2950 psi off btm. TQ: 10 K on, 8 K off. PU wt = 198 K, SO wt = 110 K, ROT wt = 139 K. Circulate in spike mud @ 8386'. MW = 10.3 ppg. ECD calc = 10.8 ppg, ECD real time (rt) = 11.1 ppg. 05:30 - 06:30 1.00 DRILL P PROD1 Circulate LO-HI sweep around. Prep for wiper trip. Calc. ECD 10.79, Act ECD 11.10. Monitor well. Pump pill. 06:30 - 08:00 1.50 DRILL P PROD1 POOH to 5400'. Had intermittant drag of 10 to 25K. Wipe thru all spots, OK. Hole looked good, no swabbing. 08:00 - 09:00 1.00 DRILL P PROD1 RIH to 8385'. Hole in good shape. 09:00 - 10:00 1.00 DRILL P PROD1 Fill pipe & stage up pumps. Wash down to 8479'. No fill. Pump HI-vis sweep around & clean hole. Act ECD 10.98 10:00 - 00:00 14.00 DRILL P PROD1 Directionaly drill f/8479-9348'. Same parameters as above. Printed: 9/25/2002 4:13:39 PM ) ) BPAMOCO Operations Summary Report Page 4 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-108 V-108 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/10/2002 Rig Release: 9/22/2002 Rig Number: 9ES Spud Date: 9/11/2002 End: 9/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2002 10:00 - 00:00 14.00 DRILL P PROD1 PU: 203k; so: 122k; Rot: 157k. Reduced backreams to 30' a TKUP. Calc ECD: 10.75; Act ECD: 11.01. 9/18/2002 00:00 - 02:00 2.00 DRILL PROD1 Drill 8.75" hole to TD @ 9625' as per Geologist. 02:00 - 03:30 1.50 DRILL PROD1 Circ Hi-vis sweep & cond mud for short trip. Calc ECD: 10.77; Act ECD: 11.05. Monitor well. Pump pill. "" 03:30 - 09:30 6.00 DRILL PROD1 Wiper trip to shoe. 25k overpull @ 9262'-wiped out OK. Swabbing at 3580'. Break circulation slow. Attempt to backream losing returns. Pump bottoms up. Backream to shoe slowly watching ECD's. 09:30 - 10:30 1,00 DRILL PROD1 Pump nut plug + sapp sweep around in casing. 600 gpm @ 2200 psi. while rotating 110 rpm. Got lots of debris in returns. Monitor well OK. 10:30 - 11 :30 1.00 DRILL PROD1 Cut and slip drill line. 11 :30 - 12:00 0.50 DRILL PROD1 Service top drive. 12:00 - 15:00 3.00 DRILL PROD1 Monitor well. Static. RIH Stage up pumps and wash last stand to bottom. No fill. Hole looked good. Calculated ECD= 10.75 Actual ECD = 10.98. 15:00 - 18:30 3.50 DRILL PROD1 Circulate sweep. Circulate and condition mud. @585 gpm, 3800 psi while rotating 100 rpm. 18:30 - 20:30 2.00 DRILL PROD1 POH from 9625' to 6986'. Pulled 25 over 9422 - 9412 wiped out with multiple passes. 20:30 - 21 :30 1.00 DRILL PROD1 Stage up pumps and spot 288 bbl of Steel Seal pill at 6986'. Pump dry job. 21 :30 - 00:00 2.50 DRILL PROD1 POH to 1150'. 9/19/2002 00:00 - 03:30 3.50 DRILL P PROD1 POH and LD NUC tool and BHA. 03:30 - 04:00 0.50 DRILL P PROD1 Clear floor. 04:00 - 05:00 1.00 BOPSUR P COMP Pull wear ring. Flush out stack. Install test plug. 05:00 - 06:30 1.50 BOPSUR P COMP Change out top rams to 7" and test door seals to 3500 psi. 06:30 - 08:00 1.50 CASE P COMP Rig Up 7" casing equipment. 08:00 - 00:00 16.00 CASE P COMP Run 7" casing per program. One joint per minute. Break circulation every 10 joints to the shoe. Circulate 15 minutes every 15 joints and CBU every 30 joints. Initially hole standing full while running casing but later not getting full displacement after 7000'+-. Well breathing during circulation typically 25-30 bbls. Total net losses to 7000' = 60 bbls. 9/20/2002 00:00 - 07:00 7.00 CASE P COMP Continue to run 7" casing. Shoe at 9613'. Total losses on trip 99 bbl. 07:00 - 07:30 0.50 CEMT P COMP LD fill up tool. MU cementing head. 07:30 - 10:30 3.00 CEMT P COMP Break circulation slowly stageing up pumps. Reciprocate pipe 295 UP, 135 DN. It took 450K to initially get pipe to break free. Condition mud at 6.5 bpm @ 765 psi. Losses stablized after taking 30 bbls. 10:30 - 13:30 3.00 CEMT P COMP PJSM. Test lines to 4000 psi. OK. Pump 30 bbl of 11.3 ppg spacer, 124 bb112.5 ppg lead cement,40 bb115.8 ppg tail slurry. Displace at 7 bpm with 364.9 bbls seawater. Bump plug with 4000 psi. Reciprocate pipe through out job. 295 UP, 135 DN. Floats held. 13:30 -14:30 1.00 CEMT P COMP Rig down cementing head. BOLDS. Drain and flush stack. 14:30 -15:00 0.50 CEMT P COMP Install packoff and test to 4000 psi. 15:00 - 16:00 1.00 CEMT P COMP RD casing running tools and change out long bails 16:00 - 17:30 1.50 CEMT P COMP Install test plug. Change out and test upper rams. Install wear ring. 17:30 - 19:00 1.50 CEMT P COMP MU BHA with 7" casing scraper. PU HWDP. Printed: 9/25/2002 4: 13:39 PM ) ') BP AMOCO Operations Summary Report Page 5 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-108 V-108 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/10/2002 Rig Release: 9/22/2002 Rig Number: 9ES Spud Date: 9/11/2002 End: 9/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/20/2002 19:00 - 22:30 3.50 CEMT P COMP RIH to 9450' 195 UP, 120 DN. Wash to 9531 and tag landing collar. 22:30 - 00:00 1.50 CEMT P COMP Pump 25 bbl Hi Vis sweep. with dirt magnet and 325 bbl clean seawater. 9/21/2002 00:00 - 05:30 5.50 CLEAN P COMP POH. Laydown Drill pipe and 7" casing scraper. 05:30 - 07:00 1.50 CLEAN P COMP Perform LOT with 10.3 ppg mud. Stage pump up to 3 bpm at 750 psi. Pump away 99 bbl down surface X long string annulus. (EMW=14.5 ppg) 07:00 - 07:30 0.50 CLEAN P COMP Continue to LD drill pipe. 07:30 - 08:30 1.00 CLEAN P COMP LD HWDP, bit and scraper. 08:30 - 09:30 1.00 CLEAN P COMP Pull wear ring. Pressure test casing to 4500 psi for 30 minutes. Good test 0 loss. 09:30 - 10:30 1.00 CLEAN P COMP Make dummy run with tubing hanger. RU tubing running equipment. 10:30 - 21 :00 10.50 CLEAN P COMP Run 3.5" tubing completion. 21 :00 - 22:00 1.00 CLEAN P COMP MU tubing hanger. Land hanger and run in lock down screws. 22:00 - 00:00 2.00 CLEAN P COMP Reverse circulate in 380 bbl seawater and spot corrosion inhibitor. 9/22/2002 00:00 - 02:00 2.00 CLEAN P COMP Set packer with 4200 psi. Test packer and tubing to 4000 psi for 30 minutes. Good test 0 loss. Test annulus to 4000 psi for 30 minutes. Good test 0 loss. Shear RP with 3400 psi. Establish reverse circulation rate 3 bpm at 400 psi. 02:00 - 02:30 0.50 CLEAN P COMP Set TWC and test to 2800 psi. 02:30 - 04:00 1.50 CLEAN P COMP ND BOP and setback. 04:00 - 05:30 1.50 CLEAN P COMP NU tree and test to 5000 psi. 05:30 - 06:30 1.00 CLEAN P COMP RU lubricator and pull TWC, 06:30 - 09:30 3.00 CLEAN P COMP RU lines and test to 3000 psi OK. Reverse in 230 bbl of diesel for freeze protection. "U" tube to the tubing. 09:30 - 1 0:30 1.00 CLEAN P COMP RD lines and set a BPV in tubing hanger. 10:30 - 12:00 1.50 CLEAN P COMP RD second annulus valve. Secure tree. Release rig. Printed: 9/25/2002 4:13:39 PM .) ) Well: Field: API: Permit: V -1 08 Prudhoe Bay Unit 50-029-23112-00 202-166 Rig Accept: 09/10/02 Rig Spud: 09/11/02 Rig Release: 09/22/02 Drilling Rig: Nabors 9ES POST RIG WORK 11/23/02 PULL BALL AND ROD. PULL 1 112 DGLV'S FROM STA 1 (8812'), STA 2 (7660') AND STA 3 (4736'). SET STA# 3 (DOME 16/64"- 1626#) ST A# 2 (DOME 16/64" 1671 #) ST A# 1 (S/O- 20/64") RUN IN TO PULL RHC PLUG BODY. 11/24/02 PULLED 3-1/2" RHC PLUG BODY. DRIFT AND TAG WI 2.50" DUMMY GUN I TEL I SB TO TO @ 9538' SLM, NO ELM OR SAMPLE. RDMO. LEAVE WELL SHUT IN, INFORM PAD OP. 11/25/02 RAN JEWELRY-TEMP LOG, PERFORATED 9103-9140,9142-9152,9156-9165 @ 6 SPF POWERFLOW. .,.. 11/27/02 WARM UP WELL BORE FOR POP * TIIIOI = 7401010. PUMPED 10 BBLS DIESEL TO PT S-RISER & FL TO 1000 PSI FOR PAD OPERATOR I PUMPED 5 BBLS NEAT SPEAR, 120 BBLS DIESEL @ 180 DEG F, & 18 BBLS NEAT FP DOWN I.A. TIIIOI = 320/400/275. 12/02/02 RUN STATIC BOTTOM HOLE PRESSURE SURVEY. GOOD DATA, (MRT READS 179 DEGREES). 6700' TVDSS = 3277 PSI 6600' TVDSS = 3236 PSI 6500' TVDSS = 3204 PSI 6600' TVDSS = 3236 PSI (REPEAT) RETURN WELL TO PAD OP. FOR PRODUCTION. 12/03/02 HOT OIL IA WI 90 BBLS DIESEL @ 1900 FOLLOWED BY 20 BBLS METH. LEAVE WELL FOR DSO TO POP. ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay / Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-108 API number...............: 50-029-23112-00 Engineer. . . . . . . . . . . . . . . . .: R. Franco RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 53.80 ft KB above permanent.......: N/A Top Drive used DF above permanent.......: 82.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.32791886 Departure (+E/W-)........: W 149.26688753 Azimuth from rotary table to target: 271.91 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] -.. 18-Sep-2002 05:49:07 Page 1 of 5 Spud date................: Last survey date....... ..: Total accepted surveys...: MD of first survey.......: MD of last survey........: 11-Sep-02 18-Sep-02 104 0.00 ft 9625.00 ft ~' ----- Geomagnetic data ---------------------- Magnetic model........ ...: BGGM version 2001 Magnetic date.... ...... ..: 10-Sep-2002 Magnetic field strength..: 1149.64 HCNT Magnetic dec (+E/W-).....: 25.93 degrees Magnetic dip.... ...... ...: 80.76 degrees ----- MWD survey Reference Criteria --------- Reference G..............: 1002.68 mGal Reference H........... ...: 1149.64 HCNT Reference Dip......... ...: 80.77 degrees Tolerance of G.... .......: (+/-) 2.50 mGal Tolerance of H...........: (+/-) 6.00 HCNT Tolerance of Dip....... ..: (+/-) 0.45 degrees ~ ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.81 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.81 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth ( ft) 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 -------- -------- 1 2 3 4 5 0.00 189.25 295.58 387.19 478.79 572.07 664.60 756.88 848.70 941.78 1036.02 1129.37 1222.43 1315.52 1410.93 1501.59 1595.76 1689.87 1784.14 1877.75 1969.95 2063.34 2157.52 2245.65 2339.08 2437.91 2530.25 2623.39 2716.43 2809.51 ------ ------ Incl angle (deg) ------ ------ 0.00 1.00 1.29 1.43 1.97 3.80 5.80 7.91 9.28 10.81 14.28 16.23 19.99 22.85 23.94 25.32 28.88 30.27 32.19 34.18 37.73 40.07 41.58 43.23 45.80 48.07 49.62 52.08 54.72 56.57 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 0.00 286.98 286.98 288.81 278.10 271.66 273.61 274.33 270.18 268.79 269.43 270.89 271.30 272.17 273.20 272.04 271.62 271.75 270.50 269.88 269.52 269.14 269.36 270.13 270.24 270.41 270.23 270.54 271.33 272.06 ------ ------ 0.00 189.25 106.33 91.61 91.60 93.28 92.53 92.28 91.82 93.08 94.24 93.35 93.06 93.09 95.41 90.66 94.17 94.11 94.27 93.61 92.20 93.39 94.18 88.13 93.43 98.83 92.34 93.14 93.04 93.08 -------- -------- TVD depth (ft) -------- -------- 0.00 189.24 295.55 387.13 478.69 571.85 664.05 755.67 846.45 938.10 1030.08 1120.14 1208.57 1295.22 1382.79 1465.20 1549.02 1630.86 1711.47 1789.81 1864.43 1937.11 2008.37 2073.44 2140.06 2207.54 2268.31 2327.11 2382.58 2435.10 18-Sep-2002 05:49:07 -------- -------- Vertical section (ft) -------- -------- 0.00 1.59 3.65 5.74 8.39 13.08 20.82 31.83 45.54 61.76 82.20 106.75 135.67 169.66 207.54 245.32 288.21 334.65 383.52 434.73 488.82 547.40 608.90 668.29 733.76 805.93 875.42 947.62 1022.30 1099.14 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 0.48 1.10 1.77 2.36 2.68 3.06 3.83 4.33 4.17 3.87 3.96 4.52 5.57 7.35 9.07 10.43 11.79 12.74 12.90 12.61 11.92 11.12 10.86 11.07 11.48 11.87 12.36 13.59 15.86 0.00 -1.58 -3.61 -5.68 -8.32 -13.00 -20.73 -31.72 -45.42 -61.65 -82.12 -106.68 -135.59 -169.57 -207.41 -245.15 -288.02 -334.45 -383.31 -434.54 -488.67 -547.31 -608.87 -668.30 -733.80 -805.99 -875.52 -947.74 -1022.41 -1099.22 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 1.65 3.78 5.95 8.65 13.27 20.95 31.95 45.63 61.79 82.21 106.75 135.67 169.66 207.54 245.32 288.21 334.66 383.52 434.74 488.83 547.44 608.97 668.39 733.88 806.07 875.60 947.82 1022.50 1099.33 0.00 286.98 286.98 287.33 285.85 281.64 278.40 276.89 275.45 273.87 272.70 272.13 271.91 271.88 272.03 272.12 272.07 272.02 271.90 271.70 271.48 271.25 271.05 270.93 270.86 270.82 270.78 270.75 270.76 270.83 2 of 5 DLS (deg/ 100f) 0.00 0.53 0.27 0.16 0.68 1.99 2.17 2.29 1.64 1.66 3.68 2.13 4.04 3.09 1.22 1.61 3.79 1.48 2.15 2.16 3.86 2.52 1.61 1.96 2.75 2.30 1.68 2.65 2.92 2.09 ------ ------ Srvy tool type Tool qual type ------ ------ TIP MWD Inc. Only MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 -------- -------- 2901.75 2993.86 3087.42 3177.94 3268.54 3363.62 3456.80 3551.35 3644.17 3737.03 3830.63 3924.13 4018.22 4112.10 4205.87 4298.21 4392.31 4485.92 4578.68 4672.62 4765.40 4858.51 4951.53 5044.57 5136.93 5230.56 5323.50 5416.76 5512.28 5606.06 ------ ------ Incl angle (deg) ------ ------ 55.83 57.17 56.67 57.99 56.69 56.32 57.89 58.22 57.98 57.07 56.56 55.74 55.88 56.62 56.21 57.21 55.87 54.90 55.85 56.17 56.99 56.53 57.58 57.27 56.87 56.27 57.46 57.55 56.46 55.28 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 272.03 270.84 270.22 270.66 270.55 269.33 269.17 269.97 269.75 270.30 270.80 270.37 270.77 271.47 270.72 270.59 271.56 271.87 270.22 270.36 270.53 271.05 270.67 270.66 270.10 269.96 269.81 271.29 271.47 271.90 ------ ------ 92.24 92.11 93.56 90.52 90.60 95.08 93.18 94.55 92.82 92.86 93.60 93.50 94.09 93.88 93.77 92.34 94.10 93.61 92.76 93.94 92.78 93.11 93.02 93.04 92.36 93.63 92.94 93.26 95.52 93.78 -------- -------- TVD depth (ft) -------- -------- 2486.41 2537.25 2588.32 2637.18 2686.07 2738.54 2789.15 2839.18 2888.23 2938.08 2989.32 3041.40 3094.27 3146.43 3198.30 3248.98 3300.86 3354.04 3406.75 3459.26 3510.36 3561.40 3611.99 3662.08 3712.29 3763.87 3814.67 3864.78 3916.79 3969.41 18-Sep-2002 05:49:07 -------- -------- Vertical section (ft) -------- -------- 1175.78 1252.59 1330.96 1407.13 1483.38 1562.62 1640.78 1720.94 1799.69 1877.99 1956.30 2033.93 2111.73 2189.78 2267.89 2345.06 2423.55 2500.59 2576.91 2654.77 2732.18 2810.04 2888.09 2966.47 3043.96 3122.06 3199.84 3278.47 3358.58 3436.21 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 18.60 20.52 21.24 21.83 22.64 22.56 21.53 20.93 20.74 20.77 21.52 22.31 23.09 24.62 26.11 26.99 28.46 30.76 32.15 32.54 33.15 34.22 35.39 36.30 36.81 36.86 36.70 37.45 39.38 41.66 -1175.82 -1252.60 -1330.99 -1407.19 -1483.46 -1562.74 -1640.97 -1721.20 -1800.00 -1878.34 -1956.67 -2034.32 -2112.14 -2190.18 -2268.29 -2345.47 -2423.96 -2500.96 -2577.27 -2655.16 -2732.60 -2810.46 -2888.52 -2966.91 -3044.43 -3122.57 -3200.40 -3279.05 -3359.14 -3436.73 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 1175.97 1252.77 1331.16 1407.36 1483.63 1562.91 1641.12 1721.33 1800.12 1878.46 1956.79 2034.44 2112.27 2190.32 2268.44 2345.62 2424.12 2501.15 2577.47 2655.36 2732.80 2810.67 2888.73 2967.14 3044.66 3122.79 3200.61 3279.26 3359.37 3436.98 270.91 270.94 270.91 270.89 270.87 270.83 270.75 270.70 270.66 270.63 270.63 270.63 270.63 270.64 270.66 270.66 27 0 .. 67 270.70 270.71 270.70 270.69 270.70 270.70 270.70 270.69 270.68 270.66 270.65 270.67 270.69 3 of 5 DLS (deg/ 100f) 0.80 1.81 0.77 1.51 1.44 1.14 1.69 0.80 0.33 1.10 0.70 0.96 0.38 1.00 0.80 1.09 1.66 1.07 1.79 0.36 0.90 0.68 1.18 0.33 0.67 0.65 1.29 1.34 1.15 1.31 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA .~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA .~/ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 -------- -------- 5699.39 5792.66 5886.08 5979.71 6073.25 6166.05 6259.59 6354.03 6447.68 6540.90 6634.89 6727.29 6821.30 6915.59 7008.40 7101.06 7195.31 7287.97 7382.17 7473.85 7567.89 7661.91 7754.08 7847.83 7941.52 8036.05 8128.90 8222.62 8315.43 8406.39 ------ ------ Incl angle (deg) ------ ------ 55.18 57.09 58.02 57.34 56.26 56.08 55.67 54.27 52.28 52.14 51.83 51.04 50.68 50.06 49.67 47.68 44.46 41.43 38.59 36.31 32.75 29.67 26.40 22.91 20.06 19.36 18.33 17.05 15.69 14.71 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 271.35 269.84 270.21 269.95 270.26 270.90 271.42 271.26 271.27 271.83 272.27 272.50 272.41 272.11 270.95 271.25 270.42 268.53 270.04 272.76 273.24 271.62 272.94 277.58 277.48 278.11 276.39 276.13 275.97 274.72 ------ ------ 93.33 93.27 93.42 93.63 93.54 92.80 93.54 94.44 93.65 93.22 93.99 92.40 94.01 94.29 92.81 92.66 94.25 92.66 94.20 91.68 94.04 94.02 92.17 93.75 93.69 94.53 92.85 93.72 92.81 90.96 -------- -------- TVD depth (ft) -------- -------- 4022.64 4074.61 4124.73 4174.79 4226.00 4277.67 4330.14 4384.35 4440.35 4497.47 4555.36 4612.96 4672.30 4732.44 4792.27 4853.45 4918.83 4986.65 5058.80 5131.58 5209.04 5289.45 5370.79 5455.99 5543.16 5632.15 5720.02 5809.31 5898.36 5986.13 18-Sep-2002 05:49:07 -------- -------- Vertical section (ft) -------- -------- 3512.87 3590.29 3669.08 3748.17 3826.40 3903.46 3980.89 4058.22 4133.27 4206.94 4280.98 4353.23 4426.14 4498.76 4569.71 4639.29 4707.14 4770.20 4830.69 4886.42 4939.71 4988.41 5031.73 5070.74 5104.89 5136.60 5166.46 5194.85 5220.94 5244.74 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 43.84 44.63 44.67 44.78 44.92 45.70 47.27 49.08 50.73 52.72 55.37 58.38 61.50 64.37 66.26 67.60 68.60 68.05 67.27 68.60 71.38 73.47 75.17 78.65 83.14 87.47 91.26 94.37 97.13 99.36 -3513.37 -3590.80 -3669.64 -3748.76 -3827.03 -3904.12 -3981.53 -4058.84 -4133.88 -4207.52 -4281.53 -4353.71 -4426.56 -4499.12 -4570.05 -4639.62 -4707.48 -4770.59 -4831.14 -4886.86 -4940.08 -4988.74 -5032.02 -5070.94 -5104.96 -5136.54 -5166.29 -5194.60 -5220.61 -5244.35 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 3513.64 3591.08 3669.91 3749.03 3827.30 3904.38 3981.81 4059.14 4134.19 4207.85 4281.88 4354.10 4426.98 4499.58 4570.53 4640.11 4707.98 4771.08 4831.61 4887.34 4940.60 4989.29 5032.58 5071.55 5105.63 5137.29 5167.10 5195.46 5221.51 5245.29 270.71 270.71 270.70 270.68 270.67 270.67 270.68 270.69 270.70 270.72 270.74 270.77 270.80 270.82 270.83 270.83 270.83 270.82 270.80 270.80 270.83 270.84 270.86 270.89 270.93 270.98 271.01 271.04 271.07 271.09 4 of 5 DLS (deg/ 100f) 0.50 2.45 1.05 0.76 1.19 0.60 0.64 1.49 2.12 0.50 0.49 0.88 0.39 0.70 1.04 2.16 3.47 3.55 3.19 3.07 3.80 3.40 3.61 4.25 3.04 0.77 1.26 1.37 1.47 1.14 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA '~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 91 92 93 94 95 96 97 98 99 100 101 102 103 -------- -------- 8499.22 8592.63 8684.79 8777.58 8871.93 8965.89 9058.35 9153.21 9245.74 9340.39 9434.77 9530.07 9553.27 Projected to TD 104 9625.00 ------ ------ Incl angle (deg) ------ ------ 13.78 12.93 12.35 11.98 11.04 10.00 9.66 9.34 9.24 8.75 ------- ------- ------ ------ Azimuth Course angle length ( deg) ( f t ) ------- ------- 275.75 284.63 283.10 279.82 281.69 282.50 282.97 283.20 280.96 279.70 8.29 279.28 7.82 279.96 7.72 279.08 7.72 279.08 ------ ------ 92.83 93.41 92.16 92.79 94.35 93.96 92.46 94.86 92.53 94.65 94.38 95.30 23.20 71.73 [(c)2002 Anadrill IDEAL ID6_1C_10] -------- -------- TVD depth (ft) -------- -------- 6076.11 6167.00 6256.93 6347.64 6440.09 6532.47 6623.57 6717.13 6808.44 6901.93 6995.27 7089.63 7112.61 7183.70 18-Sep-2002 05:49:07 -----.---- -------- Vertical section (ft) -------- -------- 5267.55 5288.84 5308.57 5327.84 5346.45 5363.33 5378.84 5394.20 5408.90 5423.53 5437.39 5450.63 5453.74 5463.30 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 101.43 105.19 110.03 113.92 117.42 121.01 124.48 128.03 131.15 133.81 -5267.10 -5288.28 -5307.86 -5327.01 -5345.51 -5362.28 -5377.68 -5392.93 -5407.53 -5422.09 Page --------------- ---------------'-- Total displ (ft) At Azim (deg) --------------- --------------- 5268.07 5289.33 5309.00 5328.23 5346.80 5363.65 5379.12 5394.45 5409.12 5423.74 271.10 271.14 271.19 271.23 271.26 271.29 271.33 271.36 271.39 271.41 136.12 -5435.88 5437.59 271.43 138.35 -5449.05 5450.80 271.45 138.87 -5452.14 5453.91 271.46 140.39 -5461.66 5463.46 271.47 5 of 5 DLS (deg/ 100f) 1.04 2.37 0.73 0.84 1.07 1.12 0.38 0.34 0.41 0.56 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA 0.49 MWD_IFR_MSA 0.50 MWD_IFR_MSA 0.67 MWD_IFR_MSA 0.00 Projected '-'" bp V-108 Schlumberger Survey Report - Geodetic Report Date: 18-Sep-02 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 271.470° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E'O.OOO fl Structure I Slot: V-Pad / V.108 TVD Reference Datum: KB Well: V-108 TVD Reference Elevation: 82.300 ft relative to MSL Borehole: V-108 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWI/API#: 500292311200 Magnetic Declination: +25.810° Survey Name I Date: V-108/ September 18, 2002 Total Field Strength: 57504.519 nT Tort I AHD I DDII ERD ratio: 146.207° / 5468.64 ft / 6.030 / 0.761 Magnetic Dip: 80.769° '~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: September 16, 2002 Location LatILong: N 70 1940.508, W 149 160.79: Magnetic Declination Model: BGGM 2002 Location Grid NlE YIX: N 5970050.460 ftUS, E 590395.420 ftUS North Reference: True North Grid Convergence Angle: +0.69032841 ° Total Corr Mag North -> True North: +25.810° Grid Scale Factor: 0.99990928 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (°) n (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970050.46 590395.42 N 70 19 40.508 W 149 160.795 189.25 1.00 286.98 189.24 1.59 0.48 -1.58 0.53 5970050.92 590393.83 N 701940.513 W 149 160.841 295.58 1.29 286.98 295.55 3.64 1.10 -3.61 0.27 5970051.52 590391.80 N 701940.519 W 149160.901 387.19 1.43 288.81 387.13 5.72 1.77 -5.68 0.16 5970052.16 590389.72 N 70 19 40.525 W 149 160.961 478.79 1.97 278.10 478.69 8.38 2.36 -8.32 0.68 5970052.72 590387.07 N 70 19 40.531 W 149 16 1 .038 572.07 3.80 271.66 571.85 13.06 2.68 -13.00 1.99' 5970052.98 590382.39 N 70 19 40.534 W149161.175 664.60 5.80 273.61 664.05 20.80 3.06 -20.73 2.17 5970053.27 590374.66 N 70 19 40.538 W 149 16 1 .400 756.88 7.91 274.33 755.67 31.80 3.83 -31.72 2.29 5970053.91 590363.66 N 70 19 40.546 W 149 16 1.721 848.70 9.28 270.18 846.45 45.52 4.33 -45.42 1.64 5970054.25 590349.96 N 701940.551 W 149 16 2.121 ~ 941 .78 10.81 268.79 938.11 61.74 4.t7 -61.65 1.66 5970053.89 590333.73 N 70 19 40.549 W 149 162.595 1036.02 14.28 269.43 1030.08 82.19 3.87 -82.12 3.68 5970053.34 590313.27 N 70 19 40.546 W 149 163.192 1129.37 16.23 270.89 1120.14 1 06.74 3.96 -106.68 2.13 5970053.13 590288.71 N 701940.547 W 149 163.909 1222.43 19.99 271.30 1208.57 135.66 4.52 -135.59 4.04 5970053.35 590259.80 N 70 19 40.552 W 149 164.753 1315.52 22.85 272.17 1295.22 169.65 5.57 -169.57 3.09 5970053.98 590225.81 N 70 19 40.563 W 149 165.745 1410.93 23.94 273.20 1382.79 207.53 7.35 -207.41 1.22 5970055.31 590187.96 N 70 19 40.580 W 149 166.850 1501.59 25.32 272.04 1465.20 245.30 9.07 -245.15 1.61 5970056.57 590150.20 N 70 19 40.597 W 149 167.952 1595.76 28.88 271.62 1549.02 288.19 10.43 -288.02 3.79 5970057.42 590107.32 N 701940.610 W 149 169.203 1689.87 30.27 271.75 1630.86 334.64 11.79 -334.45 1.48 5970058.22 590060.89 N 70 1940.624 W 149 1610.559 V-108 ASP Final Survey.xls Page 1 of 4 10/1/2002-9:01 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (°) n (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 1784.14 32.19 270.50 1711.47 383.51 12.74 -383.31 2.15 5970058.58 590012.02 N 70 1940.633 W 1491611.985 1877.75 34.18 269.88 1789.81 434.73 12.90 -434.54 2.16 5970058.13 589960.79 N 70 1940.635 W 1491613.481 1969.95 37.73 269.52 1864.43 488.83 12.61 -488.67 3.86 5970057.18 589906.68 N 701940.632 W 1491615.061 2063.34 40.07 269.14 1937.11 547.43 11.92 -547.31 2.52 5970055.79 589848.06 N 701940.625 W 149 1616.772 2157.52 41.58 269.36 2008.37 608.95 11.12 -608.87 1.61 5970054.24 589786.52 N 70 1940.617 W 1491618.570 2245.65 43.23 270.13 2073.44 668.36 10.86 -668.30 1.96 5970053.27 589727.10 N 701940.614 W 1491620.305 2339.08 45.80 270.24 2140.06 733.84 11.07 -733.80 2.75 5970052.69 589661.61 N 701940.616 W 149 1622.217 2437.91 48.07 270.41 2207.54 806.02 11 .48 -805.99 2.30 5970052.23 589589.42 N 70 19 40.620 W 149 16 24.324 2530.25 49.62 270.23 2268.31 875.53 11.87 -875.52 1.68 5970051.78 589519.91 N 70 19 40.624 W 149 16 26.354 2623.39 52.08 270.54 2327.11 947.74 12.36 -947.74 2.65 5970051.40 589447.69 N 70 19 40.629 W 149 16 28.462 .-....-Y 2716.43 54.72 271.33 2382.58 1022.43 13.59 -1022.41 2.92 5970051.73 589373.01 N 701940.641 W 149 1630.642 2809.51 56.57 272.06 2435.10 1 099.26 15.86 -1099.22 2.09 5970053.08 589296.19 N 70 19 40.663 W 149 16 32.884 2901.75 55.83 272.03 2486.41 1175.91 18.60 -1175.82 0.80 5970054.89 589219.57 N 70 1940.690 W 149 1635.120 2993.86 57.17 270.84 2537.25 1252.71 20.52 -1252.60 1.81 5970055.88 589142.78 N 701940.709 W 149 1637.362 3087.42 56.67 270.22 2588.32 1331 .1 0 21.24 -1330.99 0.77 5970055.67 589064.39 N 701940.716 W 149 1639.650 3177.94 57.99 270.66 2637.18 1407.28 21.83 -1407.19 1.51 5970055.33 588988.20 N 701940.721 W 149 1641.875 3268.54 56.69 270.55 2686.07 1483.55 22.64 -1483.46 1.44 5970055.22 588911.94 N 70 1940.729 W 1491644.101 3363.62 56.32 269.33 2738.54 1562.81 22.56 -1562.74 1.14 5970054.19 588832.66 N 701940.728 W 149 1646.416 3456.80 57.89 269.17 2789.15 1640.99 21.53 -1640.97 1.69 5970052.22 588754.46 N 701940.718 W 149 1648.700 3551.35 58.22 269.97 2839.18 1721.17 20.93 -1721.20 0.80 5970050.65 588674.25 N 701940.712 W 1491651.042 3644.17 57.98 269.75 2888.22 1799.94 20.74 -1800.00 0.33 5970049.51 588595.46 N 70 1940.710 W 149 1653.342 3737.03 57.07 270.30 2938.08 1878.26 20.77 -1878.34 1.10 5970048.60 588517.14 N 701940.710 W 149 1655.629 3830.63 56.56 270.80 2989.32 1956.58 21.52 -1956.67 0.70 5970048.40 588438.81 N 70 19 40.717 W 149 1657.916 3924.13 55.74 270.37 3041 .40 2034.22 22.31 -2034.32 0.96 5970048.26 588361.17 N 701940.725 W 149 170.182 4018.22 55.88 270.77 3094.27 2112.04 23.09 -2112.14 0.38 5970048.10 588283.35 N 701940.732 W 149 172.454 ~. 4112.10 56.62 271.47 3146.43 2190.10 24.6S -2190.18 1.00 5970048.69 588205.30 N 701940.747 W 149 174.733 4205.87 56.21 270.72 3198.30 2268.21 26.11 -2268.29 0.80 5970049.24 588127.19 N 70 1940.761 W 149177.013 4298.21 57.21 270.59 3248.98 2345.39 26.99 -2345.47 1.09 5970049.19 588050.02 N 70 1940.770 W 149179.266 4392.31 55.87 271.56 3300.86 2423.89 28.46 -2423.96 1.66 5970049.71 587971.52 N 70 1940.784 W 149 1711.557 4485.92 54.90 271.87 3354.04 2500.93 30.76 -2500.96 1.07 5970051.09 587894.50 N 701940.806 W 149 1713.805 4578.68 55.85 270.22 3406.75 2577.25 32.15 -2577.27 1.79 5970051.56 587818.19 N 70 1940.820 W 149 1716.033 4672.62 56.17 270.36 3459.26 2655.12 32.54 -2655.16 0.36 5970051.01 587740.31 N 70 1940.823 W 149 1718.307 4765.40 56.99 270.53 3510.36 2732.55 33.15 -2732.60 0.90 5970050.68 587662.88 N 70 19 40.829 W 149 17 20.567 4858.51 56.53 271 .05 3561.40 2810.42 34.22 -2810.46 0.68 5970050.82 587585.01 N 70 19 40.839 W 149 17 22.840 4951 .53 57.58 270.67 3611.99 2888.47 35.39 -2888.52 1.18 5970051.05 587506.96 N 70 19 40.850 W 149 17 25.119 V-108 ASP Final Survey. xis Page 2 of 4 10/1/2002-9:01 AM Grid Coordinates Geographic Coordinates Station ID MD Inel Azim TVD VSee N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 5044.57 57.27 270.66 3662.08 2966.87 36.30 -2966.91 0.33 5970051.01 587428.56 N 701940.859 W 1491727.408 5136.93 56.87 270.10 3712.29 3044.38 36.81 -3044.43 0.67 5970050.59 587351.05 N 70 19 40.864 W 149 17 29.671 5230.56 56.27 269.96 3763.87 3122.49 36.86 -3122.57 0.65 5970049.69 587272.92 N 701940.864 W 1491731.952 5323.50 57.46 269.81 3814.67 3200.29 36.70 -3200.40 1.29 5970048.60 587195.11 N 70 19 40.862 W 149 17 34.224 5416.76 57.55 271.29 3864.78 3278.93 37.45 -3279.05 1.34 5970048.40 587116.46 N 70 19 40.869 W 149 17 36.520 5512.28 56.46 271.47 3916.79 3359.04 39.38 -3359.14 1.15 5970049.37 587036.36 N 701940.888 W 1491738.858 5606.06 55.28 271.90 3969.41 3436.67 41.66 -3436.73 1.31 5970050.71 586958.75 N 701940.910 W 14917 41.123 5699.39 55.18 271.35 4022.64 3513.33 43.84 -3513.37 0.50 5970051.96 586882.11 N 701940.931 W 149 1743.360 5792.66 57.09 269.84 4074.61 3590.77 44.63 -3590.80 2.45 5970051.82 586804.67 N 701940.938 W 149 1745.621 5886.08 58.02 270.21 4124.73 3669.58 44.67 -3669.64 1.05 5970050.91 586725.85 N 70 19 40.938 W 149 17 47.922 ~. 5979.71 57.34 269.95 4174.79 3748.68 44.78 -3748.76 0.76 5970050.07 586646.74 N 701940.939 W 149 1750.232 6073.25 56.26 270.26 4226.00 3826.92 44.92 -3827.03 1.19 5970049.27 586568.48 N 70 1940.940 W 149 1752.517 6166.05 56.08 270.90 4277.67 3904.00 45.70 -3904.12 0.60 5970049.12 586491.40 N 701940.947 W 149 1754.767 6259.59 55.67 271.42 4330.15 3981.44 47.27 -3981.53 0.64 5970049.75 586413.98 N 70 1940.962 W 149 1757.027 6354.03 54.27 271.26 4384.35 4058.77 49.08 -4058.84 1.49 5970050.63 586336.66 N 701940.980 W 1491759.284 6447.68 52.28 271.27 4440.35 4133.82 50.73 -4133.88 2.12 5970051.38 586261.61 N 70 19 40.996 W 149181.475 6540.90 52.14 271.83 4497.4 7 4207.49 52.72 -4207.52 0.50 5970052.49 586187.96 N 701941.015 W 149 183.625 6634.89 51.83 272.27 4555.36 4281.54 55.37 -4281.53 0.49 5970054.24 586113.94 N 70 1 9 41 .040 W 149 185.785 6727.29 51.04 272.50 4612.96 4353.77 58.38 -4353.71 0.88 5970056.38 586041.73 N 70 1941.070 W 149 187.892 6821.30 50.68 272.41 4672.30 4426.68 61.50 -4426.56 0.39 5970058.62 585968.85 N701941.100 W1491810.019 6915.59 50.06 272.11 4732.44 4499.29 64.37 -4499.12 0.70 5970060.61 585896.27 N 70 19 41.128 W 149 18 12.137 7008.40 49.67 270.95 4792.27 4570.24 66.26 -4570.05 1.04 5970061.66 585825.33 N 70 19 41 .146 W 149 18 14.208 7101.06 47.68 271.25 4853.45 4639.82 67.60 -4639.62 2.16 5970062.15 585755.75 N 70 1941.159 W 1491816.239 7195.31 44.46 270.42 4918.83 4707.69 68.60 -4707.48 3.47 5970062.34 585687.89 N 70 19 41.168 W 149 18 18.220 7287.97 41.43 268.53 4986.65 4770.77 68.05 -4770.59 3.55 5970061.03 585624.80 N 701941.162 W 149 1820.063 7382.17 38.59 270.04 5058.80 4831 .27 67.27 -4831 .14 3.19 5970059.52 585564.27 N701941.154 W1491821.830 ~ p 7473.85 36.31 272.76 5131.58 4887.01 68.60 -4886.86 3.07 5970060.17 585508.55 N 70 19 41.167 W 149 18 23.457 7567.89 32.75 273.24 5209.04 4940.28 71.38 -4940.08 3.80 5970062.31 585455.30 N 701941.194 W 14918 25.010 7661.91 29.67 271.62 5289.45 4988.99 73.47 -4988.74 3.40 5970063.82 585406.62 N 701941.214 W 1491826.431 7754.08 26.40 272.94 5370.79 5032.30 75.17 -5032.02 3.61 5970065.00 585363.32 N701941.231 W1491827.695 7847.83 22.91 277.58 5455.99 5071 .29 78.65 -5070.94 4.25 5970068.00 585324.37 N 701941.265 W 1491828.831 7941.52 20.06 277.48 5543.16 5105.41 83.14 -5104.96 3.04 5970072.09 585290.31 N 701941.309 W 1491829.824 8036.05 19.36 278.11 5632.15 5137.10 87.47 -5136.54 0.77 5970076.03 585258.67 N 701941.351 W 149 1830.746 8128.90 18.33 276.39 5720.02 5166.93 91.26 -5166.29 1.26 5970079.47 585228.88 N 701941.388 W 1491831.615 8222.62 17.05 276.13 5809.31 5195.31 94.37 -5194.60 1.37 5970082.23 585200.54 N 70 19 41 .418 W 149 18 32.441 V-108 ASP Final Survey.xls Page 3 of 4 10/1/2002-9:01 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8315.43 15.69 275.97 5898.36 5221 .38 97.13 -5220.61 1.47 5970084.68 585174.50 N 701941.445 W 1491833.200 8406.39 14.71 274.72 5986.13 5245.17 99.36 -5244.35 1.14 5970086.62 585150.74 N 701941.467 W 149 1833.894 8499.22 13.78 275.75 6076.11 5267.97 1 01.43 -5267.10 1.04 5970088.42 585127.97 N 701941.487 W 1491834.558 8592.63 12.93 284.63 6167.00 5289.24 105.19 -5288.28 2.37 5970091.92 585106:75 N 70 1941.524 W 149 1835.176 8684.79 12.35 283.1 0 6256.93 5308.93 110.03 -5307.86 0.73 5970096.53 585087.11 N 701941.572 W 14918 35.748 8777.58 11.98 279.82 6347.64 5328.18 113.92 -5327.01 0.84 5970100.19 585067.92 N 701941.610 W 149 1836.307 8871.93 11.04 281.69 6440.09 5346.76 117.42 -5345.51 1.07 5970103.46 585049.38 N 701941.644 W 149 1836.847 8965.89 10.00 282.50 6532.47 5363.62 121.01 -5362.28 1.12 5970106.85 585032.57 N 70 1941.679 W 149 1837.337 9058.35 9.66 282.97 6623.57 5379.10 124.49 -5377.68 0.38 5970110.14 585017.13 N 701941.713 W 149 1837.786 9153.21 9.34 283.20 6717.13 5394.44 128.03 -5392.93 0.34 5970113.50 585001.84 N 70 19 41 .748 W 149 18 38.232 ~ 9245.74 9.24 280.96 6808.45 5409.12 131.16 -5407.53 0.41 5970116.45 584987.20 N 701941.779 W 1491838.658 9340.39 8.75 279.70 6901 .93 5423.74 133.82 -5422.09 0.56 5970118.93 584972.62 N 701941.805 W 1491839.083 9434.77 8.29 279.28 6995.27 5437.58 136.12 -5435.88 0.49 . 5970121.07 584958.80 N 70 1941.827 W 1491839.486 9530.07 7.82 279.96 7089.63 5450.80 138.35 -5449.05 0.50 5970123.14 584945.61 N 7d 1941.849 W 149 1839.870 9553.27 7.72 279.08 7112.62 5453.91 138.87 -5452.14 0.67 5970123.63 584942.51 N 701941.854 W 149 1839.960 9625.00 7.72 279.08 7183.70 5463.46 140.39 -5461.65 0.00 5970125.03 584932.98 N 70 19 41.869 W 149 18 40.238 ~' V-108 ASP Final Survey. xis Page 4 of 4 10/1/2002-9:01 AM Schlum~ergep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-6711 ATTN: Beth Wen Job # Log Description V-103 V-103 \1-103 V-103 V-103 22476 OH EDIT PP, ARC & ADN LWD (PDC) 22476 MD VISION RESISTIVITY . 22476 TVD VISION RESiStiVITY 22476 MD VISION DENINEÙTRON 22476 TVDVISION DENINEUTRON V-107 V-107 V-107 'v-107 V.107 22474 OH EDIT PEX, AIT & BHC (PDC) 22474 PEX RESISTIVITY 2'2474 PEX SONIC 22474 PEX NEUTRON/DEN 22474 PEX CAUPÉR ~ Od-llo&J V-108 V-108 V.108 V.108 V-108 V.108 V.108 22468 OH EDIT MWD/GRlRES/DEN.NEUTRON (PDC) 22468 MD VISION RESISTIVITY 22468 TVD VISION RESISTIVITY 22468 MD VISION DENINEUTRON-QUADRANT 22468 TVD VISION DEN/NEUTRON-QUADRANT 22468 MD VISION-SERVICE' " 22468 TVD VISION-SERVICE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd. . Anchorage AK 99508-4254~ .. Date Delivered: U~ ~ ~~ 10/01/02 10/01/02 10/01/02 10/01/Ó2 10/01/02 10/13/02 1 Ó/13/02 1oi13/02 10/13/02 10/13/02 09/18/02 09/18/02 09/18/02 09/18/02 09/18/02 09/18/02 09/18/02 NO. 2519 10/31/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date Borealis P. Bay Color Sepia Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Received by: BL CD ~ '-' RECEIVED NOV 0 1 2002 Alaska O¡i & Gas Cons. CommiSlion Anchorage .) ) ~ 0;>'- / lotp MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V -1 08 Date Dispatche 24-Sep-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys 2 RECEIV'ED O. Y'T On 2fìNJ ''v ¡ ~' '\J\;m Masks Q¡~ & Gas GŒ¡5. 0:nnmi5skm Anchorage Received ./ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ') ~~~1JŒ ill)~ ~ \ , ) TONY KNOWLES, GOVERNOR AI1ASIiA. OIL AND GAS CONSERVAnONCO~SSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit V-108 BP Exploration (Alaska), Inc. Permit No: 202-166 Surface Location: 4805' NSL, 1906' WEL, Sec. 11, T11N, RIlE, UM Bottomhole Location: 4984' NSL, 2091' WEL, Sec. 10, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above development well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, c~~~~~~ Chair BY ORDER OF THE COMMISSION DATED this~ay of August, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 'f \tJtJ ~ J ILl 0 t. '\ STATE OF ALASKA~\ :::r¡r- 8/t':>,f~ ALASKA ~,fL AND GAS CONSERVATION COM~,. ..1SION 14 PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [] Exploratory [] Stratigraphic Test II Development Oil [] Service[] Development Gas [] Single Zone [] Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 82.3' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028241 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ./ V-108 9. Approximate spud date 08/31/02 ./ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9536' MD /7087' TVD 0 17. Anticipated pressure {~e 20 MC 25.035 (e) (2)} 57 Maximum surface 2851 psi~, At total depth (TVD) 6790' /3530 pSiQ Setting Depth TQP Rotom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 3261' 2682' Surface Surface 9536' 7087' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill [] Redrill [] Re-Entry [] Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4805' NSL, 1906' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 4974' NSL, 1970'WEL, SEC. 10, T11N, R11E, UM At total depth 4984' NSL, 2091' WEL, SEC. 10, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028240, 2091' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 500' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casing WeiQht Grade Coupling 20" 91.5# H-40 Weld 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC..M Number 2S100302630-277 Hole 42" 12-1/4" 8-3/4" LenÇJth 80' 3231' 9506' Ouantitv of Cement (include stace data) ,260 sx Arctic Set (Approx.) 509 sx PF 'L', 339 sx Class 'G' 252 sx Class IG', 179 sx Class 'G' / 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RE(:EI r: ~w.' .", l. !(' n P CiO/f)? h h.J ',.J oj L I.L Perforation depth: measured Alaska Oil & Gas GtH1S. L;OiiUìliSSIOP Anchorage true vertical 20. Attachments II Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch II Drilling Program II Drilling Fluid Pr: ram [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer NameINumber: James Fr. n , 564-4468 Prepared By Name/Number: Terrie Hubble, 564-4628 21,'~~:~:~;~roÆ&~~:;::£;~i~;~~~~~y,,:,;;;~,,; Date. $--r-ð:Z- Permit Nu~ber \ ' APINu~b~r" ., ,'. ." v ",,1.. e., ,', ,~, ~ ..-... 'Ap~r~~~I"Ö~te' See cover lett~r ,~ð ? -¥ ç; 50- a 2.. ?.... 2..3 /1 ¿ i/;¡~ h ~ for other reQuirements Conditions of Approval: Samples Required 0 Yes J81 No Mud Log Required 0 Yes B No Hydrogen Sulfide Measures 0 Yes ]8" No Directional Survey Required EYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Të S'E- toP Ë tð 'f SOO PSt. Onglnal Signed By Approved By C..?mffi¥ ~sli T ~yIO!' Form 10-401 Rev. 12-01-85 by order of 0 RT~1N A L the commission Date 3/d.d. /na. Submi/in Triplicate ') ") IWell Name: V-108 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 590,395.42' Y = 5,970,050.46' 4805' FSL (474' FNL), 19061 FEL (3373' FWL), Sec. 11, T11N, R11E X = 585,050.00' Y = 5,970,157.00' 4974' FSL (305' FNL), 1970' FEL (3309' FWL), Sec. 10, T11N, R11E X = 584,928.48' Y = 5,970,166.29' 4984' FSL (295' FNL), 20911 FEL (3188' FWL), Sec. 10, T11N, R11E I AFE Number: I BRD5M4050 I I Estimated Start Date: 18/31/2002 I I MD: 19536' I TVD: 17087' I I RiQ: I Nabors 9ES / I OperatinQ days to complete: 114 RT/GL: 128.5' I 1 RKB: 182;3' I Well DesiQn (conventional, slim hole, etc.): I Ultra Slimhole (Iongstring) I Objective: I Single zone producer into the Kuparuk formation. Mud Program: 12 %" Surface Hole (0-3261 '): Initial Base PF to top SV SV toTO Densitv (ppg) 8.5 - 9.2 / 9.0 - 9.5 9.5 max Viscosity (seconds) 250-300 200-250 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 - 70 15 - 20 30 - 45 < 10 20 - 40 < 10 8.5-9.5 8.5-9.5 8.5-9.5 8 3A" Production Hole (3261' - 9536'): LSND Interval Density Tau 0 YP PV pH API 10' Gel (ppg) Filtrate Upper 9.7 4-7 25-30 1 0-15 8.5-9.5 6-10 10 Interval Top of HRZ 10.3 ./ 3-7 20-25 1 0-15 8.5-9.5 4-6 10 toTO V-108 Drilling Program-Draft Page 1 ) ) Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1869' 550 4" 17.5# 90 1800 10.0 N/A 18,18,18,16 .942 1869'-3261 ' 650 4" 17.5# 110 2400 10.2 N/A 18,18,18,16 .942 Production Hole: 8 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3261' - 9536' 600 4" 17.5# 240 3400 11.2 N/A 3x14,3x15 .969 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-3261' Surface Superior hole cleaning practices at to SV-1 connections will greatly enhance cuttings transport in the sliding mode 185 60 500 9.5 Acceptable 210 60 600 9.5 Acceptable 200 80 500 9.5 Acceptable 235 80 600 9.5 Acceptable 260 80 700 9.5 Acceptable 205 100 500 9.5 Acceptable 250 100 600 9.5 Acceptable 315 100 700 9.5 Acceptable 3261 '-9536' 9-5/8" to Sweeps and fully reamed connections TD to maintain minimum hole cleaning requirements 300 60 550 9.7 Acceptable 325 80 600 9.7 Acceptable 340 60 700 9.7 Acceptable 200 80 550 10.1 Acceptable V-108 Drilling Program-Draft Page 2 Directional: Ver. Anadrill P3 KOP: 500' Maximum Hole Angle: Close Approach Wells: WKUPST -01 Logging Program: Surface Intermediate/Production Hole Formation Markers: Formation Tops SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 Na WS1 Oa Obf Base CM2 (Colville) THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) TD Criteria V-108 Drilling Program-Draft ) ) 57 deg at 2804' MD All wells pass 1/200 minor risk criteria. WKUPST-01 - P&A'd Exploration well drilled blind IFR-MS corrected surveys will be used for survey validation. GyroData will be needed for surface issues to 1000' MD. Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: TVDss 1535 1665 1700 2050 2300 2545 2870 3203 3582 3960 4200 4355 4700 4955 6255 6420 6480 6500 6520 6680 6790 6860 MWD 1 GR None None MWD/GR/PWD/RES/DENS/NEUT/AZM DENS Estimated pore pressure, PPG Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon Bearing, 10 ppg EMW Hydrocarbon Bearing, 10 ppg EMW -,,' 10,) Non-Hydrocarbon Bearing, 10 ppg EMW 150' MD below Miluveach top Page 3 ) / CasingITubing Program: / Hole Csgl WtlFt Grade Size TbQ O.D. 42" Insulated 20" 91.5# 12 %" 9 5/8" 40# 8 3A" 711 26# Tubing 3 Y211 9.2# Conn Length H-40 WLD 80' L-80 BTC 3231' L -80 BTC-m 9506' L-80 BTC-m 8865' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT ) Top MDrrVD GL GL GL GL Btm MDrrVD bkb 11 0/11 0 3261 '/2682' 9536'/7087' 8865'/6440' EMW 12.1 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on 1869' of annulus in the permafrost @ 225% excess and 517' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 875' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2386' MD Total Cement Volume: Lead 377 bbl I 2113fe I 509 sks of Halliburton Permafrost L at 10.7 ppg and 4.15 dIsk. Tail 70 bbl I 390 fe I 339 sks of Halliburton 'G' at 15.8 ppg and 1 .15 cf/sk. /" Casinq Size 17" Production Longstring 1 Basis: Stage 1: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: Tail from shoe to 8564' MD, lead from 8564' to 5550' - 500' above NA sands Total Cement Volume: Lead 105 bbls I 589 fe I 252 sks of Halliburton Premium "G" at 12.5 ppg and 2.34cf/sk. Tail 37 bbl 1207 fe I 179 sks of Halliburton 'G' at 15.8 ppg and 1.16 dIsk. V-108 Drilling Program-Draft / Page 4 ) ) Well Control: / Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future fracture stimulation treatment, the BOP equipment will be tested to 4500 psi. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: 3530 psi @ 6790' TVOss - Kuparuk A Sands . Maximum surface pressure: 2851 psi @ surface ./ (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: 4500 psi (The casing and tubing will be tested to 4500 psi as /' required for fracture stimulation.) . Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg diesel ./ Disposal: . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class" wastes to OS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V -108 Drilling Prog ram-Draft Page 5 ) ^) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in Feb. 2002. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 14" drilling assembly with MWD/LWD(page 4) and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. -"An intermediate wiper/bit trip to surface for a will be performed prior to exiting the Permafrost. / 4. Run and cement the 9-5/8", 40# surface casing back to surface. ./ 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4500 psi. 6. MU 8-3/4" drilling assembly with MWD/LWD(page 4) and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. ~ 7. Drill out shoe joints and displace well to 9.7 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead to first wiper trip. 9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.3 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to TD at -150' below Top Miluveach. 11. Condition hole for running 7" 26# long-string casing. / 12. Run and cement the 7" production casing in a single stage. (To be reviewed based on log results.) Displace the cement with 8.5 ppg heated filtered seawater if single stage. 13. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morr1ingA~port. /' 14. T é$tçásil1gtp 4$OOp$ìf()r3Þrnihùt~$. / . / 15. Run the 3-1/2", 9.2#, L-80 BTC-m completion assembly. Set packer and test the tubing to 4500 psi / and annulus to 4500 psi for 30 minutes. Shear RP valve and install TWC. Test below to 1000 psi. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 17. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 18. Rig down and move off. V-108 Drilling Program-Draft Page 6 ) ') V-108 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ Check the landing ring height on V-108. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" ;;;,~"''',>~.~.')'': Job 2: DrillinQ Surface Hole ~ There is one nearby well issue in the surface hole. Refer to page 4 for details. ~ GyroData survey will be required per the directional plan to 1000' MD or until the magnetic interference at the surface has dissipated. ~ Gas hydrates have been observed in wells drilled on V-Pad. These were encountered near the base of permafrost to TO in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations )Il,'m'mx:4..~~)$ Job 3: Install surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 225% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at ::1:1 OOO'MD to allow remedial cementing. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 300/0 excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Halliburton Cement Program" .:. "Surface Casing Port Collar Procedure" ~'1i»~'~-'- < .~.»>,-""""",=,,,.,.,.,>:,,,,,,,,,,,,,:~.~ ,.~~~ V -108 Drilling Program-Draft Page 7 ) ') Job 7: DrillinQ Production Hole Hazards and Contingencies ~ V-108 will cross the same fault twice - once at the base of the Ugnu at - 3682'TVDrkb (+/- 250') and the second time in the lower Colville at-6257'TVDrkb (+/- 150'). The estimated throw of the fault is 90'. The well will be - 57 degrees and 15 degrees respectively when crossing the fault. Lost circulation is considered a risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ K'P~-rP~~~~NÇJ;:lritb~~~$ø$ç~Öf1rió. Óf1Qppg þqrøPrø$$Qré~ttb$K~Pf1rQkt~rg~tQ~Þ~~; QéltJgr~91~~~n~9~q~~Ør~9i~rt()f~?.18Rg,~tm~~p~~çeË~~in.$§ng~i...1p:$ PP~~H9jptr~.holé/ tbøldckt9lerémç~ '~~l)i6bl:'j'~l>AI)~çç.....~J~~P-r YliHb~ r~ql.Jir~(t ..~~..W~II~~ h~ig"'J~I)~çI aWétr~"~$$fQtldçl( çlE!t~ti9r)~G<:>rit~pt. [i)tìlliD9M~riág~tif l.QTi$lé$§1~élri1gl1pþg~ ~ V-Pad development wells have "kick tolerances" in the 25-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals ~ There is one "close approach" issue with the production hole interval of V-108. The exploration well WKUPST -01 which is a P&A'd well was drilled blind in this area. Be aware of the possibility for magnetic interference when drilling from 7500' MD to 8700' MD. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. HShale Drilling- Kingak & HrZ" ~);»X~'~').m'AA."1$.'m:m¡{.~ilm:<mm. Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The interval is planned to be cemented in a single stage with a 12.5 ppg lead (500'MD above the Schrader) and a 15.8 ppg tail (500' above the Kuparuk). If, at the discretion of the company representative, a single stage cement job is deemed to risky, then a 2 stage cement job will be performed. >- Ensure the lower production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 63 bbls of dead crude (2300' MD, 2221 'TVD), the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ../ ~ Ensure a minimum hydrostatic equivalent of 10.3 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be issued detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. V-108 Drilling Program-Draft Page 8 ) ) Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" jlWmm.;-m;1'$~~M~"":wm Job 12: Run Completion Hazards and Contingencies )- Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalance if there is a casing integrity problem. )- Shear valves have been failing at lower than the 2500 psi differential pressure. When test annulus maintain no more than a 1500 psi differential: 3000 psi tubing pressure, 4500 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus "1~~«~,ff,.~""',,,,,,,,,,,,,,,,,.. Job 13: ND/NU/Release RiQ Hazards and Contingencies )- No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus »««...c~~_."'- V -108 Drilling Program-Draft Page 9 .J bp V-108 Schlumbøruep Proposed Well Profile - Geodetic Report Report Date: July 29, 2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 271.900° Field: Prudhoe Bay Unit - WOA (Drill Pads) y Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V-Pad / V-1 08 Illty tll TVD Reference Datum: KB Well: V-108 II1II TVD Reference Elevation: 82.3 ft relative to MSL Borehole: V-108 Fea51 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWI/API#: 50029 Magnetic Declination: 25.815° Survey Name I Date: V-108 (P3) / July 29,2002 Total Field Strength: 57504.304 nT Tort I AHD I DDII ERD ratio: 99.237° 15469.46 ft /5.863/0.771. Magnetic Dip: 80.769° ..........-' Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: September 11, 2002 Location LatlLong: N 70.32791886, W 149.26688753 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5970050.460 ftUS, E 590395.420 ftUS North Reference: True North Grid Convergence Angle: .¡{).69032841 ° Total Corr Mag North .> True North: +25.815° Grid Scale Factor: 0.99990928 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim TVD I VSec I N/.S E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) KBE 0.00 0.00 271.54 0.00 0.00 0.00 0.00 0.00 5970050.46 590395.42 N 70.32791886 W 149.26688753 Base Gubik 327.30 0.00 271.54 327.30 0.00 0.00 0.00 0.00 5970050.46 590395.42 N 70.32791886 W 149.26688753 KOP Bid 1/100 400.00 0.00 271.54 400.00 0.00 0.00 0.00 0.00 5970050.46 590395.42 N 70.32791886 W 149.26688753 Bid 2.5/100 500.00 1.00 271.54 499.99 0.87 0.02 -0.87 1.00 5970050.47 590394.55 N 70.32791892 W 149.26689459 600.00 3.50 271.54 599.91 4.80 0.13 -4.80 2.50 5970050.53 590390.62 N 70.32791922 W 149.26692646 700.00 6.00 271.54 699.56 13.08 0.35 -13.07 2.50 5970050.65 590382.35 N 70.32791982 W 149.26699352 800.00 8.50 271.54 798.75 25.70 0.69 -25.69 2.50 5970050.84 590369.73 N 70.32792075 W 149.26709586 900.00 11.00 271.54 897.30 42.63 1.15 -42.62 2.50 5970051.10 590352.79 N 70.32792200 W 149.26723314 SV6 966.41 12.66 271.54 962.30 56.25 1.51 -56.23 2.50 5970051.29 590339.18 N 70.32792299 W 149.26734351 ~if 1000.00 13.50 271.54 995.01 63.85 1.72 -63.82 2.50 5970051.41 590331.59 N 70.32792356 W 149.26740506 1100.00 16.00 271.54 1091.71 89.30 2.40 -89.27 2.50 5970051.78 590306.14 N 70.32792542 W 149.26761143 1200.00 18.50 271.54 1187.21 118.95 3.20 -118.91 2.50 5970052.23 590276.49 N 70.32792760 W 149.26785178 1300.00 21.00 271.54 1281.32 152.74 4.11 -152.69 2.50 5970052.73 590242.71 N 70.32793009 W 149.26812571 1400.00 23.50 271.54 1373.86 190.60 5,12 -190.54 2.50 5970053.28 590204.85 N 70.32793284 W 149.26843264 1500.00 26.00 271.54 1464.67 232.47 6.25 -232.39 2.50 5970053.91 590162.99 N 70.32793593 W 149.26877200 1600.00 28.50 271.54 1553.56 278.25 7.48 -278.15 2.50 5970054.59 590117.23 N 70.32793928 W 149.26914307 SV5 1673.17 30.33 271.54 1617.30 314.18 8.44 -314.08 2.50 5970055.11 590081.29 N 70.32794190 W 149.26943443 1700.00 31.00 271.54 1640.38 327.87 8.81 -327.75 2.50 5970055.32 590067.62 N 70.32794291 W 149.26954528 V-108 (P3) report.xls Page 1 of 3 7/29/2002-11 :06 AM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim TVD VSec N/-S E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1800.00 33.50 271.54 1724.94 381 .22 10.25 -381.09 2.50 5970056.12 590014.27 N 70.32794684 W 149.26997782 SV4 1826.92 34.17 271.54 1747.30 396.21 10.65 -396.07 2.50 5970056.34 589999.29 N 70.32794793 W 149.27009930 End Bid 1839,02 34.48 271.54 1757.30 403.04 10.83 -402.90 2.50 5970056.43 589992.46 N 70.32794842 W 149.27015468 Base Perm 1869.35 34.48 271.54 1782.30 420.20 11.29 -420.06 0.00 5970056.69 589975.29 N 70.32794967 W 149.27029383 Bid 2.5/100 1899.68 34.48 271.54 1807.30 437.37 11.75 -437.22 0.00 5970056.94 589958.13 N 70.32795093 W 149.27043299 1900.00 34.48 271.54 1807.57 437.55 11.76 -437.40 2.50 5970056.95 589957.95 N 70.32795096 W 149.27043444 2000.00 36.98 271.54 1888.73 495.95 13.33 -495.78 2.50 5970057.82 589899.56 N 70.32795523 W 149.27090785 2100.00 39.48 271.54 1967.28 557.83 14.99 -557.64 2.50 5970058.73 589837.69 N 70.32795976 W 149.27140948 2200.00 41.98 271.54 2043.05 623.08 16.75 -622.86 2.50 5970059.70 589772.46 N 70.32796455 W 149.27193836 2300.00 44.48 271.54 2115.90 691.57 18.59 -691.33 2.50 5970060.72 589703.98 N 70.32796956 W 149.27249359 -- SV3 2323.11 45.06 271.54 2132.30 707.84 19.02 -707.60 2.50 5970060.95 589687.71 N 70.32797073 W 149.27262552 2400.00 46.98 271.54 2185.69 763.17 20.51 -762.91 2.50 5970061.78 589632.39 N 70.32797479 W 149.27307404 2500.00 49.48 271.54 2252.30 837.75 22.52 -837.46 2,50 5970062.89 589557.83 N 70.32798026 W 149.27367857 2600.00 51.98 271.54 2315.58 915.16 24.60 -914.85 2.50 5970064.03 589480.42 N 70.32798592 W 149.27430614 2700.00 54.48 271.54 2375.43 995.26 26.75 -994.92 2.50 5970065.22 589400.34 N 70.32799176 W 149.27495543 SV2 2711.86 54.78 271.54 2382.30 1004.94 27.01 -1004.59 2.50 5970065.36 589390.67 N 70.32799247 W 149.27503385 2800.00 56.98 271.54 2431.73 1077.90 28.97 -1077.53 2.50 5970066.44 589317.72 N 70.32799780 W 149.27562533 End Bid 2804.65 57.10 271.54 2434.26 1081.80 29.07 -1 081.43 2.50 5970066.50 589313.82 N 70.32799807 W 149.27565695 SV1 3160.04 57.10 271.54 2627.30 1380.18 37.09 -1379.71 0.00 5970070.92 589015.49 N 70.32801984 W 149.27807575 9-5/8" Csg pt 3261.29 57.10 271.54 2682.30 1465.20 39.38 -1464.70 0.00 5970072.19 588930.49 N 70.32802606 W 149.27876494 UG4a 3758.37 57.10 271.54 2952.30 1882.55 50.60 -1881.91 0.00 5970078.38 588513.21 N 70.32805645 W 149.28214817 UG3 4371.44 57.10 271.54 3285.30 2397.28 64.43 -2396.46 0.00 5970086.01 587998.58 N 70.32809383 W 149.28632075 UG1 5069.19 57.10 271.54 3664.30 2983.11 80.17 -2982.09 0.00 5970094.69 587412.86 N 70.32813626 W 149.29106976 Ma 5627.02 57.10 271.54 3967.30 3451.47 92.76 -3450.29 0.00 5970101.64 586944.58 N 70.32817011 W 149.29486651 Na 6050.46 57.10 271.54 4197.30 3806.99 102.32 -3805.69 0.00 5970106.92 586589.13 N 70.32819576 W 149.29774855 Oa 6372.64 57.10 271.54 4372.30 4077.49 109.59 -4076.10 0.00 5970110.93 586318.67 N 70.32821523 W 149.29994138 ~ Crv 3/100 6594.52 57.10 271.54 4492.82 4263.79 114.59 -4262.33 0.00 5970113.68 586132.41 N 70.32822861 W 149.30145158 6600.00 56.94 271.54 4495.81 4268.38 114.72 -4266.93 3.00 5970113.76 586127.81 N 70.32822895 W 149.30148888 6700.00 53.94 271.54 4552.53 4350.72 116.93 -4349.24 3,00 5970114.97 586045.49 N 70.32823486 W 149.30215636 6749.68 52.45 271.54 4582.30 4390.50 118.00 -4389.00 3.00 5970115.57 586005.72 N 70.32823772 W 149.30247879 6800.00 50.94 271.59 4613.49 4429.98 119.08 -4428.47 3.00 5970116.17 585966.25 N 70.32824061 W 149.30279886 6900.00 47.94 271.70 4678.51 4505.94 121.26 -4504.39 3.00 5970117.44 585890.31 N 70.32824644 W 149.30341452 7000.00 44.94 271.82 4747.42 4578.39 123.48 -4576.81 3.00 5970118.78 585817.88 N 70.32825239 W 149.30400180 Obf Base 7034.84 43.89 271.86 4772.30 4602.77 124.26 -4601.18 3.00 5970119.27 585793.50 N 70.32825448 W 149.30419943 7100.00 41.94 271.95 4820.02 4647.14 125.73 -4645.53 3.00 5970120.20 585749.14 N 70.32825842 W 149.30455908 V-108 (P3) report.xls Page 2 of3 7/29/2002-11 :06 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7200.00 38.94 272.10 4896.12 4712.00 128.02 -4710.35 3.00 5970121.71 585684.31 N 70.32826456 W 149.30508473 7300.00 35.94 272.27 4975.51 4772.79 130.33 -4771.09 3.00 5970123.29 585623.55 N 70.32827077 W 149.30557729 CM2 7375.27 33.69 272.41 5037.30 4815.76 132.08 -4814.03 3.00 5970124.52 585580.59 N 70.32827548 W 149.30592551 7400.00 32.95 272.46 5057.97 4829.34 132,66 -4827.60 3.00 5970124.94 585567.02 N 70.32827704 W 149.30603556 7500.00 29.95 272.69 5143.27 4881.50 135.00 -4879.71 3.00 5970126.65 585514.89 N 70.32828334 W 149.30645814 7600.00 26.95 272.96 5231 .18 4929.13 137.34 -4927.28 3.00 5970128.42 585467.30 N 70.32828964 W 149.30684391 7700.00 23.95 273.30 5321.47 4972.09 139.68 -4970.19 3.00 5970130.24 585424.37 N 70.32829596 W 149.30719189 7800.00 20.96 273.73 5413.87 5010.27 142.02 -5008.31 3.00 5970132.12 585386.23 N 70.32830228 W 149.30750102 7900.00 17.96 274.29 5508.15 5043.56 144.33 -5041.54 3.00 5970134.03 585352.97 N 70.32830853 W 149.30777050 End Crv 7999.06 15.00 275.06 5603.13 5071.63 146.61 -5069.55 3.00 5970135.97 585324.94 N 70.32831471 W 149.30799766 <- CM1 8194.90 15.00 275.06 5792.30 5122.24 151.08 -5120.04 0.00 5970139.83 585274.41 N 70.32832683 W 149.30840712 Top HRZ 8759.13 15.00 275.06 6337.30 5268.05 163.97 -5265.51 0.00 5970150.97 585128.80 N 70.32836177 W 149.30958684 Base HRZ 8929.95 15.00 275.06 6502.30 5312.19 167.88 -5309.55 0.00 5970154.35 585084.73 N 70.32837237 W 149.30994399 K-1 8992.07 15.00 275.06 6562.30 5328.25 169.30 -5325.56 0.00 5970155.57 585068.70 N 70.32837621 W 149.31007383 Kuparuk Target 9064.54 15.00 275.06 6632.30 5346,97 170.95 -5344.24 6.00 5970157.00 585050.00 N 70.32838068 W 149.31022532 Top Kuparuk 9074.89 15.00 275.06 6642.30 5349.65 171.19 -5346.91 0.00 5970157.21 585047.33 N 70.32838134 W 149.31024697 KupC 9095.59 15.00 275.06 6662.30 5355.00 171.66 -5352.25 0.00 5970157.61 585041 .99 N 70.32838261 W 149.31029028 LCU I Kup B 9199.12 15.00 275.06 6762.30 5381.75 174.03 -5378.94 0.00 5970159.66 585015.27 N 70.32838903 W 149.31050673 KupA 9313.00 15.00 275.06 6872.30 5411.18 176.63 -5408.30 0.00 5970161.91 584985.89 N 70.32839608 W 149.31074483 TMLV 9385.48 15.00 275.06 6942.31 5429.91 178.28 -5426.99 0.00 5970163.33 584967.18 N 70.32840055 W 149.31089640 TD I 7" Csg Pt 9535.47 15.00 275.06 7087.19 5468.68 181.71 -5465.66 0.00 5970166.29 584928.47 N 70.32840984 W 149.31121001 LeÇlal Description: Surface: 4805 FSL 1906 FEL S11 T11N R11E UM : 4922 FSL 1015 FEL S10 T11N R11E UM Kuparuk Target: 4974 FSL 1970 FEL S10 T11N R11E UM BHL: 4984 FSL 2091 FEL S10 T11N R11E UM NorthinÇl ey) rftUSl EastinÇl eX) rftUSl 5970050.46 590395.42 5970115.57 586005.72 5970157.00 585050.00 5970166.29 584928.48 ~ V-108 (P3) report.xls Page 3 of3 7/29/2002-11 :06 AM - +-' <D- ~~ g~ 0 0) C\ > II ~ c CO ;.~ -..- 0 ..c~ +-'C\ Q.CX) 0)-..- om -~ ro .. o't- .- 0) to::: <D > > <D 0) :Jw L... r- -) VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska V-loa (P3) Prudhoe Bay Unit - WOA Schlumberger Structure: V-Pad Section At: 271.90 deg Date: July 29, 2002 -2000 -.."+.., .....;.... .....¡..... .....>.... ....~.... 0-,.....,;.... - , , , i KOP Bid 1I1p0400 MD 400 TVD '~~;l~~:;~~=-= End Blþ 1839 MD 1757 TVD 34.48. i 271,54. az 403 departure ------ , - - - - , ----------: Hase Gut.:¡k :~2:: MD ~Q? '1"\/D - --:- - - - -------- ----- -------- ------- ------ ----- Bid i2.5I100 1900 MD 1807 TVD ¡SV6 ,J;òß MD 8<!2 TVD / / 34_~. 271,54. az 437 departure ¡ ~-= := .~ ErId Bid 2805 MD 2434 TVD i " = :: =: ;7 5410=27I?4~Z J];82~paßure1~~~1¿;,;;;¡g er;:;1~ ~.;; 1n2 -Nr¡ :: ~ - '3~Sl8~C'9-Pr:>,~"'.'::!['¡ .78~.!.ú_.. ,"' ,".' .'" ,-., --, - -- - - - - - - - - - ~%~'~":b~;f= '='::" ='="~"'j:~~:;;= ~ = = = - - - ,..ti9.'d..,An,gl.~ §,7 J o.,~ .... ...j.. ...n '..., .... ------ 2000 - -- - - - --.f---- ----- ...., "[",,)(3:;' 437'1 ~Ö 32i)'5 'f':ib .. ----- ...¡.. ..m : Cry 3/100 ! -~~i!~;D~~ - - - - ....¡. 'Un 'm' .m' m.. m.. . ¡UG1 5069 MD 3664 TVD ....;. 4000 -..+, :"1Mä:::5çäi:M[f:'::mi57T\~tj .. '1,a GO';õ1'¡¡[)419TrVD "TO.;'637=3" MD"'4372' "pJi)" ::::1:-....":::.. - - - - - - - - - - - - ..n ..~. . , . , ...tOtlŠai~'ë-' 7(-::35 r...~o- 4772 T"ib "'1 UTe~l:r 737"5 r~1õ" Sö"37 f"VD .. End Cry 7999 MD 5603 TVD 15,00. 275,06. az - - -: ~72.2epa.!!ur,,- - - - -- - - . , . . , , ----------- , . - - - - l:~MT (111) MD !)"F§"2 TVi:: - 6000 -,. "Hóld'AnglèlS:ÖQO . ""¡{üpä,uk'rärgët ' 9065 MD 6632 TVD -' - ]50.9:: ~50§: az,= ,..." ..... ;;!;ï34U,1eP.ïjituf.i;k ....,. . . , . "'¡7 op'"f1RZu 375~ Mü" 61~.7 ry~ ....1 , . ----------------------- ~ ~ ~ ~ = = = ~ j,':~~"j~,:~]~:'f~:'~~- t~: '=", = _.=-~ - - - 1 : (...'H. V H~~~;t3 :v1U 0H4;' I \it) : ..... ..... ..... ..... ,'m ...... ------ 8000 -, Tq/ T' Csg Pt 9535 MD 7087 TVD 15:00. 275.06. az 54~9 departure 10000 -" I -2000 I 0 I 6000 I 2000 I 4000 Vertical Section Departure at 271.90 deg from (0.0, 0.0). (1 in = 2000 feet) 2000 - ^ ^ ^ I ~ 0:: 0 Z 1000 - 0-. I ~ :::J 0 -1000-. (j) V V V -2000 -., Client: Well : Field: Structure: Scale: Date: PLAN VIEW BP Exploration Alaska V-I08 (P3) Prudhoe Bay Unit - WOA V-Pad 1 in = 1000 ft 29-Jul-2002 -6000 , -4000 -5000 I Tier Tarpet Kuparuk Targ~ 9065 MO 6632,IYI?", '1500; 27500j az J171 N 53441 End Cry TO / T" Csg PI '. . i 7999 MD 5603 TVD 9535 !:MD 7087 TVD i, 1. 5,00' 275,06' az 15.00' 275,06' az Vi 147 N 5070 W 182~ 5466W : ~; \ HOld AzimutH 275 06° \ , ,. Cry 3/100 , 6595 MP 4493 TVD 57.10' !271,54' az 115N ~262W I -6000 I -5000 I -4000 «< WEST -3000 I -2000 . . . , . . Hold Azimuth 271.54° I I -3000 I -2000 EAST »> -1000 , 0 I True North Mag Dee ( E 25.82° ) 9-518" Csg PI 3.291...M.Q,,2\?RI'i' 57,10' 271,54' a;l 39N 1465W ¡ Bid 2,51100 ) End Bid 1900MD 1807TVD ¡ 1839MD 1757TVD 34,48' 271,54' az ¡ 34.48' 271.54' az 12N 437/1W : 11 N B::32:1oo i 500 MO 500 TVD i/' 1,00' 271,54' az œ-k'"::. ¡ KOP Bid 11100 400 MO 400 TVD 0.00' 271,54' az 0 N 0 E ~t i End Bid i 2805 MO 2434 TVO i 57,10' 271,54' az i 29N 1081 W ....(u ; I -1000 i I 0 Schlumberger 1000 ., u",.- 2000 ---" . o@uo- 1000 ,.--0 -....-r' .- -1 000 ".~ -2000 1000 ,) Schlumberger Anticollision Report ) COmpaD)': Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB V Pad V-108 Plan V-108 Date: 7/29/2002 Time: 11 :30:39 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: V-108, True North V-108 plan 82.3 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 100.00 ft Depth Range: 28.50 to 9535.47 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse T rav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 7/18/2002 Validated: No Planned From To Survey ft ft 28.50 1000.00 1000.00 9535.47 Version: Toolcode 4 Tool Name Planned: Plan #3 V1 Planned: Plan #3 V1 GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station Casing Points 3261.29 2682.30 9535.47 7087.19 Diämetër in 9.625 7.000 . HoleSiie in 12.250 8.750 95/8" 7" Summary I '. < I Site Reference Offsët Ctr~Ctr. .. . No~Go Allowäblë MD MD DiståöceNea Dëviätion Warning ft ft ft ft ft WKUPST-01 WKUPST-01 V1 8216.95 5800.00 2525.35 0.00 2525.34 Pass: Minor 1/200 V-100 V-100 V7 492.58 500.00 386.74 8.12 378.62 Pass: Major Risk V-101 V-101 V7 499.37 500.00 33.95 8.15 25.81 Pass: Major Risk V-102 V-102 V5 497.65 500,00 151.42 9.49 141.93 Pass: Major Risk V-103 Plan V-103 V3 Plan: PI 495.02 500.00 295.71 10.45 285.26 Pass: Major Risk V-104 Plan V-104 V5 Plan: PI 594.93 600.00 88.26 10.52 77.75 Pass: Major Risk V-105 Plan V-105 V10 Plan: P 496.28 500.00 220.97 9.80 211.17 Pass: Major Risk V-106 V-106 V10 495.16 500.00 269.10 7.61 261.49 Pass: Major Risk V-201 V-201 V8 591.39 600.00 133.84 9.52 124.34 Pass: Major Risk EX WKUPST-01 PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad ) ) V-108 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates may be encountered near the base of the Permafrost at 1869' MD and near the TO hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: . A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 10.0 pore pressure. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . V-108 will cross a fault twice - at ....3682' TVD (+/-250') and again at -6257' TVD (+/- 150'). The estimated throw of the fault is approximately 90'. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies TREE == 4-1/16" CrN WELLHEAD = FMC ~AcTüÄ^T6'R';"N_"^^"^^N"^ÑÃ . ,>,y",.'.wu.'W~W.'.'.'.'''''''''.'.'.>.' ,., ,. ,v/,w,.',w.w,','.'.y".".Whv.v,",""'.'.".'.'.'.'.'.WN,W KB. ELEV = 82.3' 'sF:'ELBT;'w,', '. wW''''''WWNNÃ . ............'...w.'..>.-.'.".w.'.'.'.w."......w.'.'.w ,. W ... .. d, v.w........ KOP = 300' ,~~"~~~9!~,~~::=~~~~@::~~~~í, Datum MD = ','" """"''''',",',W.W.,,".W.",','-.,',','-",w' ..... "..,., .. .".. Datum ìV D = 8800' SS ) 9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 3261' Minimum ID = 2.813" @ xxxx' 3-1/2" HES X NIPPLE 1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" l-i 8995' ÆRFORA TION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 PBTD 1-1 9456' 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 9536' DATE REV BY 07/25/02 =--1 1011' 1-1 9-5/8" TAM PORT COLLAR I I 2200' 1-1 3-1/2" HES X NIP, ID = 2.813" I V -1 08 I - - I I ~ ~ L I I /1 ~I z 0t ~ COMMENTS PROPOSED COMPLETION DA TE REV BY jdf COMMENTS ) ST MD 1 2 3 GAS LIFT MANDRELS ND DEV ìYÆ VLV LATCH PORT DATE tbd KBG-2 DCK-3 BTM 3.5x 1 5300 KBG-2 DV BTM 3.5x1 3500 KBG-2 DV BTM 3.5x 1 8774' 1-13-1/2" BKR CMD SLIDING SLY, ID = 2.813" 1 8875' 1-1 7" X 3-1/2" BKR PRBv1IER PKR, ID = I I 2.992" am ~ 3-1f2II-ESX~ 0=2813' I æi8 Il 3-1f2'I-ESX~ 0=2813' I am 1-1 3-1f2'~ 0=2875'1 GPB BOREALIS WELL: V-108 ÆRMrr No: API No: SEC 11, T11 N, R11 E 4805' NSL & 1906' WEL BP Exploration (Alas ka) H 207010 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 7/12/02 INV# CK071002H PERMIT TO DRILL FEE R' E- r if'",' ¡¡ ""I r, '( ,'~ ~ ~ \\9 r~ ",;,¡c. ~ '\V1' q,,.,ç-, ~ '\~ ~~'-:' A I I '"\ n ('. On fí2 f!¡Ub J Ó l.UV ' Alaska Oil & Gas Cons, t;ownWjSIU' AnchoraQ8 {lOB THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANKOFA$HLAND ANAFFIUATEOF NATIONAL CITY BANK .cLEVELAND, OHIO 56-389 412 PAY Ð ør,;'-'; "Ùñ: J'1II,,~Il. ''''J';i)¡ .f" o.r. 'a.~.'...~l~",J :!::::1 ::::. ~~r~: TO THE ORDER OF ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7THA¥E STE 100 ANCHqßAGE,i 1\1<- 99501 ,,1 2 0 ? 0 It 0 III I: 0... It 2 0 :I 8 q 5 I: 0 0 8 ...... . q /II DATE CHE9K N9. H207010 7/12/02 VENDOR DISCOUNT NET No.H 201010 CONSOLIDATED COMMERCIAL ACCOUNT r:.. !~ggY.J.!8P..~g:Ç;~ ;t~9~ð¥€)...:'\..!þ....w..::t~.:-::{~ ,.:, :.,[:.ó:'.:.: ':''''';:;':7.'''''':J~/'' :X..':";'/';':': ':'¿"~;:'" :"',,,'~.::~~~.:::r.......r.....~:......::.....\:;..... i~~:~r~~~~~¥.}t~f~¡;:~!f~ilt H .~ '.......",.. 1\ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ßU ¿J-/ð~ PTD# .Lt>¿ - / .h Á CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 'WELL PERMIT CHECKLIST COMPANY ðfJ Y WELL NAME I'IILA. 1./"/6f?' PROGRAM: Exp - Dev.x Redrll- Re-Enter - Serv - Wellboreseg- FIELD & POOL ¡:;C¡O/~ð INITCLASS fÅ:,~I/ 1-0// GEOLAREA ?7~ UNIT# /I~<ò ON/OFFSHORE~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . RN 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ','////' t7 /~h'? 8. If deviated, iswellbore plat included.. . . . . . . . . . . . . . Y N t::}!.E=- J! IJ "''- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ;tVy N /J (Service Well Only) 13. Well located w/in area & strata authorized by injection order #- Y~. ,/' //./, /7, (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. N , ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N ?,.:; i' <p 1(0 . 16. Surface casing protects all known USDWs. " . . . . . . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y... 19. CMT will cover all known productive horizons. . . . . . . . . . N 20. Casing designs adequate for C: T, B & permafrost. . . . . . . . N. I, IDe c 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N Netþfl> -( c..:- ~ . 22. If a re-drill, has a 10-403 for abandonment been approved. . . /\1/A:- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . éiì. N 24. If diverter required, does it meet regulations. . . . . . . . . . 0N 10 ¡ '"3 25. Drilling fluid program schematic & equip list adequate. . . . . & N m ~ m kI Sf.,-5 rpc¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~ N 2...7... BOPE press rating appropriate; test to t.l500 psig. N f/4t;¡) '2. -tCS I yJ ~ . C A - 1>J I 2,8. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N W ~ \\ il.,OL 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 31. Mechanical condition of wells within AOR verified. . . . . . . . Y N /1// k 32. Permit can be issued w/o hydrogen sulfide measures. . . . . @N 33. Data presented on potential overpressure zones. . . . . . . . XN ,/] 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /f~ r-t \ 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact name/phone for weekly progress reports. . . . . . . . Y N ~APPR DATE ,APPR DATE (Service Well Only) . GEOLOGY APPR DATE rffr rrd;Þ /. (Exploratory Only) /' GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/lnstructions: RP~ TEM JDH.JII- JBR COT DTS 7/;x)f~ WGA ~A- MJW SFD- Rev: 07/12/02 G:\geology\perm its\checklist.doc