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Home My WebLink About202-033Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-102 202033 500292307000 8 1/1/2024 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d 0 d... - 033 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed II 11I1111 RESCAN DIGITAL DATA ~iskettes. No.1 0 Other, NofType: OVERSIZED (Scannable) 0 Maps: 0 Color Items: 0 Greyscale Items: 0 Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: BY: ~ leJ vVt° J~ II j~ Dale: ft, II Dl( Isl m? "1 ~ X 30 = 30 + d.-4- = TOTAL PAGES Slf ~ j Date: <6 If, {} Lf- Isl VVJ. P 6: Production Scanning 111I1I11I1111111111 Stage 1 Page Count from Scanned File:..s:S ~,~ cu:lW Page Count Matches Number in Scanning Preparation: .~ YES NO Helen ~ --- Date:C() ð3 ' 0 Lf Isl YVlP I YES NO 0 Logs of various kinds: NOTES: BY: Helen ~ 0 Other:: Date~, I ~ Dt I Project Proofing Helen ~ Scanning Preparation BY: Helen ~ \ I BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: 151 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111111 BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 , /n/"Jnn' ,^, II I 'i tnr" r-il r", r n n rt"... STATE OF ALASKA ALASKAAND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ig Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 151 Exploratory ❑ - 202 -033 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 23070 -00 -00 8. Property Designation (Lease Number) : , 9. Well Name and Number: ADLO- 028240 PBU V -102 10. Field /Pool(s): . PRUDHOE BAY FIELD / BOREALIS OIL POOL 11. Present Well Condition Summary: Total Depth measured 8960 feet Plugs (measured) None feet true vertical 7043 feet Junk (measured) None feet Effective Depth measured 8847 feet Packer (measured) feet true vertical 6931 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20 ", 91.5 #, H -40 Surface - 109 Surface - 109 1490 470 Surface 3240' 7 -5/8 ", 29.7 #, L -80 29 - 3269 29 - 2722 6890 4790 Intermediate 8194' 5 -1/2 ", 15.5 #, L -80 26 - 8220 26 - 6311 7000 4990 Production 727' 3 -1/2 ", 9.2 #, L -80 8220 - 8947 6311 - 7030 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ - _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2 ". 9.2# L -80 23 - 8238 23 - 6329 Packers and SSSV (type, measured and true vertical depth) t ; 12. Stimulation or cement squeeze summary:�,a�1t1'�`�jd� Intervals treated (measured): .. qt y, Treatment descriptions including volumes used and final pressure: pk � '„ s- 4 r ` - '' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 781 924 1930 340 Subsequent to operation: 671 793 1657 430 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 • Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager Signature ,,,f +d6��'��® Phone (907) 564 -5674 Date 7/13/2011 FINNS JUL 13 ZO11, � J' ii, Form 10-404 Revised 10/2010 r �e, Submit Original Only V -102 202 -033 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -102 6/23/02 PER 8,450. 8,490. 6,538.14 6,577.68 V -102 6/23/11 APF 8,520. _ 8,540. 6,607.35 6,627.12 V -102 6/23/11 APF 8,580. 8,600. 6,666.67 6,686.44 V -102 6/24/11 APF 8,490. 8,520. 6,577.68 6,607.35 V -102 6/25/11 APF 8,470. 8,490. 6,557.91 6,577.68 AB ABANDONED PER PERF • APF BPP ADD PERF RPF REPERF BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • V -102 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ty T U 6/23/2011 ***WELL FLOWING UPON ARRIVAL * ** (ELINE RE- PERF /ADPERF) ;WELL SHUT IN AND FLAGGED. RUN 1: PERFORATE 8580 -8600 WITH 2.5" PJ GUNS: ENT HOLE = 0.31 ", PENETRATION= 24.4 ", MAX GUN SWELL= 2.66" IN FLUID. 3 RUN 2: PERFORATE 8520 -8540 W ITH 2.5" PJ GUNS: ENT HOLE = 0.31 ", PENETRATION= 24.4 ", MAX GUN SWELL= 2.66" IN FLUID. WELL LEFT SI. FINAL VALVE POSITIONS: SWAB, SSV, GTL, WING = CLOSED, MASTER =OPEN, IA/OA =OTG. FINAL T /I /0= 950/1380/520 * * *IN PROGRESS, CONTINUE ON 24- JUNE - 2011 * ** 6/24/2011 ** *CONTINUED FROM 23- JUN -2011 * ** (add perf) T /I /0= 1275/1425/500 ;RUN 3: PERFORATE 8490 - 8520 FT WITH 2.5" PJ GUNS: ENT HOLE = 0.31 ", PENETRATION= 24.4 ", MAX GUN SWELL= 2.66" IN FLUID (PULLING 200# TO 1300# OVER FROM 8000' TO 7650') `RUN IN W/ 4TH GUN RUN BUT SET DOWN @ 7650', UNABLE TO WORK THRU & PULLING 300# OVER EACH ATTEMPT LAY DOWN EQUIPMENT FOR NIGHT WHILE PAD OP FLOWS WELL AND RE- ATTEMPT 4TH GUN RUN IN THE MORNING 'TWO = 1500/1500/500 ** *WELL FLOWING ON DEPARTURE - CONTINUE JOB ON 24- JUN - 2011 * ** 6/24/2011 TWO= 380,1520,670. Temp= 110 °. WHPs (Pre -EL perf). ;SV= C. WV, SSV, MV =O. IA, OA= OTG. NOVP. ! j � � E 6/25/2011; ** *JOB IN PROGRESS FROM 24- JUNE - 2011 * ** (ELINE ADPERF /RE -PERF) !WELL FLOWING UPON ARRIVAL. T /I /0= 400/1500/700. SHUT IN WELL. MADE DUMMY RUN TO 8718'. TWO 1100/1400/575 RUN 4 PERFORATE: 8470 -8490 W/ 2.5" PJ HMX, 6 SPF, 60 DEG PHASING. BEFORE PERF T /I /0= 1350/1450/480 AFTER PERF T /I /0= 1350/1450/480 1 FINAL VALVE POSITIONS: SWAB,SSV,WING,GLT,CHEM INJ= CLOSED, 3 MASTER =OPEN, IA/OA =OTG. FINAL T /I /0= 1350/1420/480 ** *JOB COMPLETE * ** 3 • • FLUIDS PUMPED BBLS 3 DIESEL 3 TOTAL ,TREE 3-1/8" 5M CIW WELLHEAD = 11" FMC SA41, NOTES: ACTUATOR = NA V -102 KB. ELEV -= 82.10' BF. ELEV = 53.60' Ma xAngle = 50° @ 3909' _- 1 986' H 7 -5/8" TAM COLLAR, ID = 6.875" I _Datum MD = 8596' I 2520' H 3 -1/2" HES X NIP, ID = 2.813" I Datum "ND = 6600' SS 120" CONDUCTOR I ? 17 -5/8" CSG, 29.7 #, L -80 BTC, ID = 6.875" I--I 3269' • GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4460 3503 49 KBG2 -9 DOME INTG 16 05/13/11 Ill 2 7072 5292 39 KBG2 -9 DOME INTG 16 05/13/11 Minimum ID = 2.813" @ 2520' 1 8138 6231 12 KBG2 -9 SO INTG 22 05/13/11 3 -1/2" HES X NIPPLE ' I 8195' H 3 -1/2" BKR CMD SLIDING SLV, ID = 2.813" 13 -1/2" TBG, 9.2 #, L -80, IBT -M, .0087 bpf, ID = 2.992" H. 8219' 8219' H BKR LOC SEAL ASSY, ID = 2.990" I 15 -1/2" CSG, 15.5 #, L -80, BTC, .0238 bpf, ID = 4.950" H 8220' 1 8221' I OF BKR PBR, ID = 4.00" I 14-3/4" X 3 -1/2" CSG XO, ID = 3.000" H 8240' 1 8240' I_I BTM OF 3 -1/2" BKR SEAL ASSY, ID = 2.990" I 8260' H 3 -1/2" HES X NIP, ID = 2.813" I 1 8280' H 3-1/2" HES X NIP, ID = 2.813" I PERFORATION SUMMARY REF LOG: I 8386' H 15' PUP JT W / RA TAG 1 ANGLE AT TOP PERF: 9° @ 8450' , Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE , 2 -1/2" 6 8450 - 8490 0 06/23/02 ' 2 -1/2" 6 8470 - 8490 0 06/25/11 ' 2 -1/2" 6 8490 - 8520 0 06/24/11 2 -1/2" 6 8520 - 8540 0 06/23/11 ) ' 2 -1/2" 6 8580 - 8600 0 06/23/11 1 8652' F-116' PUP JT W / RA TAG J 1 8750' H TOP OF SAND (07/01/02) 1 PBTD I 8847' �4• miemen 13-1/2" CSG, 9.2 #, L -80 IBT, .0087 bpf, ID = 2.992" I—I 8947' ►��•QQ• 4 DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 05/28/02 N9ES ORIGINAL COMPLETION 06/27/11 TTW/ PJC ADPERFS (06/23- 25/11) WELL: V -102 07/01/02 PWE/KK FCO / TOP OF SAND PERMIT No: 2020330 04/10/03 DRS/TP TVD /MD CORRECTIONS AR No: 50- 029 - 23070 -00 04/27/04 KS /KAK GLV C/O SEC 11, T11N, R11E, 4841' NSL & 1760' WEL 06/12/05 RMH/PJC GLV C/O 06/01/11 JLJ/ PJC GLV C/0 (5/13/11) BP Exploration (Alaska) ~ BP Exploration (Alaska) Inc. "~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 `~~ ,~'!~t`,ua~~u~~~J tii~~' ~~' _ ~i ~~U~ . t.;~ August 14, 2009 ~ ~~ ~~~ `~~~ ~ 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, Aladce Oil ~ Gas Cons. Camm~~~inn A~chorap~ ~t~~,-0~3 ~.~ ~ a ~-- 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 inhibitor/ sealant date ft bbls ft na ai 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 SUrfBCe 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 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 v-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 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 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 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 5002923178ot00 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 125 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA t8.7 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 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-201 2012220 5002923054000o SC leak NA 4 NA 9o.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 18.28 1/9/2009 V-210 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 12 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-2t7 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-2t8 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 ~ 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 '" . ;00. .,.:.:~..............:,'." "',~' '., ;-, '"" " 'Ì.- " ,. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ). ~ J ült\ ~k ,{ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 J(llÅ¿ (vI rvl~ ~'-{) ~ API No. 50-029-23070-00-00 Permit to Drill 2020330 Well Name/No. PRUDHOE BAY UN BORE V-102 Operator BP EXPLORATION (ALASKA) INC MD 8960 /" - - - --- -- -- ------- ------- -- -- ----~--- TVD 7043--- Completion Date 6/23/2002 ~ Completion Status 1-01L UIC N Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No Directional surve~ DATA INFORMATION ----------------- ------- - -- --. - - - - Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset ~ed/Fnnt- Number ~ i<LoQ (M r-Rp1-- J5& I ~ ~/ ~ C !fJ/ C ~Log ~V i~- J{Og i~' ~ .------------- Name Cement Evaluation Directional Survey Log Log Run Interval OH/ -- Scale Media No Start Stop CH Received Comments 2 Blu 1 70 1734 Open 6/27/2002 Platform Express 0 8960 Open 6/12/2002 25 Blu 1&2 70 1734 Open 6/27/2002 Platform Express Merged runs 25 Blu 1&2 70 1734 Open 6/27/2002 Platform Express Merged runs 0 8960 Open 6/12/2002 Geodetic 102 8959 Open 8/9/2002 25 Blu 1 & 2 70 1734 Open 6/27/2002 Platform Express Merged runs 25 Blu (if!) 102 8959 Open 8/9/2002 25 Blu 1 & 2 70 1734 Open 6/27/2002 Platform Express Merged runs 80 8969 Open 6/27/2002 PEX AIT BHC Digital Data ----- 2 Blu 3265 8913 Open 6/27/2002 HeAL Caliper 0 8960 Open 6/12/2002 2901 84~2 ~dI09, Ne I o' 25 Blu 1 & 2 70 1734 Open 6/27/2002 Platform Express Merged runs SubSea 25 Blu t^b 102 8959 Open 8/9/2002 ~ 2 5436 8761 Open 6/27/2002 Modular Formation Dynamics Tester Porosity Neutron Directional Survey ~73 GammaRay Density Gamma Ray ~~tion/Resistivity l)1Ô61 See Notes Cement Evaluation Directional Survey 112~ ~ \! v-~ð \..)-\ ~_J" Sonic Gamma..Ray Formation Tester Permit to Drill 2020330 MD 8960 Well Cores/Samples Information: TVD 7043 Name Well Cored? ADDITIONAL INFORMATION y@J Chips Received? Analysis Received? . - - ------------ Comments: -- --- - ---- -- - ------ ----- Y/N ~t~-- - ------ --- ------ Compliance Reviewed By: - DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Well Name/No. PRUDHOE BAY UN BORE V-102 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23070-00-00 Completion Date 6/23/2002 Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops }~ Current Status 1-01L UIC N Sample Set Number Comments (J>/N Q)N ~ Date: J r4- v-\ 2- ~ '-( --_/ SChlumbel'gep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well <1n/-aOJ 5 L-109 L-109 L-109 L-109 L-109 L-109 . L-109 V L-108 a()d. t 0'1 V-102 ~n~ - 03~ V-102 \ V-102 ..j, Job# Log Description Date 06/06/02 06/06/02 06/06/02 06/06/02 06/06/02 06/06/02 06/06/02 08/03/02 OS/21/02 OS/21/02 OS/21/02 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: 22303 PEX-AIT-BHC-POROSITY 22303 PEX-AIT 22303 PEX-BHC 22303 PEX-POROSITY 22303 PEX- TRIPLE COMBO 22303 PEX-TRIPLE COMBO SSTVD 22303 PEX-HOLE & CEMENT VOLUME LEAK DETECTION LOG 22258 OH MWD/GR 22258 MD IMPULSE-GR 22258 TVD IMPULSE-GR RECEIVED t.JJG 0 9 2002 AlaSka Oil & Gas Cons. ComûSion An~ 08/07/02 NO. 2300 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia BL CD 1 1 1 1 1 1 1 1 1 1 1 -~~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Received~ (.~ SC___..gBP Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Log Description Job# V-102 õ'1D~,-o3ß V-102 - V-102 V-102 V-102 V-102 V-102 V-102 22256 PEX AIT SHC 22256 PEX AIT 22256 PEX DEN/NEUTRON POROSITY 22256 PEX & SONIC SSTVD 22256 SHC 22256 MDT 22256 PEX CEMENT VOLUME 22256 CEMENT VOLUME HCAL-CALlPER v ~ 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 RECEIVED JUN 2 7 2002 Date Delivered: AJaska Or¡ & Gas ConS. Commission Anch018gO 6/25/2002 NO. 2190 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia BL CD OS/23/02 OS/23/02 1 . OS/23/02 1 OS/23/02 1 OS/23/02 1 OS/23/02 1 05/16/02 1 OS/23/02 1 Schlumberger DeS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie ReCeiVe~(J}O°0-- ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 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 r.' - I ". ".'. " 4841' NSL, 1760' WEL, SEC. 11, T11 N, R11 E, UM, COMPLETION I ~JXf.Å-\. At top of productive interval I / DAJE ,~ '~a' :.,~î 4159' NSL, 3179' WEL, SEC. 02, T11N, R11E, UM \ ~,L 'i??- t r\.!' " " "",'.''''",1.1,,,1,: 10. Well Number At total depth I VE~ED t 'J~ I" '", ~: 4221 "NS.L, 3216: ~EL, SEC. 02, T11N, R11E, UM :,:,~(:.{).. ;:~', r \J1!., ~'ifi~f 5. Elevation In feet (Indicate KB, DF, etc.) 6. Lease Designation and SeriãrNlo:' KBE = 82.1' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/14/2002 5/21/2002 6/23/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8960 7043 FT 8847 6931 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES / AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, Dipole Sonic, Gas Detection, 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 109' 42" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 29' 3269' 9-7/8" 392 sx Articset Lite III, 206 sx 'G' 5-1/2" 15.5# L-80 26' 8220' 6-3/4" 147 sx LiteCrete, 192 sx Class 'G' 3-1/2" 9.2# L-80 8220' 8947' 6-3/4" J5-1/2" x 3-1/2" CementinQ ProQram) Classification of Service Well 7. Permit Number 202-033 8. API Number 50- 029-23070-00 9. Unit or Lease Name Prudhoe Bay Unit V-102 11. Field and Pool Prudhoe Bay Field I 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) 2520' MD 1900' (Approx.) 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6spf MD TVD 8450' - 8490' 6538' - 6578' 25. SIZE 3-1/2", 9.2#, L-80 MD TVD RES, CMR, MDT AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 8238' PACKER SET (MD) None 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8450' - 8490' Frac'd, Placed 162,000#'5 of 16/20 and 5,900#'5 12/18 Carbolite Behind Pipe PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 3119 OIL-BsL 27. Date First Production July 18, 2002 Date of Test Hours Tested 7/21/2002 4 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE GAs-McF 2263 GAs-McF WATER-BBL 12 WATER-BsL Freeze Protected with 150 BBls Diesel & 20 Bbls MeOH CHOKE SIZE 176 OIL GRAVITY-API (CORR) GAS-OIL RATIO 726 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbmitRrpe1: 1 \' E D No core samples were taken. 28. .U!! ,) l~, {'IOD? J ~- I-l} L l... Alaska DH & Gas Cons. con¡¡wSSIOiì Anchorage G ~ (l f~: i (.=,',~ ~ f\! It'l L W f:J 0 M 5 B F l JUL 3 Q 2ÜlJ4;ubmit In Duplicate ..# b It ¡ !~,l~ ~ , '0'~~\ Form 10-407 Rev. 07-01-80 ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Schrader Bluff M 5160' 39751 Schrader Bluff N 5495' 4202' Schrader Bluff 0 57281 4359' Base Schrader I Top Colville 6262' 4719' CM1 7557' 5689' HRZ 8154' 6247' Kalubik 8354' 6443' Kuparuk D 8443' 65311 Kuparuk C 8447' 6535' LCU I Kuparuk B 86011 6687' Kuparuk A 8722' 6807' Miluveach 68021 6884' 31. List of Attachments: ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. MDT was ran, log supplied for detail. r~ r'" !h( ill'" J , ~"'" t~,.. ~ \l [: D','~ :.. ~ \1 [, ~JUL 26 2002,' Alaska OH & Gas Gons. Commission Anchorage Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I ~erebY certify that the fO~Oi~g is t~~ ad&rect to the best of my knowledge Signed Terrie Hubble ~R A/lc..i , ~ Title Technical Assistant V-102 202-033 Well Number Permit No. / Approval No. INSTRUCTIONS Date 07. x.ó~ Prepared By Name/Number: Terrie Hubble, 564-4628 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In. Other-explain. Form 10-407 Rev. 07-01-80 l""\ r'¡ 1 ! \'- \. . I \ ,/ I \ ¡ n ~ ,,\, 1 ! "-, L- Legal Name: V-102 Common Name: V-102 Test Date 5/18/2002 Test Type LOT Test Depth (TMD) 3,269.0 (ft) BP EXPLORATION Leak-Off TestSul11mary TestDepth (TVD) 2,722.0 (ft) AMW 9.30 (ppg) SurfacePressurè Lèak OffPl'essUre>(BHP) 1,965 (psi) EMW 13.90 (ppg) 650 (psi) .~ c-- Printed: 6/3/2002 1 :01:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0) ) BP EXPLORATION Operations Summary Report Page 1 of 8 V -1 02 V-102 DRILL +COMPLETE NABORS NABORS 9ES Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 9-ES Spud Date: 5/14/2002 End: 5/28/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/13/2002 12:00 - 16:00 4.00 MOB P PRE BLOW DOWN PIT COMPLEX. DISCONNECT SERVICE LINES: MUD, WATER, STEAM, AIR & FLOWLINE. SET MATS, CONTINUE TO CLEAN DERRICK. 16:00 - 00:00 8.00 MOB P PRE PJSM MOVE CAMP AND PITS OFF V-106. MOVE MATS & PREP LOCATION WITH D8 CAT. RE-POSITION MATS FOR SUB MOVE. INSTALL DIVERTER. MOVE SUB. 5/14/2002 00:00 - 02:00 2.00 MOB P PRE MIRU. SPOT AND LEVEL RIG OVER HOLE. 02:00 - 04:00 2.00 MOB P PRE SPOT PITS, CAMP COMPLEX, AND LEVEL. 04:00 - 05:30 1.50 RIGU P PRE N 1 U DIVERTER SYSTEM. SPOT CUTTINGS TANK. 05:30 - 09:00 3.50 RIGU P PRE TAKE ON FRESH WATER. MIX SPUD MUD. R 1 U FLOOR. CONTINUE R 1 U. 09:00 - 09:30 0.50 RIGU P PRE FUNCTION TEST DIVERTER. OK. WITNESS OF TEST WAIVED BY AOGCC, JOHN CRISP. 09:30 - 10:00 0.50 RIGU P PRE SERVICE TOP DRIVE AND CROWN. 10:00 - 11 :00 1.00 RIGU P PRE PREPARE BHA IN PIPE SHED. CONTINUE TO MIX SPUD MUD. 11 :00 - 11 :30 0.50 RIGU P PRE PRE-SPUD MEETING WITH ALL CREW MEMBERS. 11:30-13:00 1.50 DRILL P SURF PI U BHA #1. BIT, MOTOR, STAB, LEAD DC, MWD, & ORIENT. 13:00 - 15:00 2.00 DRILL P SURF FILL CONDUCTIOR WITH WATER. CHECK FOR LEAKS. DRILL FI 108' - 298', 15:00 - 16:30 1.50 DRILL P SURF CHANGE OUT 2 STDS HWDP FOR JARS. RU SWS ELINE UNIT FOR GYRO SURVEY. 16:30 - 00:00 7.50 DRILL P SURF DRILL AND RUN GYRO'S FI 298' - 910'. KOP: 295'. WOB = 30 - 35 K, 652 GPM @ 2000 PSI. UP WT = 70, DWN WT = 70, RT WT = 70, TO = 2 K FT LBS @ 80 RPM. AST = 2.13 HRS, ART = 2.08 HRS, GYRO TIME = 1.75 HRS. 5/15/2002 00:00 - 07:00 7.00 DRILL P SURF DIRECTIONALL Y DRILL FI 910' - 1,747'. 83K UP, 70K DN, 75K RT WT, 220 SPM, 652 GPM, 2,160 PSI, 80 RPM, 5K TO. 07:00 - 07:30 0.50 DRILL P SURF CIRCULATE SWEEP AROUND TO CLEAN HOLE @ 220 SPM, 1,875 PSI. 07:30 - 09:30 2.00 DRILL P SURF FLOW CHECK. POOH FOR WIPER TRIP. 94K UP, 70K DN. HOLE SLICK. CHG OUT BIT & DROP UBHO SUB. 09:30 - 10:30 1.00 DRILL P SURF TIH TO 1,654'. HOLE SLICK. 10:30 - 17:00 6.50 DRILL P SURF M 1 U TOP DRIVE. WASH TO BTM. DIRECTIONAL Y DRILL FI 1,747' - 3,285'. TD SURFACE HOLE. UP WT = 110K, DN WT = 75K, RT WT = 88K. 220 SPM, 652 GPM, 2,570 PSI. AST = 7.4 HRS, ART = 5.9 HRS. 17:00 - 18:00 1.00 DRILL P SURF CIRCULATE BOTTOMS UP & HOLE CLEAN. 18:00 - 20:00 2.00 DRILL P SURF POOH TI 3,052'. HOLE SWABBING. PULL 30 KOVER. BACKREAM TO 1,700' (LAST WIPER TRIP). POOH TO 1,500' NO DRAG. 20:00 - 21 :30 1.50 DRILL P SURF TIH TI 3,057'. TAG UP. WASH AND REAM TO BOTTOM @ 3,285'. 21 :30 - 22:00 0.50 DRILL P SURF CIRCULATE BOTTOMS UP & HOLE CLEAN (RECIPROCATE & ROTATE). UP WT = 110K, DN WT = 75K, RT WT = 88K. 22:00 - 00:00 2.00 DRILL P SURF POOH FOR E-LOG RUN. SB DP & HWDP. HOLE SLICK. 5/16/2002 00:00 - 02:30 2.50 DRILL P SURF LD BHA. CLEAR FLOOR. 02:30 - 02:45 0.25 EVAL P SURF PJSM FOR E LINE LOGGING. 02:45 - 06:00 3.25 EVAL P SURF RUN PEXlBHCS TO 1734'. NO FURTHER PROGRESS. MAKE SEVERAL ATTEMPTS TO GET DEEPER. PICK UP I CLEAN - ACTS LIKE A LEDGE. ABORT & LOG BACK OUT I TO SURFACE & RD SWS. I Printed: 6/3/2002 1 :02:02 PM ') ) BPEXPLORATION Operations Summary Report Page Qof 8 Legal Well Name: V -1 02 Common Well Name: V -1 02 Spud Date: 5/14/2002 Event Name: DRILL +COMPLETE Start: 5/15/2002 End: 5/28/2002 Contractor Name: NABORS Rig Release: 5/28/2002 Rig Name: NABORS 9ES Rig Number: 9-ES - To Hours Task Code NPT Phase Description of Operations 5/16/2002 06:00 - 08:00 2.00 CASE P SURF MAKE DUMMY RUN WITH CASING HANGER. R / U TO RUN CASING. C/O TO LONG BAILS. PJSM FOR CASING RUN. 08:00 - 12:00 4.00 CASE P SURF M / U SHOE TRACK (BAKER-LOK) & RUN 78 JTS 7 5/8", L-80, 29.7 #, BTC CASING. 12:00 - 12:30 0.50 CASE P SURF M / U LANDING JT. LANG CASING IN HEAD. FLOAT SHOE @ 3269'. BREAK OUT FILL-UP TOOL. M / U CMT HEAD. 12:30 - 15:30 3.00 CASE P SURF RECIRPOCATE & CIRCULATE CASING. 8 BPM, 550 PSI. UP WT = 120 K, ON WT = 80 K. 15:30 - 18:30 3.00 CEMT P SURF PJSM. PUMP 5 BBLS CW -100, TEST LINES TO 3500 PSI, PUMP 5 BBLS CW - 100. PUMP 75 BBLS. 10.2 PPG MUDPUSH XL@ 6 BPM, 500 PSI. DROP BOTTOM PLUG & PUMP 310 BBLS 10.7 PPG ARTICSET LITE III LEAD SLURRY@ 8BPM, 1000 PSI. STOP RECIPROCATING PIPE @ 220 BBLS AWAY. FOLLOWED BY 43 BBLS. 15.8 PPG CLASS "G" TAIL SLURRY, 4.5 BPM, 775 PSI. DROP TOP PLUG AND CHASE W/ 10 BBLS WATER. SWITCH TO RIG PUMPS AND FINISH DISPLACEMENT W/ 137 BBLS, 9.7 PPG MUD. BUMP PLUG @ 2 BPM, 200 PSI TO 1500 PSI. BLEED PRESSURE. FLOATS GOOD. 78 BBLS LEAD CEMENT TO SURFACE. 18:30 - 19:30 1.00 CEMT P SURF BREAK OUT CMT HEAD. BACK OUT AND L / 0 LANDING JOINT. CLEAR RIG FLOOR. 19:30 - 00:00 4.50 BOPSUR P PROD1 NO DIVERTER STACK. N / U CASING SPOOL AND TUBING SPOOL. N / U BOP STACK. DBL VALVE CASING HEAD. 5/17/2002 00:00 - 02:00 2.00 BOPSUR P PROD1 CONTINUE N / U BOP STACK. CHANGE OUT BAILS. 02:00 - 03:00 1.00 BOPSUR P PROD1 JACK UP RIG. SHIM & RE-LEVEL. 03:00 - 07:00 4.00 BOPSUR P PROD1 R / U TEST EQUIPMENT. TEST BOP STACK, STAND PIPE MANIFOLD, CHOKE MANIFOLD, AND ALL RELATED VALVES AND LINES TO 250 PSI LOW / 5 MIN, 4500 PSI HIGH / 5 MIN. TEST ANNULAR PREVENTER TO 250 PSI LOW / 5 MIN, 3500 PSI HIGH /5 MIN. WITNESS OF TEST WAIVED BY JOHN CRISP AOGCC. 07:00 - 08:00 1.00 BOPSUR N SFAL PROD1 ATTEMPT TO PULL TEST PLUG AND TEST JOINT WITH TUGGER LINE. TEST PLUG STUCK IN WELL HEAD. N / U TOP DRIVE. WORK PIPE TO 15 KAND CIRCULATE. PULLED FREE. SET WEAR BUSHING. R / 0 TEST EQUIPMENT AND BLOW DOWN LINES. TEST PLUG HAD SOME SCARriNG ON 00. 08:00 - 14:00 6.00 DRILL P PROD1 MOVE HWDP FROM OFF DRLS SIDE TO DRLS SIDE OF DERRICK. P / U DP SINGLES FROM PIPE SHED AND TIH. RACK DP IN DERRICK. TOTAL 123 JTS PICKED UP & RACKED BACK. 14:00 - 15:00 1.00 DRILL P PROD1 TEST 7 5/8" CASING TO 3500 PSI FOR 30 MIN. OK. 15:00 - 18:00 3.00 DRILL N SFAL PROD1 PULL BOP STACK TO INSPECT WELL HEAD SPOOLS (DUE TO SCARRING ON TEST PLUG EARLIER). CASING HEAD BOWL SCARRED. CHANGE OUT CASING AND TUBING SPOOLS. TEST WELL HEAD TO 1000 PSI. OK. N / U BOP STACK. 18:00 - 18:30 0.50 DRILL N SFAL PROD1 R / U TEST EQUIPMENT. TEST CASING HEAD AND TUBING HEAD FLANGES TO 250 PSI LOW / 5 MIN. PRESSURE UP TO 4500 PSI FOR HIGH TEST. TEST JT PARTED. SHUT DOWN FOR INCIDENT INVESTIGATION. 18:30 - 19:30 1.00 DRILL N RREP PROD1 INCIDENT INVESTIGATION. Printed: 6/3/2002 1 :02:02 PM Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: 5/17/2002 5/18/2002 5/19/2002 ) ) BP EXPLORATION Operations Summary Report V-102 V-102 DRILL +COMPLETE NABORS NABORS 9ES From ;.To Hours Task Code NPT Phase 19:30 - 21 :30 21 :30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 04:00 04:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 -10:30 10:30 - 12:00 12:00 - 12:30 12:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 19:00 2.00 DRILL N 2.00 DRILL N 0.50 DRILL N 1.00 DRILL N 2.50 DRILL P 0.50 DRILL P 2.50 DRILL P 1.00 DRILL P 1.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 8.50 DRILL P 1.00 DRILL P 2.00 DRILL P 0.50 DRILL P 1.50 DRILL N 0.50 DRILL P 1.00 DRILL P 15.50 DRILL P I I RREP PROD1 RREP PROD1 RREP PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 PROD1 I Page 3 of8 Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 9-ES Spud Date: 5/14/2002 End: 5/28/2002 Description of Operations PULL BOP STACK TO RETRIEVE TEST PLUG. OPEN TOP RAM BONNET TO INSPECT VARIABLE PIPE RAMS. RAMS DAMAGED. REPLACE RAMS. CLOSE BONNET. RU TEST EQUIPMENT TO TEST BONNET SEALS, VARIABLE RAMS, CASING & TUBING HEAD FLANGES. RU TEST EQUIPMENT. BODY TEST STACK AND UPPER PIPE RAMS, WELLHEAD CONNECTION TO 250 PSI LOW / 5 MIN, 4500 PSI HIGH / 5 MIN. OK. RD TEST EQUIPMENT. BLOW DOWN LINES. INSTALL WEAR BUSHING AND RILDS. M / U BHA #3. TIH. CHANGE OUT STABILIZER BLADE ON MTR. ORIENT MWD / LWD. P / U TIH De's, JARS, & HWDP. SHALLOW TEST MWD / LWD TOOLS @ 250 GPM, 950 PSI. TIH PU 4" DP FROM PIPE SHED. TEST CSG TO 1,000 PSI AFTER TRIP PAST TAM COLLAR TO VERIFY COLLAR CLOSED. PERFORM D-1 (KICK WHILE TRIPPING) AND D-6 (STRIPPING DRILL) DRILLS. BLOW DOWN LINES. CUT AND SLIP 65' OF DRILL LINE. FUNCTION AND CHECK C.O. M. SERVICE TOP DRIVE, BLOCKS, & CROWN. CONTINUE TIH. WASH DOWN LAST STAND ABOVE FLT CLR @ 3184'. TAG CMT @ 3170'. DRILL SHOE TRACK, WASH/REAM RAT HOLE TO 3285'. 300 GPM, 1770 PSI, 50 RPM. DRILL 20 NEW FORMATION TO 3305'. UP WT = 100 K, DWN WT = 67 K, RTWT = 88 K. SWAP MUD IN HOLE TO 9.3 PPG LSND. CIRCULATE AND CONDITION MUD. PULL INTO CASING SHOE. CLOSE HYDRIL AND PERFORM LOT. 9.3 PPG MW, 2722' TVD, 650 PSI LEAK OFF PRESSURE, EMW = 13.9 PPG. BENCH MARK ECD W/ 9.3 PPG MW = 10.8 PPG. DIRECTIONALL Y DRILL F/3305' - 4529'. 330 GPM, 134 SPM, 60 ROT, 2300 PSI. UP WT = 111, DWN WT = 72, RT WT = 86. TQ: ON BTM = 5 K, OFF BTM = 2 K. AST = 0.3 HRS, ART = 3.56 HRS. CIRCULATE AROUND TWO LOW/HIGH SWEEPS. ECD = 11.7 PPG (BENCHMARK = 11.2 PPG). POH 4 STANDS TO 4154' WITH 25 K OVER AND INTERMITTENT SWABBING. TIH 3 STANDS TO 4340' AND BACKREAM TO SHOE @ 3269'. CONTINUE BACK REAMING TO 7 5/8" CASING SHOE. 90 RPM, 1720 PSI, 300 GPM. SERVICE AND INSPECT TOP DRIVE. BLOWER HOSE BAD (WEATHER CHECKED). REMOVE AND REPLACE HOSE. SERVICE BLOCKS AND CROWN. TIH TO 4460'. HOLE SLICK. WASH LAST STAND TO BOTTOM. CIRCULATE AROUND A LOW / HIGH VIS SWEEP. DIRECTIONALL Y DRILL F/ 4529' - 6397'. CIRCULATE LOW / HIGH VIS SWEEPS AROUND EVERY 200'. REAM STANDS Printed: 6/3/2002 1 :02:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') BP EXPLORATION Operations .Summary Report Page 4 of 8 V-102 V -1 02 DRILL +COMPLETE NABORS NABORS 9ES Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 9-ES Spud Date: 5/14/2002 End: 5/28/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/19/2002 03:30 - 19:00 15.50 DRILL P PROD1 ON CONNECTIONS. UP WT = 142 K, DN WT = 85 K, ROT WT = 107 K. TO ON BTM = 7 K, OFF BTM = 6 K. 330 GPM, 2600 PSI, 80 RPM. AST = 0.35 HR, ART = 8.92 HRS. 19:00 - 20:30 1.50 DRILL P PROD1 CIRCULATE 3 SWEEPS AROUND TO GET ECD TO 11.68 PPG VS 11.2 PPG THEO. 20:30 - 23:30 3.00 DRILL P PROD1 POOH FOR WIPER TRIP WI INTERMITTENT DRAG & SWABBING TO 5800'. HOLE TIGHT. BACK REAM TO 4528' (LAST WIPER TRIP). PULL 2 STANDS DRY TO 4341'. HOLE SLICK. 23:30 - 00:00 0.50 DRILL P PROD1 TIH TO 6300'. 5/20/2002 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE TO RIH TO 6300'. WASH LAST STAND TO BOTTOM @ 6397'. PUMP SWEEP. 00:30 - 19:00 18.50 DRILL P PROD1 DIRECTIONALL Y DRILL F/6397' - 7981'. UP WT = 167 K, DN WT = 97 K, RT WT = 124 K. TO: ON BTM = 8 K, OFF BTM = 8 K. 134 SPM, 330 GPM, 3200 PSI. ART = 11.04 HRS, AST = 2.25 HRS. CALC ECD = 11.09 PPG, ECD = 11.89 PPG. PUMP LOW / HIGH SWEEPS EVERY 300'. 19:00 - 21 :00 2.00 DRILL N DPRB PROD1 NOTICED PIT GAIN ON CONNECTION. 5 BBLS. FLOW CHECK WELL. WELL FLOWING. SHUT WELL IN ON ANNULAR. TOTAL PIT GAIN = 10 BBLS. SICP= 77 PSI, SIDPP = 7 PSI. OBSERVE WELL. SUSPECT BREATHING. BLED PRESSURE TO 0 PSI. OPEN ANNULAR. OBSERVE WELL. SLIGHT FLOW. STAND BACK STAND TO ALLOW ROOM TO WORK PIPE. CIRCULATE BOTTOMS UP. NO FLUID GAIN OR LOSS. SHUT DOWN PUMPS. OBSERVE WELL. SLIGHT FLOW. 21 :00 - 00:00 3.00 DRILL P PROD1 CIRCULATE AROUND 10.1 PPG MUD. PLANNED OPERATION PRIOR TO DRILLING HRZ FORMATION. 5/21/2002 00:00 - 01 :00 1.00 DRILL P PROD1 TAKE NEW SPR W/1 0.1 PPG MUD. DIRECTIONALL Y DRILL F/7981' - 8074'. 01 :00 - 02:30 1.50 DRILL P PROD1 CIRCULATE BOTTMS UP. @ 330 GPM, 2300 PSI. CIRCULATE BOTTOMS UP @ 250 SPM, 1550 PSI. NO GAIN OR LOSSES. MONITOR WELL. 3.4 BBL GAIN 1 20 MIN. TAPPERING OFF TO o. 02:30 - 05:30 3.00 DRILL P PROD1 BACK REAM TO LAST CASING POINT @ 6397'. 110 RPM, 330 GPM, 2200 PSI. HOLE FILL OK. PULL UP 2 STANDS WITH PUMPS OFFTO 6113'.. HOLE SLICK BUT SWABBING. 05:30 - 06:00 0.50 DRILL P PROD1 RIH. STAGE UP PUMPS. WASH LAST STAND TO BOTTOM. OK. 06:00 - 07:00 1.00 DRILL P PROD1 WORK PIPE & CIRCULATE BOTTOMS UP @ 330 GPM, 2200 PSI. 07:00 - 22:00 15.00 DRILL P PROD1 DIRECTIONALL Y DRILL F/8074' - 8960'. TD WELL. UP WT = 193 K, DN WT = 114 K, RT WT = 144 K. TO: 9 K ON BTM, 9 K OFF BTM. 134 SPM, 330 GPM, 2865 PSI, ECD = 11.70 PPG (BASE LINE = 11.67 PPG). AST = 15.7 HRS. ART = 0 HRS. 22:00 - 23:00 1.00 DRILL P PROD1 CIRCULATE LOW 1 HIGH SWEEP AROUND. 23:00 - 00:00 1.00 DRILL P PROD1 STAND BACK 1 STAND. MONITOR WELL. VERY SLIGHT FLOW (BREATHING?). START WIPER TRIP TO SHOE. 5/22/2002 00:00 - 01 :00 1.00 DRILL P PROD1 POOH TO 7883'. HOLE SWABBING. NO OVER PULL. ATTEMPT TO ESTABISH CIRCULATION WITH MINIMAL RETURNS. Printed: 6/3/2002 1 :02:02 PM ) ) BP EXPLORATION Operations Summary Report Page 5 of8 Legal Well Name: V-102 Common Well Name: V -1 02 Spud Date: 5/14/2002 Event Name: DRILL +COMPLETE Start: 5/15/2002 End: 5/28/2002 Contractor Name: NABORS Rig Release: 5/28/2002 Rig Name: NABORS 9ES Rig Number: 9-ES From - To Hours Task Code NPT Phase Descri ptionof' Operations 5/22/2002 01 :00 - 02:00 1.00 DRILL P PROD1 RIH SLOW TO 8350'. ATTEMPT CIRCULATION WITH MINIMAL RETURNS. RIH TO 8915'. WORK PIPE & STAGE UP PUMPS WITH LOSSES. REGAIN FULL RETURNS. TOTAL FLUID LOSS = 52 BBLS. 02:00 - 05:30 3.50 DRILL P PROD1 STAGE UP PUMPS TO 330 GPM, 2218 PSI. CIRCULATE & CONDITION MUD WITH BOTTOMS UP. SUBSTANTIAL CUTTINGS ON BOTTOMS UP. RUN IN WITH LAST STAND TO BOTTOM @ 8960'. PUMP LOW I HIGH SWEEP AROUND. CIRCULATE AND CONDITION MUD UNTILL HOLE CLEAN. 05:30 - 10:00 4.50 DRILL P PROD1 POOH BACK REAM FI BOTTOM @ 8960' - 8074'. 320 GPM, 110 RPM, 1950 PSI. FLOW CHECK. OK. POOH SLOWLY TO 7000'. BREAK CIRCULATION. POOH TO 7 5/8" CASING SHOE. HOLE SLICK. 10:00 - 10:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE, BLOCKS, & CROWN. FLOW CHECK WELL. OK. 10:30 - 11 :00 0.50 DRILL P PROD1 CIRCULATE BOTTOMS UP @ 7 5/8' CASING SHOE. 330 GPM, 1650 PSI. UP WT = 100 K, DN WT = 77 K. 11 :00 - 14:00 3.00 DRILL P PROD1 TIH TO BOTTOM @ 8960'. FILL PIPE @ 6116'. HOLE SLICK. 14:00 - 16:00 2.00 DRILL P PROD1 CIRCULATE LOW I HIGH SWEEP AROUND @ 330 GPM, 2245 PSI. 16:00 - 21 :00 5.00 DRILL P PROD1 DROP 2.25" RABBIT. TOOH FOR ELECTRIC LOGGING. TIGHT SPOT @ 8500'. WORK THROUGH SEVERAL TIMES-OK. SLM. NO CORRECTION. 21 :00 - 22:00 1.00 DRILL P PROD1 STAND BACK HWDP. LD BHA #3: 3 De's, MWD-LWD, DC, STAB, MOTOR, & BIT. RECOVER RABBIT. 22:00 - 00:00 2.00 DRILL P PROD1 CLEAR RIG FLOOR. PJSM WTIH SCHLUMBERGER LOGGING. RU FOR ELECTRIC LOGGING. 5/23/2002 00:00 - 00:30 0.50 EVAL P PROD1 PI U SCHLUMBERGER PEX I BHCS LOGGING TOOLS. CALIBRATE TOOLS. 00:30 - 08:00 7.50 EVAL P PROD1 RIH W/ LOGGING TOOLS TO TD @ 8960'. LOG FROM 8960' - 3030'. 08:00 - 09:00 1.00 EVAL P PROD1 TOOH WI LOGGING TOOLS. L / D TOOLS AND CLEAR RIG FLOOR. 09:00 - 10:00 1.00 EVAL P PROD1 CUT AND SLIP 65' OF DRILLING LINE. SCHLUMBERGER R I U FOR DP CONVEYED MDT LOGS. 10:00 - 12:30 2.50 EVAL P PROD1 M I U LOGGING TOOLS. ZERO, FUNCTION TEST, & CALIBRATE LOGGING TOOLS. 12:30 - 14:30 2.00 EVAL P PROD1 TIH WITH HWDP AND 4" DP WITH LOGGING TOOLS ON BOTTOM TO 7 5/8" CASING SHOE @ 3269'. 14:30 - 15:00 0.50 EVAL P PROD1 CIRCULATE BOTTOMS UP AND R / U ELECTRIC LINE SHEAVE. 15:00 - 23:00 8.00 EVAL P PROD1 TIH WITH LOGGING TOOLS ON DP. BREAK CIRCULATION EVERY 10 STANDS. 23:00 - 00:00 1.00 EVAL P PROD1 M I U WIRELlNE SIDE ENTRY SUB. LATCH UP WET CONNECT. 5/24/2002 00:00 - 01 :00 1.00 EVAL P PROD1 CONTINUE TO LATCH UP WET CONNECT FOR LOGGING TOOLS. 01 :00 - 01 :30 0.50 EVAL P PROD1 CORRELATE & CALIBRATE LOGGING TOOLS. 01 :30 - 08:00 I 6.50 EVAL P PROD1 MDT LOG DOWN F/8212', SAMPLE DEPTHS: 8452', 8456', 8465',8470',8476',8483',8495',8508',8521', 8588',8593', 18736.5',8741', & 8761'. I Printed: 6/3/2002 1 :02:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION, Operations Summary Report Page 6 of 8 V -1 02 V-102 DRILL +COMPLETE NABORS NABORS 9ES Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 9-ES Spud Date: 5/14/2002 End: 5/28/2002 Date From - To Hours Task Code NPT Phase ,Description of Operations 5/24/2002 08:00 - 10:00 2.00 EVAL P PROD1 POOH WITH DP TO WIRE LINE SIDE ENTRY SUB @ 8120'. POWER DOWN TOOLS, UNLATCH WET CONNECT. POOH WITH ELECTRIC LINE. R / D WIRELlNE SIDE ENTRY SUB. 10:00 - 13:00 3.00 EVAL P PROD1 POOH WITH DP TO 5019'. M / U WIRELlNE SIDE ENTRY SUB. RIH WITH ELECTRIC LINE AND LATCH UP WET CONNECT. TEST TOOLS. 13:00 - 00:00 11.00 EVAL P PROD1 TIH WITH MDT TOOLS ON DP TO 6066'. LOGGING UP SAMPLES @ 6066' & 5972'. UP WT = 140 K, DWN WT = 85 K. 5/25/2002 00:00 - 09:00 9.00 EVAL P PROD1 CONTINUE MDT LOGGING @ 5740' & 5436'. 09:00 - 10:30 1.50 EVAL P PROD1 POOH TO WIRELlNE SIDE ENTRY SUB @ 5019'. POWER DOWN TOOLS. UNLATCH WET CONNECT AND POOH WITH ELECTRIC LINE. N I D SIDE ENTRY SUB, XO's AND ELECTRICE LINE SHEAVES. 10:30 - 11 :30 1.00 EVAL P PROD1 BREAK CIRCULATION, STAGE UP PUMPS TO 4 BPM @ 425 PSI. RECIPROCATE STRING. UP WT = 128 K, DWN WT = 82 K. 11 :30 - 14:00 2.50 EVAL P PROD1 MONITOR WELL. PUMP SLUG. TOOH. MONITOR WELL AT CASING SHOE. OK. POOH. STAND BACK HWDP. 14:00 - 18:00 4.00 EVAL P PROD1 PJSM. BREAK DOWN LOGGING TOOLS. BLEED OFF PRESSURE. DUMP LOG SAMPLES. CLEAR RIG FLOOR. 18:00 - 21 :30 3.50 EVAL P PROD1 PULL WEAR BUSHING, R I U TEST EQUIPMENT. TEST BOPE TO 250 PSI LOW I 5 MIN & 4500 PSI HIGH 15 MIN. TEST ANNULAR TO 250 PSI LOW / 5 MIN & 3500 PSI HIGH I 5 MIN. WITNESSING TEST WAIVE BY CHUCK SCHEAVE (AOGCC). CHOKE MANIFOLD TESTED WHILE POOH. 21 :30 - 23:00 1.50 EVAL P PROD1 P / U BHA #4: HOLE OPENER, FLOAT SUB, XO, HWDP & JARS. RIH TO CASING SHOE @ 3269'. 23:00 - 23:30 0.50 EVAL P PROD1 CIRCULATE BOTTOMS UP. STAGE UP PUMPS TO 330 GPM @ 780 PSI. 23:30 - 00:00 0.50 EVAL P PROD1 TI H TO 4400'. 5/26/2002 00:00 - 00:30 0.50 EVAL P PROD1 STAGE UP PUMPS TO 330 GPM, 980 PSI. CIRCULATE BOTTOMS @ 4440'. RECIPROCATE PIPE. 00:30 - 01 :00 0.50 EVAL P PROD1 TIH TO 5195'. HOLE SLICK. 01 :00 - 01 :30 0.50 EVAL P PROD1 STAGE UP PUMPS TO 330 GPM, 1100 PSI. CIRCULATE BOTTOMS UP. RECIPROCATE PIPE. 01 :30 - 02:00 0.50 EVAL P PROD1 TIH TO 6316'. HOLE SLICK. 02:00 - 03:00 1.00 EVAL P PROD1 STAGE UP PUMPS TO 330 GPM, 1175 PSI. CIRCULATE BOTTOMS UP. MUD THICK AND SLIGHT GAS ON BOTTOMS UP. 03:00 - 04:00 1.00 EVAL P PROD1 TIH TO 8597'. HOLE SLICK. 04:00 - 07:30 3.50 EVAL P PROD1 STAGE UP PUMPS. WASH LAST STAND TO BOTTOM @ 8960'. CIRCULATE @ 330 GPM, 1490 PSI. ROTATE PIPE @ 110 RPM AND RECIPROCATE. SOME GAS AND THICK MUD OFF BOTTOM. PUMP LOW I HIGH SWEEP AROUND. CONDITION MUD TO 15 YP FOR CASING RUN. UP WT = 206 K, DWN WT = 117 K, ROT WT = 148 K. SPOT CASING PILL ON BOTTOM FI 8960' - 6400'. 07:30 - 09:30 2.00 EVAL P PROD1 TOOH RACK BACK DP TO 7990'. LAY DOWN DP FROM 7990' - 6400'. FLOW CHECK. OK. 09:30 - 10:30 1.00 EVAL P PROD1 BREAK CIRCULATION. SPOT 153 BBLS "STEELSEAL" PILL I FROM 6409' - 3269' (7 5/8" CSG SHOE). 330 GPM, 1190 PSI. RECIPROCATE AND ROTATE @ 60 RPM. Printed: 6/3/2002 1 :02:02 PM ) ) BPEXPLORATION Operations Summary Report Page 70f 8 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: V -1 02 V -1 02 DRILL +COMPLETE NABORS NABORS 9ES Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 9-ES Spud Date: 5/14/2002 End: 5/28/2002 Date From - To Hours Task Code NPT Phase Description, of Operations 5/26/2002 10:30 - 17:00 6.50 EVAL P PROD1 POOH L / D DP TO HWDP. TIH WITH STANDS IN DERRICK. L / D DP, HWDP, & BHA. 17:00 - 17:30 0.50 CASE P PROD1 PULL WEAR BUSHING. P / U CASING HANGER AND LANDING JT. DUMMY RUN TO CASING HEAD. OK. 17:30 - 18:30 1.00 CASE P PROD1 R / U TO RUN 31/2" x 51/2" CASING STRING. 18:30 - 19:00 0.50 CASE P PROD1 PJSM. 19:00 - 23:30 4.50 CASE P PROD1 P / U FLOAT EQUIPMENT & SHOE TRACK. CHECK FLOATS. RUN IN HOLE WITH 3 1/2" CASING AND TOOLS. CHANGE OUT HANDLING TOOLS AND RUN IN HOLE WITH 5 1/2" CASING STRING TO 3269'. FILLING EVERY JT. 23:30 - 00:00 0.50 CASE P PROD1 CHANGE TO 200T SPIDER ELEVATORS. R / U FILL UP TOOL AND STABBING BOARD. 5/27/2002 00:00 - 00:30 0.50 CASE P COMP CIRCULATE 1.5 TIMES BOTTOMS UP @ 7 5/8" CASING SHOE (3269'). 410 PSI, 2 BPM. UP WT = 78 K, DN WT = 66 K. 00:30 - 02:30 2.00 CASE P COMP TIH W/ 51/2" CASING @ 60 FPM TO 4400'. BREAK CIRCULATION EVERY 3 JTS. 02:30 - 03:30 1.00 CASE P COMP CIRCULATE BOTTOM UP @ 4400'. 2 BPM, 480 PSI. RECIPROCATE CASING. UP WT = 90 K, DN WT = 69 K. 03:30 - 04:30 1.00 CASE P COMP CONTINUE TIH TO 5220'. BREAKING CIRCULATION EVERY 3 JTS. 60 FPM. 04:30 - 05:30 1.00 CASE P COMP CIRCULATE BOTTOMS UP @ 5220'. RECIPROCATE PIPE. 2 BPM, 480 PSI. UP WT = 101 K, DN WT = 73 K. 05:30 - 07:00 1.50 CASE P COMP CONTINUE RIH WITH CASING @ 60 FPM TO 5290'. BREAKING CIIRCULATION EVERY 3 JTS. 07:00 - 08:00 1.00 CASE P COMP CIRCULATE BOTTOMS UP @ 6290'. 2 BPM, 553 PSI. RECIPROCATE PIPE. UP WT = 123 K, DN WT = 76 K. 08:00 - 14:00 6.00 CASE P COMP CONTINUE RIH @ 30 FPM TO CASING TD @ 8947'. HOLE SLICK. TOTAL OF 19 JTS 3 1/2", 9.2 #, L -80, IBT-M & 200 JTS OF 51/2",15.5#, L-80, IBT-M, CASINGS PLUS JEWELRY RAN IN HOLE. M / U 51/2" CASING HANGER AND LANDING JT. 14:00 - 14:30 0.50 CASE P COMP R / D FILL-UP TOOL. BLOW DOWN TOP DRIVE. R / U CEMENT HEAD AND LINES. 14:30 - 17:00 2.50 CASE P COMP CIRCULATE AND CONDITION MUD FOR CEMENT JOB. STAGE PUMPS UP TO 4 BPM, 710 PSI. UP WT = 170 K, DWN WT = 90 K. RECIPROCATE PIPE. NO LOSSES. 17:00 - 19:30 2.50 CASE P COMP SWITCH TO DOWELL. PUMP 5 BBLS. CW-100, TEST LINES TO 3500 PSI., PUMP 15 BBLS CW-100 & 40 BBLS 11.0 PPG MUDPUSH XL SPACER @ 3 BPM. PUMP 70 BBLS (150 SX), 11.5 PPG, 2.67 YEILD, LiteCRETE LEAD SLURRY, AT 3 BPM WITH THE FOLLOWING ADDITIVES: .02% BWOC D046 + 0.25% BWOC D167 + 0.2 GAUSX B153. PUMP 40 BBLS (177 SX), 15.8 PPG, 1.17 YEILD, LATEX "G" TAIL SLURRY @ 4 BPM WITH THE FOLLOWING ADDITIVES: 0.04% BWOC D800 + 0.30% BWOC D065 + 0.2 GAUSX D047 + 2.0 GAUSX D600G. FLUSH LINES & DROP COMBO TOP & BOTTOM WIPER PLUGS. DISPLACE CEMENT WITH RIG PUMP, 202 BBLS SEAWATER @ 4 BPM. BUMP PLUG WITH 500 PSI OVER PUMP PRESSURE TO 2100 PSI. CHECK FLOATS- OK. RECIPROCATE PIPE UNTIL 20 BBLS TAIL CEMENT 19:30 - 20:30 I OUT THE SHOE. 1.00 CASE P COMP R / D CEMENT HEAD. BREAK OUT LANDING JT AND L / D I I Printed: 6/3/2002 1 :02:02 PM ) ") BP EXPLORATION OperationsSummáry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-102 V -1 02 DRILL +COMPLETE NABORS NABORS 9ES From - To Hours Task Code NPT Phase 5/27/2002 19:30 - 20:30 1.00 CASE P 20:30 - 21 :00 0.50 RUNCOrvP 21 :00 - 00:00 3.00 RUNCOrvP 00:00 - 06:00 6.00 RUNCOrvP 06:00 - 07:00 1.00 RUNCOrvP 07:00 - 10:30 3.50 RUNCOrvP 10:30-11:30 1.00 f'UNCOrvP 11 :30 - 14:30 3.00 RUNCOrvP 14:30 - 15:00 0.50 RUNCOrvP 15:00 - 17:00 2.00 RUNCOrvP 17:00 - 19:30 2.50 RUNCOrvP 19:30 - 21 :00 1.50 RUNCOrvP 21 :00 - 22:00 1.00 RUNCOrvP 22:00 - 00:00 2.00 RUNCOrvP CaMP CaMP CaMP 5/28/2002 CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP Page 8 of 8 Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 9-ES Spud Date: 5/14/2002 End: 5/28/2002 Description of Operations IN PIPE SHED. SET 5 1/2" PACK OFF BUSHING. RILDS. TEST PACK OFF TO 5000 PSI. OK. R /0 CASING ELEVATORS. R / U TO RUN 31/2" COMPLETION STRING. M / U 4" SEAL ASSEMBL Y& RIH WITH 3 1/2", 9.2#, L-80, IBT-M AND JEWELRY. Ran 3.5 " completion striing. MU circulation swedge and land seals in PBR. Pressure up to 200 psi to verify seals in PBR. Bleed off and establish space out dimension. Reverse in clean brine with corrosion inhibitor. Space out and land tubing. Test tubing to 4500 psi for 30 minutes OK. Bleed tubing back to 3000 psi. Test annulus to 4500 psi for 30 minutes. OK. Bleed off tubing and shear RP valve. Set TWC. and test from below with 2800 psi. Perform L.O.T. EMW=12.4 Pumped 80 bb110.1 ppg 3 bpm @ 1000 psi. Freeze protect outer annulus with 40 bbl crude oil. NO BOP. NU tree and test to 5000 psi OK. Pull TWC with lubricator. Freeze protect inner annulus and tubing with 90 bbl diesel. Displace diesel to annulus and "U" tube into tubing. Set BPV. Release rig. Printed: 6'3/2002 1 :02:02 PM ) ') Well: Field: API: Permit: V-102 Prudhoe Bay Unit 50-029-23070-00 202-033 Rig Accept: 05/14/02 Rig Spud: 05/14/02 Rig Release: OS/28/02 Drilling Rig: Nabors 9ES POST RIG WORK 06/19/02 RAN 2.5 X 14' DUMMY GUN TO 8822' SLM (TARGET DEPTH WAS 8490' SLM). LEFT WELL SHUT-IN. 06/23/02 LOG PRESSITEMP FROM 8100' TO 8836' (TD). LOG JEWELRY FROM TD TO 8100', EOT @ 8232'. PERF 8450' - 8490' IN TWO RUNS W/2.5" POWERFLOW (BH) HMX GUNS, 6 SPF, 60 PHASING, ORIENTED 10 DEG OFF BOTTOM. ALL SHOTS FIRED. WHP REMAINED 0 PSI THROUGHOUT PERF JOB. NOTIFY PAD OPER OF STATUS. LEAVE WELL SHUT IN FOR STATIC. 06/27/02 PERFORM SBHP WI PETRADAT GAUGES AND MRT'S (162 & 170). SET CIS, PULL DCK-3 FROM STA# 1, RUN SPMG BTM IN STA# 1. MIT IA TO 4000#. INJECTIVITY TEST OF 1 BPM FOR 20 BBLS. 06/28/02 MIT IA TO 4000#. INJECTIVITY TEST W/20 BBLS DIESEL @ 1 BPM. PASSED MIT. SET SPMG IN STA# 1, MITIA TO 4000#, OK (-125# IN 30 MIN) 1 BPM INJ TEST. 20 BBLS AWAY, OK. PULL CIS. LEFT WELL SI FOR FRAC. FRAC'D KUP C SANDS WI YF125LG SYSTEM AND 190.6 K# C-LlTE. SCREENED OUT @ 97 BBLS INTO THE 10 PPGA 12/18 STG TO 7200 PSI. PLACED 162 K# 16/20 AND 5.9 K# 12/18 BEHIND PIPE, LEFT 22.8K# (37 BBLS) C-LlTE IN CSG, EST. TOS NEAR SURFACE. AVG TREAT = 4640 PSI, LOAD TO RECOVER IS 1202 BBLS, WELL NOT FREEZE PROTECTED. LOST ONE TREESAVER CUP ELEMENT, 1" H X 2.992" O.D. X 0.25" THICK IN HOLE. 06/29/02 TAGGED UNKNOWN OBSTRUCTION AT 486'. FOUND BITS OF RUBBER IN TREE AT FLANGE BELOW FLOW CROSS. KNOCKED BITS ON TO CLOSED SURFACE SAFETY VALVE TO BE REMOVED BY VAC TRUCK. RU SURFACE IRON, UNABLE TO RAISE MAST DUE TO HIGH CROSS WIND (22-27 MPH - 35 GUST). WINDS DOWN TO 22-24 STEADY, FINISH RU. PT 200/4000 PSI, CHIKSAN LEAK ON REEL CONNECTION. REPAIR CHIKSAN. 07/01/02 PT EQUIP. FLUSH TREE TO TANKS TO CLEAN OUT SAVER RUBBER DEBRIS. RIH TAG ICE PLUG AT 500' WASH THRU HARD TO SLUSHY ICE TO 1225, STARTED GETTING LIGHT SAND RETURNS AT 1225'. CONTINUE WASHING SAND STRINGERS TO 6000' AND START PUMPING 10 BBL BIO PILLS. CLEAN OUT TO 8350', CHASE WITH BIO PILL FROM 7800'. WASH BACK UP 50 DEG ANGLE HOLE SECTION TO 3000' WITH BIO PILL. RBIH, CLEAN OUT TO 8750' WITH HEC SWEEPS. CIRCULATE AND RECIPROCATE BELOW PERFS FOR 45 MIN. POOH WASHING JEWELRY. WELL FREEZE PROTECTED WITH NEAT METHANOL TO 3000'. LEAVE WELL SHUT IN, NOTIFY DSO OF STATUS. 07/03/02 DRIFT WI 2.50" CENT & 1.75"SB. TAG TD @ 8636' SLM. UNABLE TO DO GAS LIFT DUE TO FRAC SAND IN WELL. RDMO 07/05/02 BRUSH AND FLUSH TUBING WI HBR, 100 BBLS HOT DIESEL. SET 3112 X LOCK CATCHER. PULL STA 1, PETREDAT SIDE POCKET MEMORY GAUGE, BTM LATCH. PULL STA 2 AND 3, BTM LATCH 1" DGLV. SET LGLV STA# 3 (16/64" TRO. 1747#), STA# 2 (16/64",1789#), STA# 1 (20/64" ORIF). PUMPED 116 BBLS OF 1800 DIESEL DOWN TBG AT A RATE OF 1.1 BPM FOR BRUSH AND FLUSH. V-102, Post Drilling Work Page 2 ) ') 07/06/02 FINISH SETTING STA# 1 S/O. PULL 3 1/2" XX C-SUB. RDMO GAVE WELL BACK TO PAD OPP. LEAVE SHUT IN. 07/17/02 PUMP 150BBLS HEATED DIESEL AND 20BBLS 100% METHANOL TO WARM UP AND FREEZE PROTECT WELL FOR TEST UNIT. ANADRILL SCHLUMBERGER Survey report Client. ..................: BP Exploration (Alaska) Inc. Field... ....... ..........: Prudhoe Bay / Borealis We 11. . . . . . . . . . . . . . . . . . . . .: V -102 API number...............: 50-029-23070-00 Engineer....... ..........: St. Amour COUNTY: ..................: 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.......: 53.60 ft KB above permanent. . . . . . . : NA DF above permanent. ......: 82.10 ft ----- Vertical section origin---------------- Latitude (+N/S-)... ......: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-) ........: -999.25 ft Azimuth from rotary table to target: 343.73 degrees [(c)2002 Anadrill IDEAL ID6_1C_10) 22-May-2002 06:32:20 Spud date............... .: Last survey date.... .....: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 14-May-2002 22-May-02 99 0.00 ft 8960.00 ft ~ ----- Geomagnetic data ---------------------- Magnetic model........ ...: BGGM version 2001 Magnetic date............: 14-May-2002 Magnetic field strength..: 1149.53 HCNT Magnetic dec (+E/W-).....: 26.05 degrees Magnetic dip.............: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G. . . . . . . . . . . . . . : R..............: Dip. . . . . . . . . . . . : of G...........: of R...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.53 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.05 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.05 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 '~ ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) --- -------- -------- 1 2 3 4 5 0.00 50.00 100.00 175.00 267.00 6 7 8 9 10 359.00 454.00 546.00 640.00 731.00 11 12 13 14 15 825.00 940.95 1033.84 1124.94 1217.79 16 17 18 19 20 1311.76 1405.14 1498.99 1590.60 1685.52 21 22 23 24 25 1776.16 1869.60 1962.86 2056.54 2150.38 26 27 28 29 30 2243.98 2337.03 2430.06 2524.50 2617.69 ------ ------ Incl angle (deg) ------ ------ 0.00 0.47 0.60 0.95 1.07 0.19 1.31 3.28 5.44 7.45 9.86 11.62 14.20 18.11 22.32 25.38 27.25 30.84 34.57 38.49 41.53 42.76 43.69 44.55 45.25 44.62 45.04 46.38 45.88 45.18 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 343.73 141.81 140.32 129.18 135.69 257.77 314.47 327.15 334.35 346.08 349.84 351.85 349.19 347.39 344.69 342.74 341.86 341.57 344.61 344.76 345.81 344.18 342.51 342.27 342.24 342.59 342.75 342.75 342.24 342.53 ------ ------ 0.00 50.00 50.00 75.00 92.00 92.00 95.00 92.00 94.00 91.00 94.00 115.95 92.89 91.10 92.85 93.97 93.38 93.85 91.61 94.92 90.64 93.44 93.26 93.68 93.84 93.60 93.05 93.03 94.44 93.19 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 100.00 174.99 266.98 358.97 453.96 545.88 639.61 730.03 822.95 936.87 1027.40 1114.89 1202.00 1287.94 1371.64 1453.67 1530.75 1607.01 1676.43 1745.71 1813.67 1880.92 1947.39 2013.65 2079.64 2144.60 2210.05 2275.33 22-May-2002 06:32:20 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.19 -0.62 -1.49 -2.88 -3.63 -2.67 0.77 7.75 17.90 31.99 53.43 74.03 99.29 131.34 169.33 210.71 256.23 305.71 362.19 420.43 483.11 546.97 612.17 678.39 744.48 810.07 876.65 944.72 1011.20 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 -0.16 -0.52 -1.22 -2.32 -2.96 -2.23 0.71 6.99 16.61 30.45 51.78 72.23 97.04 128.14 164.59 204.02 247.28 294.63 349.12 405.47 466.03 527.21 589.37 652.46 715.48 778.10 841.70 906.63 970.01 0.00 0.13 0.42 1.15 2.34 2.80 1.87 -0.31 -3.70 -6.99 -9.87 -13.28 -16.74 -21.93 -29.74 -40.43 -53.03 -67.33 -81.65 -96.57 -111.35 -127.59 -145.91 -165.64 -185.83 -205.80 -225.34 -245.09 -265.57 -285.69 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 0.21 0.67 1.68 3.30 4.07 2.91 0.78 7.91 18.02 32.01 53.45 74.15 99.48 131.55 169.48 210.80 256.28 305.74 362.23 420.49 483.18 547.03 612.20 678.40 744.49 810.07 876.65 944.72 1011.20 0.00 141.81 141.23 136.58 134.64 136.66 140.13 336.39 332.11 337.18 342.03 345.62 346.95 347.26 346.93 346.20 345.43 344.77 344.51 344.54 344.64 344.69 344.53 344.30 344.10 343.95 343.85 343.77 343.67 343.59 2 of 5 DLS (deg/ 100f) ----- 0.00 0.94 0.26 0.51 0.18 1.28 1.28 2.20 2.37 2.63 2.63 1.55 2.85 4.33 4.64 3.36 2.05 3.83 4.45 4.13 3.44 1.76 1.58 0.94 0.75 0.72 0.47 1.44 0.66 0.78 ------ ------ Srvy tool type Tool qual type ----- ------ ------ TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR '-' GYR 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 22-May-2002 06:32:20 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 31 2710.82 44.44 341.62 93.13 2341.40 1076.81 1032.46 -305.89 1076.82 343.50 1.05 MWD_IFR_MSA - 32 2803.81 45.68 342.86 92.99 2407.09 1142.60 1095.14 -325.96 1142.62 343.42 1.63 MWD_IFR_MSA - 33 2896.30 46.58 344.04 92.49 2471.18 1209.28 1159.05 -344.94 1209.29 343.43 1.34 MWD_IFR_MSA - 34 2989.49 47.86 343.92 93.19 2534.48 1277.67 1224.79 -363.82 1277.69 343.46 1.38 MWD_IFR_MSA - 35 3083.60 47.41 344.00 94.11 2597.89 1347.21 1291.62 -383.03 1347.22 343.48 0.48 MWD_IFR_MSA - 36 3176.39 48.49 342.50 92.79 2660.04 1416.10 1357.59 -402.90 1416.12 343.47 1.67 MWD_IFR_MSA - 37 3222.61 48.32 342.41 46.22 2690.73 1450.66 1390.55 -413.32 1450.68 343.45 0.40 MWD_IFR_MSA - 'c~' 38 3348.85 46.98 342.92 126.24 2775.77 1543.94 1479.61 -441.12 1543.96 343.40 1.10 MWD_IFR_MSA - 39 3443.39 46.77 342.53 94.54 2840.39 1612.93 1545.50 -461.61 1612.96 343.37 0.37 MWD_IFR_MSA - 40 3536.45 49.34 346.19 93.06 2902.60 1682.11 1612.13 -480.22 1682.14 343.41 4.02 MWD_IFR_MSA - 41 3629.60 49.40 346.84 93.15 2963.26 1752.72 1680.88 -496.70 1752.73 343.54 0.53 MWD_IFR_MSA - 42 3722.75 49.48 346.79 93.15 3023.83 1823.39 1749.78 -512.85 1823.39 343.66 0.10 MWD_IFR_MSA - 43 3816.20 49.79 347.44 93.45 3084.35 1894.47 1819.19 -528.72 1894.47 343.79 0.63 MWD_IFR_MSA - 44 3909.46 50.20 346.97 93.26 3144.31 1965.77 1888.85 -544.54 1965.78 343.92 0.59 MWD_IFR_MSA - 45 4003.29 50.18 344.65 93.83 3204.39 2037.79 1958.72 -562.21 2037.81 343.99 1.90 MWD_IFR_MSA - 46 4097.46 48.56 343.54 94.17 3265.71 2109.25 2027.45 -581.79 2109.28 343.99 1.94 MWD_IFR_MSA - 47 4191.37 49.28 345.12 93.91 3327.42 2180.03 2095.61 -600.90 2180.06 344.00 1.48 MWD_IFR_MSA - 48 4285.61 49.11 345.34 94.24 3389.00 2251.34 2164.58 -619.09 2251.38 344.04 0.25 MWD_IFR_MSA - 49 4379.65 49.17 346.23 94.04 3450.52 2322.42 2233.53 -636.55 2322.47 344.09 0.72 MWD_IFR_MSA - 50 4472.80 48.89 345.29 93.15 3511.60 2392.71 2301.70 -653.85 2392.77 344.14 0.82 MWD_IFR_MSA - 51 4564.73 49.40 345.77 91.93 3571.74 2462.20 2369.03 -671.22 2462.28 344.18 0.68 MWD_IFR_MSA - -~ 52 4657.08 48.23 344.27 92.35 3632.55 2531.68 2436.16 -689.18 2531.77 344.20 1.76 MWD_IFR_MSA - 53 4750.80 47.46 342.79 93.72 3695.45 2601.16 2502.79 -708.87 2601.24 344.19 1.43 MWD_IFR_MSA - 54 4843.74 47.11 343.43 92.94 3758.50 2669.44 2568.13 -728.71 2669.51 344.16 0.63 MWD_IFR_MSA - 55 4937.55 46.75 342.34 93.81 3822.56 2737.96 2633.62 -748.88 2738.02 344.13 0.93 MWD_IFR_MSA - 56 5030.37 46.79 343.24 92.82 3886.13 2805.58 2698.22 -768.88 2805.63 344.09 0.71 MWD_IFR_MSA - 57 5124.73 46.79 343.45 94.36 3950.74 2874.35 2764.11 -788.60 2874.40 344.08 0.16 MWD_IFR_MSA - 58 5217.71 46.84 344.16 92.98 4014.37 2942.15 2829.22 -807.50 2942.20 344.07 0.56 MWD_IFR_MSA - 59 5311.39 47.48 342.78 93.68 4078.07 3010.83 2895.06 -827.05 3010.88 344.06 1.28 MWD_IFR_MSA - 60 5404.43 47.46 342.69 93.04 4140.96 3079.39 2960.54 -847.40 3079.43 344.03 0.07 MWD_IFR_MSA- ANADRILL SCHLUMBERGER Survey Report 22-May-2002 06:32:20 Page 4 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 61 5496.55 47.62 341.99 92.12 4203.15 3147.33 3025.30 -868.02 3147.36 343.99 0.59 MWD_IFR_MSA - 62 5590.02 47.80 341.08 93.47 4266.05 3216.42 3090.88 -889.92 3216.44 343.94 0.75 MWD_IFR_MSA - 63 5683.47 47.73 340.73 93.45 4328.86 3285.52 3156.26 -912.55 3285.53 343.87 0.29 MWD_IFR_MSA - 64 5777.63 48.05 339.86 94.16 4392.00 3355.25 3222.02 -936.11 3355.25 343.80 0.77 MWD_IFR_MSA - 65 5871.88 48.18 338.31 94.25 4454.93 3425.18 3287.56 -961.15 3425.18 343.70 1.23 MWD_IFR_MSA - 66 5965.71 47.82 338.85 93.83 4517.71 3494.63 3352.47 -986.62 3494.64 343.60 0.57 MWD - IFR_MSA - '- 67 6060.21 46.80 338.82 94.50 4581.79 3563.84 3417.25 -1011.70 3563.86 343.51 1.08 MWD_IFR_MSA - 68 6153.20 47.29 339.14 92.99 4645.15 3631.66 3480.78 -1036.11 3631.71 343.42 0.58 MWD_IFR_MSA - 69 6246.78 47.30 338.37 93.58 4708.62 3700.17 3544.87 -1061.03 3700.26 343.34 0.60 MWD_IFR_MSA - 70 6340.46 46.93 337.22 93.68 4772.37 3768.44 3608.42 -1086.97 3768.58 343.24 0.98 MWD_IFR_MSA - 71 6433.06 47.25 336.39 92.60 4835.42 3835.77 3670.76 -1113.68 3835.98 343.12 0.74 MWD_IFR_MSA - 72 6526.17 45.81 339.87 93.11 4899.49 3902.99 3733.44 -1138.87 3903.28 343.04 3.12 MWD_IFR_MSA - 73 6618.34 45.28 342.26 92.17 4964.04 3968.70 3795.66 -1160.22 3969.02 343.00 1.94 MWD_IFR_MSA - 74 6711.46 44.75 342.45 93.12 5029.87 4034.55 3858.42 -1180.18 4034.88 342.99 0.59 MWD_IFR_MSA - 75 6802.94 44.58 341.80 91.48 5094.94 4098.83 3919.63 -1199.92 4099.18 342.98 0.53 MWD_IFR_MSA - 76 6896.10 44.51 340.46 93.16 5161.33 4164.11 3981.46 -1221.05 4164.49 342.95 1.01 MWD_IFR_MSA - 77 6989.04 41.71 343.24 92.94 5229.18 4227.57 4041.78 -1240.87 4227.98 342.93 3.64 MWD_IFR_MSA - 78 7083.04 39.10 344.23 94.00 5300.75 4288.49 4100.27 -1257.95 4288.89 342.94 2.86 MWD_IFR_MSA - 79 7176.84 36.41 345.61 93.80 5374.91 4345.90 4155.71 -1272.91 4346.28 342.97 3.01 MWD_IFR_MSA - 80 7269.46 35.68 344.68 92.62 5449.80 4400.38 4208.38 -1286.88 4400.74 343.00 0.99 MWD_IFR_MSA - 81 7363.13 34.48 343.79 93.67 5526.45 4454.21 4260.19 -1301.50 4454.56 343.01 1.39 MWD_IFR_MSA - ~ 82 7457.62 33.79 343.64 94.49 5604.66 4507.23 4311.09 -1316.36 4507.58 343.02 0.74 MWD_IFR_MSA - 83 7550.43 30.98 345.60 92.81 5683.03 4556.93 4359.00 -1329.58 4557.26 343.04 3.23 MWD_IFR_MSA - 84 7643.81 27.46 343.37 93.38 5764.52 4602.49 4402.92 -1341.72 4602.82 343.05 3.95 MWD_IFR_MSA - 85 7737.56 23.73 341.16 93.75 5849.06 4642.97 4441.50 -1354.00 4643.30 343.05 4.11 MWD_IFR_MSA - 86 7830.77 19.23 339.87 93.21 5935.77 4677.04 4473.68 -1365.35 4677.39 343.03 4.85 MWD_IFR_MSA - 87 7925.09 17.38 337.14 94.32 6025.32 4706.53 4501.25 -1376.17 4706.91 343.00 2.16 MWD_IFR_MSA - 88 8016.96 14.84 335.35 91.87 6113.57 4731.81 4524.59 -1386.40 4732.23 342.96 2.82 MWD_IFR_MSA - 89 8110.75 12.94 334.15 93.79 6204.62 4754.05 4544.95 -1395.99 4754.51 342.93 2.05 MWD_IFR_MSA - 90 8204.30 11.24 332.96 93.55 6296.09 4773.33 4562.50 -1404.71 4773.85 342.89 1.84 MWD_IFR_MSA- ANADRILL SCHLUMBERGER Survey Report 22-May-2002 06:32:20 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8297.65 10.11 331.71 93.35 6387.82 4790.28 4577.82 -1412.73 4790.85 342.85 1.24 MWD- IFR_MSA - 92 8391.91 9.13 331.30 94.26 6480.76 4805.68 4591.67 -1420.24 4806.30 342.81 1.04 MWD _IFR_MSA - 93 8485.48 8.56 330.31 93.57 6573.21 4819.70 4604.23 -1427.25 4820.37 342.78 0.63 MWD- IFR_MSA - 94 8577.51 8.66 328.62 92.03 6664.21 4833.05 4616.09 -1434.25 4833.78 342.74 0.30 MWD- IFR_MSA - 95 8670.73 8.33 327.64 93.22 6756.40 4846.32 4627.79 -1441.52 4847.10 342.70 0.39 MWD - IFR_MSA - 96 8764.86 7.59 327.51 94.13 6849.63 4858.84 4638.79 -1448.51 4859.69 342.66 0.79 MWD- IFR_MSA - 97 8858.08 7.48 328.34 93.22 6942.04 4870.60 4649.15 -1455.00 4871.51 342.62 0.17 MWD- IFR_MSA - '-' 98 8905.63 7.35 328.20 47.55 6989.19 4876.51 4654.37 -1458.23 4877.46 342.60 0.28 MWD- IFR_MSA - Projected to TD: 99 8960.00 7.19 328.02 54.37 7043.13 4883.14 4660.21 -1461.86 4884.12 342.58 0.30 Proj [(c)2002 Anadrill IDEAL ID6_1C_10] -/ õ V-102 Survey Report - Geodetic Schlumberger Report Date: 22-May-02 Survey t DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 342.580° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure t Slot: V-Pad IV-102 TVD Reference Datum: KB Well: V-102 TVD Reference Elevation: 82.100 ft relative to MSL Borehole: V-102 Sea Bed t Ground Level Elevation: 55.000 ft relative to MSL UWltAPI#: 500292307000 Magnetic Declination: +25.930° Survey Name t Date: V-1021 May 22,2002 Total Field Strength: 57499.478 nT Tort I AHD t DDlt ERD ratio: 136.369° 14900.52 ft 15.930 10.69E Magnetic Dip: 80.765° .~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: May 23,2002 Location LatlLong: N 70 19 40.870, W 1491556.551 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5970089.060 ftUS, E 590540.350 ftUS North Reference: True North Grid Convergence Angle: -+0.69143910° Total Corr Mag North -> True North: +25.930° Grid Scale Factor: 0.99990931 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim I TVD I VSec Nt-S I EI-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970089.06 590540.35 N 70 1940.870 W 1491556.551 50.00 0.47 141.81 50.00 -0.19 -0.16 0.13 0.94 5970088.90 590540.48 N 701940.869 W 1491556.547 100.00 0.60 140.32 100.00 -0.63 -0.52 0.42 0.26 5970088.54 590540.78 N 70 1940.865 W 149 15 56.538 175.00 0.95 129.18 174.99 -1.51 -1.22 1.15 0.51 5970087.86 590541.52 N 70 1940.858 W 1491556.517 267.00 1.07 135.69 266.98 -2.91 -2.32 2.34 0.18 5970086.77 590542.72 N 70 1940.848 W 1491556.482 359.00 0.19 257.77 358.97 -3.66 -2.96 2.80 1.28 5970086.13 590543.18 N 70 1940.841 W 1491556.469 454.00 1.31 314.47 453.96 -2.69 -2.23 1.87 1.28 5970086.85 590542.24 N 70 19 40.848 W 149 15 56.496 546.00 3.28 327.15 545.88 0.77 0.71 -0.31 2.20 5970089.77 590540.03 N 701940.877 W 1491556.560 640.00 5.44 334.35 639.61 7.78 6.99 -3.70 2.37 5970096.00 590536.57 N 70 19 40.939 W 149 15 56.659 -" 731.00 7.45 346.08 730.03 17.94 16.61 -6.99 2.63 5970105.58 590533.16 N 701941.034 W 1491556.755 825.00 9.86 349.84 822.95 32.00 30.45 -9.87 2.63 5970119.38 590530.11 N 701941.170 W 1491556.839 940.95 11.62 351.85 936.87 53.38 51.78 -13.28 1.55 5970140.67 590526.45 N 701941.380 W 1491556.938 1033.84 14.20 349.19 1 027.40 73.93 72.23 -16.74 2.85 5970161.08 590522.74 N 70 1941.581 W 14915 57.039 1124.94 18.11 347.39 1114.89 99.15 97.04 -21.93 4.33 5970185.82 590517.25 N701941.825 W1491557.191 1217.79 22.32 344.69 1202.00 131.17 128.14 -29.74 4.64 5970216.82 590509.07 N 701942.131 W 1491557.419 1311.76 25.38 342.74 1287.94 169.15 164.59 -40.43 3.36 5970253.14 590497.94 N 701942.489 W 1491557.731 1405.14 27.25 341.86 1371.64 210.54 204.02 -53.03 2.05 5970292.41 590484.87 N 70 1942.877 W 1491558.099 1498.99 30.84 341.57 1453.67 256.09 247.28 -67.33 3.83 5970335.48 590470.05 N 70 1943.302 W 14915 58.516 V-102 ASP Final Survey.xls Page 1 of 4 6/6/2002-2:33 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim I TVD I VSec I Nf-S I EJ.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (01100ft) (ftUS) (ftUS) 1590.60 34.57 344.61 1530.75 305.56 294.63 -81.65 4.45 5970382.66 590455.16 N 70 1943.768 W 14915 58.934 1685.52 38.49 344.76 1607.01 362.01 349.12 -96.57 4.13 5970436.95 590439.58 N 70 1944.304 W 1491559.370 1776.16 41.53 345.81 1676.43 420.21 405.4 7 -111.35 3.44 5970493.12 590424.12 N 701944.858 W 1491559.801 1869.60 42.76 344.18 1745.71 482.85 466.03 -127.59 1.76 5970553.47 590407.15 N 70 19 45.454 W 149160.276 1962.86 43.69 342.51 1813.67 546.71 527.21 -145.91 1.58 5970614.42 590388.11 N 70 1946.055 W 149160.810 2056.54 44.55 342.27 1880.92 611.93 589.37 -165.64 0.94 5970676.33 590367.63 N 70 1946.667 W 149 16 1.386 2150.38 45.25 342.24 1947.39 678.16 652.46 -185.83 0.75 5970739.17 590346.68 N 70 1947.287 W 149161.976 2243.98 44.62 342.59 2013.65 744.27 715.48 -205.80 0.72 5970801.94 590325.95 N 70 1947.907 W 149162.559 2337.03 45.04 342.75 2079.64 809.87 778.10 -225.34 0.47 5970864.31 590305.66 N 70 19 48.523 W 14916 3.130 ~ 2430.06 46.38 342.75 2144.60 876.46 841.70 -245.09 1.44 5970927.66 590285.15 N 70 1949.148 W 149163.706 2524.50 45.88 342.24 2210.05 944.55 906.63 -265.57 0.66 5970992.33 590263.89 N 70 1949.787 W 149164.304 2617.69 45.18 342.53 2275.33 1011.05 970.01 -285.69 0.78 5971055.46 590243.00 N 70 1950.410 W 149164.892 2710.82 44.44 341.62 2341.40 1076.68 1032.46 -305.89 1.05 5971117.65 590222.06 N 701951.024 W 149165.481 2803.81 45.68 342.86 2407.09 1142.50 1095.14 -325.96 1.63 5971180.09 590201.23 N 70 1951.641 W 149166.068 2896.30 46.58 344.04 2471.18 1209.16 1159.05 -344.94 1.34 5971243.76 590181.48 N 70 19 52.269 W 149166.622 2989.49 47.86 343.92 2534.48 1277.54 1224.79 -363.82 1.38 5971309.26 590161.81 N 70 1952.916 W 149 167.173 3083.60 47.41 344.00 2597.89 1347.05 1291.62 -383.03 0.48 5971375.85 590141.79 N 70 19 53.573 W 149167.734 3176.39 48.49 342.50 2660.04 1415.95 1357.59 -402.90 1.67 5971441.57 590121.14 N 70 19 54.222 W 149168.314 3222.61 48.32 342.41 2690.73 1450.51 1390.55 -413.32 0.40 5971474.39 590110.32 N 70 19 54.546 W 149168.619 3348.85 46.98 342.92 2775.77 1543.81 1479.61 -441.12 1.10 5971563.10 590081.45 N 70 19 55.422 W 149169.431 3443.39 46.77 342.53 2840.39 1612.81 1545.50 -461.61 0.37 5971628.73 590060.17 N 70 1956.070 W 1491610.029 3536.45 49.34 346.19 2902.60 1681.96 1612.13 -480.22 4.02 5971695.13 590040.76 N 701956.725 W 1491610.572 3629.60 49.40 346.84 2963.26 1752.49 1680.88 -496.70 0.53 5971763.67 590023.45 N 701957.401 W 1491611.054 3722.75 49.48 346.79 3023.83 1823.06 1749.78 -512.85 0.10 5971832.36 590006.48 N 70 19 58.079 W1491611.525 3816.20 49.79 347.44 3084.35 1894.04 1819.19 -528.72 0.63 5971901.57 589989.76 N 701958.762 W 149 1611.989 ~ 3909.46 50.20 346.97 3144.31 1965.24 1888.85 -544.54 0.59 5971971.03 589973.10 N 701959.447 W 1491612.451 4003.29 50.18 344.65 3204.39 2037.20 1958.72 -562.21 1.90 5972040.67 589954.60 N 70200.134 W 1491612.967 4097.46 48.56 343.54 3265.71 2108.64 2027.45 -581.79 1.94 5972109.16 589934.20 N 70200.810 W 1491613.539 4191.37 49.28 345.12 3327.42 2179.39 2095.61 -600.90 1.48 5972177.07 589914.26 N70201.480 W1491614.097 4285.61 49.11 345.34 3389.00 2250.65 2164.58 -619.09 0.25 5972245.82 589895.25 N 70202.159 W 1491614.629 4379.65 49.17 346.23 3450.52 2321.66 2233.53 -636.55 0.72 5972314.54 589876.95 N 70202.837 W 1491615.139 4472.80 48.89 345.29 3511.60 2391.88 2301.70 -653.85 0.82 5972382.49 589858.84 N 70203.507 W 1491615.644 4564.73 49.40 345.77 3571.74 2461.32 2369.03 -671.22 0.68 5972449.60 589840.65 N70204.169 W1491616.152 4657.08 48.23 344.27 3632.55 2530.75 2436.16 -689.18 1.76 5972516.50 589821.89 N 70204.829 W 1491616.676 4750.80 47.46 342.79 3695.45 2600.22 2502.79 -708.87 1.43 5972582.88 589801.40 N 70205.485 W 1491617.251 V-102 ASP Final Survey.xls Page 2 of 4 6/6/2002-2:33 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim I TVD I VSec I Nf-S I EJ-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 4843.74 47.11 343.43 3758.50 2668.50 2568.13 -728.71 0.63 5972647.97 589780.77 N 70206.127 W 1491617.831 4937.55 46.75 342.34 3822.56 2737.03 2633.62 -748.88 0.93 5972713.21 589759.82 N 70206.771 W 1491618.420 5030.37 46.79 343.24 3886.13 2804.65 2698.22 -768.88 0.71 5972777.56 589739.03 N 70207.407 W 1491619.004 5124.73 46.79 343.45 3950.74 2873.42 2764.11 -788.60 0.16 5972843.20 589718.53 N 70208.055 W 1491619.580 5217.71 46.84 344.16 4014.37 2941.20 2829.22 -807.50 0.56 5972908.06 589698.84 N 70208.695 W 14916 20.133 5311.39 47.48 342.78 4078.07 3009.88 2895.06 -827.05 1.28 5972973.67 589678.50 N 70209.343 W 1491620.704 5404.43 47.46 342.69 4140.96 3078.45 2960.54 -847.40 0.07 5973038.88 589657.37 N 70 20 9.986 W 1491621.298 5496.55 47.62 341.99 4203.15 3146.40 3025.30 -868.02 0.59 5973103.38 589635.97 N702010.623 W1491621.901 5590.02 47.80 341.08 4266.05 3215.54 3090.88 -889.92 0.75 5973168.69 589613.28 N 70 20 11.268 W 149 1622.540 ~ 5683.47 47.73 340.73 4328.86 3284.70 3156.26 -912.55 0.29 5973233.79 589589.86 N 70 20 11.911 W 149 1623.202 5777.63 48.05 339.86 4392.00 3354.49 3222.02 -936.11 0.77 5973299.25 589565.52 N 70 20 12.558 W 149 16 23.890 5871.88 48.18 338.31 4454.93 3424.53 3287.56 -961 . 15 1.23 5973364.48 589539.69 N 70 20 13.203 W 149 16 24.622 5965.71 47.82 338.85 4517.71 3494.08 3352.47 -986.62 0.57 5973429.08 589513.44 N 70 2013.841 W 1491625.366 6060.21 46.80 338.82 4581.79 3563.40 3417.25 -1011.70 1.08 5973493.54 589487.58 N 70 20 14.478 W 1491626.098 6153.20 47.29 339.14 4645.15 3631.32 3480.78 -1036.11 0.58 5973556.76 589462.41 N702015.103 W1491626.811 6246.78 47.30 338.37 4708.62 3699.93 3544.87 -1061.03 0.60 5973620.54 589436.72 N 702015.733 W 1491627.540 6340.46 46.93 337.22 4772.37 3768.33 3608.42 -1086.97 0.98 5973683.77 589410.02 N 70 20 16.358 W 149 16 28.297 6433.06 47.25 336.39 4835.42 3835.81 3670.76 -1113.68 0.74 5973745.77 589382.56 N 70 20 16.971 W 149 16 29.078 6526.17 45.81 339.87 4899.49 3903.16 3733.44 -1138.87 3.12 5973808.14 589356.62 N 702017.587 W 1491629.814 6618.34 45.28 342.26 4964.04 3968.91 3795.66 -1160.22 1.94 5973870.09 589334.52 N 70 2018.199 W 1491630.438 6711.46 44.75 342.45 5029.87 4034.78 3858.42 -1180.18 0.59 5973932.60 589313.81 N 70 2018.817 W 149 1631.021 6802.94 44.58 341.80 5094.93 4099.08 3919.63 -1199.92 0.53 5973993.56 589293.33 N702019.418 W1491631.598 6896.10 44.51 340.46 5161.33 4164.41 3981.46 -1221.05 1.01 5974055.13 589271.46 N 70 20 20.027 W 149 16 32.215 6989.04 41.71 343.24 5229.18 4227.90 4041.78 -1240.87 3.64 5974115.20 589250.91 N 70 20 20.620 W 149 16 32.794 7083.04 39.10 344.23 5300.76 4288.81 4100.26 -1257.95 2.86 5974173.4 7 589233.13 N 702021.195 W 1491633.294 , '- 7176.84 36.41 345.61 5374.91 4346.18 4155.71 -1272.91 3.01 5974228.72 589217.51 N 70 20 21.740 W 1491633.731 7269.46 35.68 344.68 5449.80 4400.63 4208.38 -1286.88 0.99 5974281.22 589202.91 N 70 20 22.258 W 14916 34.139 7363.13 34.48 343.79 5526.45 4454.44 4260.19 -1301.50 1.39 5974332.84 589187.66 N 70 20 22.768 W 149 16 34.566 7457.62 33.79 343.64 5604.66 4507.45 4311.09 -1316.36 0.74 5974383.55 589172.18 N 70 20 23.268 W 1491635.001 7550.43 30.98 345.60 5683.03 4557.12 4359.00 -1329.58 3.23 5974431.29 589158.40 N 702023.739 W 1491635.387 7643.81 27.46 343.37 5764.52 4602.66 4402.92 -1341.72 3.95 5974475.06 589145.73 N 70 20 24.171 W 14916 35.742 7737.56 23.73 341 .16 5849.06 4643.15 4441.50 -1354.00 4.11 5974513.49 589132.98 N 70 20 24.551 W 14916 36.101 7830.77 19.23 339.87 5935.77 4677.25 4473.68 -1365.35 4.85 5974545.52 589121.25 N 70 20 24.867 W 149 16 36.433 7925.09 17.38 337.14 6025.32 4706.79 4501.25 -1376.17 2.16 5974572.95 589110.10 N 70 20 25.138 W 1491636.749 8016.96 14.84 335.35 6113.57 4732.12 4524.59 -1386.40 2.82 5974596.17 589099.58 N 70 20 25.368 W 1491637.048 V-1 02 ASP Final Survey.xls Page 3 of4 6/6/2002-2:33 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim I TVD VSec Nt-S EJ-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 8110.75 12.94 334.15 6204.62 4754.43 4544.95 -1395.99 2.05 5974616.42 589089.75 N 70 20 25.568 W 149 16 37.328 8204.30 11.24 332.96 6296.09 4773.78 4562.50 -1404.71 1.84 5974633.86 589080.82 N 702025.741 W 1491637.583 8297.65 10.11 331.71 6387.82 4790.80 4577.82 -1412.73 1.24 5974649.08 589072.62 N 702025.891 W 1491637.817 8391.91 9.13 331.30 6480.76 4806.26 4591.67 -1420.24 1.04 5974662.83 589064.94 N 70 20 26.028 W 149 16 38.037 8485.48 8.56 330.31 6573.21 4820.34 4604.23 -1427.25 0.63 5974675.30 589057.78 N 702026.151 W 149 1638.242 8577.51 8.66 328.62 6664.20 4833.76 4616.09 -1434.25 0.30 5974687.08 589050.64 N 70 20 26.268 W 149 16 38.446 8670.73 8.33 327.64 6756.40 4847.09 4627.79 -1441.52 0.39 5974698.69 589043.23 N 70 20 26.383 W 149 16 38.658 8764.86 7.59 327.51 6849.62 4859.68 4638.79 -1448.51 0.79 5974709.61 589036.11 N 70 20 26.491 W 149 16 38.863 8858.08 7.48 328.34 6942.04 4871.51 4649.15 -1455.00 0.17 5974719.88 589029.49 N 70 20 26.593 W 149 16 39.052 ~ 8905.63 7.35 328.20 6989.19 4877.46 4654.37 -1458.23 0.28 5974725.06 589026.20 N 702026.644 W 1491639.147 8960.00 7.19 328.02 7043.12 4884.12 4660.21 -1461.86 0.30 5974730.86 589022.50 N 70 20 26.702 W 149 16 39.253 -" V-1 02 ASP Final Survey.xls Page 4 of 4 6/6/2002-2:33 PM ) ) MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-102 Date Dispatched: 31-May-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys ~oa-ò3 ~ 2 Received By: ~ ~~r....J 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 JUN 1 2 2002 AlaskA Oi' & G3s Cons. f'.IVft_"-L M~ VVllu'~n ALASKA 0 STATE OF ALASKA )ND GAS CONSERVATION COMMIE PERMIT TO DRILL 20 AAC 25.005 pN \¡J flit: Lit'll tJì L frb~ 15--Ð?-, Lenath 80' 3189' 8200' 746' 0 Exploratory 0 9tratigraphic Test II Development Oil 0 Service 0 Development Gas EJ'Single Zone;1> 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 77' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number V-102 9. Approximate spud date 03/15/02 ,/ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8946' MD 16966' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 48 Maximum surface 2683 psig, At total depth (TVD) 6390' I 3322 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 3189' 2682' Surface Surface 8200' 6248' 8200' 6248' 8946' 6967' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 48411 NSL, 1760' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 4269' NSL, 31291 WEL, SEC. 02, T11 N, R11 E, UM At total depth 4397' NSL, 3166' WEL, SEC. 02, T11N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028238, 8821 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casing Weiaht Grade CouDlina 20" 91.5# H-40 Weld 7-5/8" 29.7# L-80 BTC 5-1/2" 15.5# L-80 BTC-M 3-1/2" 9.2# L-80 IBT-M 1 b. Type of well Number 2S100302630-277 Hole 42" 9-7/8" 6-3/4" 6-3/4" Quantitv of Cement (include stage data) 260 sx Arctic Set (Approx.) 370 sx Articset Lite, 197 sx 'G' 142 sx LiteCrete, 182 sx Class 'G' (5-1/2" x 3-112" Cementing Program) 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 /~JaS'f;a (in ;:;. í.::':~~? !;cns. Perforation depth: measured true vertical 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify Ihal the fOregoipJ, i ,. is true a~d correct to, the best of my knOWled,ge Signed Lowen Crane ()29-~ ;l~eo.n::o~::::g Engineer Dale ì -2'{ - ~d- Permit ~um~er /"'1"'-:) API Num~¡ Z..-;J 070"" ,-Q/'->o !J1,A pr?val Date See cover lett.er 2ó 7 -- ó..::'.) _5 50- D ~ ,- ~ ' L.J ..,~' ~;' [) ).. for other requirements Conditions of Approval: Samples Required 0 Yes BI No Mud Log Required 0 Yes ŒJ No Hydrogen Sulfide Measures 0 Yes Bl No Directional Survey Required {gJ Yes 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: 'Tec;+ e~ PE -fo ~£:Ð f£(. \dølJf'l'1 . . .. by order of Approved By Onglnal Signed By Commissioner the commission Form 10-401 Rev. 12-01-85 t;ammy qe~h~, ¡ (--: f '. . , : \", ' i -, ,(I'" - Date ~,' I) '{ . ;, Subfuit In Triplicate ) ) IWell Name: IV-102 Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: I AFE Number: 15M4016 x = 590,540.35' Y = 5,970,089.06' 4841' FSL (43T FNL), 17601 FEL (3519' FWL), Sec. 11, T11 N, R11 E X = 589,110.00' Y = 5,974,779.99' 4269' FSL (1009' FNL), 31291 FEL (2149' FWL), Sec. 02, T11 N, R11 E X = 589,071.31' Y = 5,974,906.82' 4397' FSL (882' FNL), 3166' FEL (2112' FWL), Sec. 02, T11N, R11E I Rig: I Nabors 9ES ./ 1 Estimated Start Date: 13/15/2002 1 1 MD: 18,946' I I TVD: 16966' I I Operatina days to complete: 117.2 .... 1 BF/MS: 148.8' I I RKB: 177.0' I Well Desian (conventional, slimhole, etc.): 1 Microbore (Iongstring) // 1 Objective: I Kuparuk Formation /1 Mud Program: 9-7/8" Surface Hole (0-3189'): Densitv Viscosity (ppg) (seconds) 8.5 - 8.6 300 9.3 - 9.5 ./., 200- 250 9.6 max / 200 - 250 Initial below Permafrost interval TD Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100fe) (mls/30min) 50 - 70 15 - 20 30 - 45 15 - 20 30 - 45 15 - 20 8.5- 9.5 8.5 -9.5 8.5 - 9.5 63A" Intermediate 1 Production Hole (3189' - 8946'): Interval Density Tau 0 YP PV (ppg) 9.3-9.5 Upper Interval Top of HRZ 10.3 V -102 Drilling Program 4-7 20-25 4-6 20-25 pH 8.5-9.5 Fresh Water LSND API HTHP Fi Itrate Fi Itrate 4-6 8-12 8-14 8.5-9.5 3-5 <10 by HRZ Page 1 ) ) Hydraulics: Surface Hole: 9 7/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1875' 550 4" 17.5# 130 1600 10.2 N/A 18,18,18,12 .856 1 ,875' -3,189' 600 4" 17.5# 150 2600 10.4 N/A 18,18,18,12 .856 Production Hole: 6 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3,189' -7500' 285 4" 17.5# 210 1700 - 1900 10.0 N/A 14,15,15 .495 7,500'-8,946' 275 4" 17.5# 200 2200 - 2600 11.1 N/A 5x12 .552 Directional: Ver. Anadrill P2 Slot NL KOP: 300' Maximum Hole AnÇlle: Close Approach Wells: Survey Program: Logging Program: Surface Production Hole Formation Markers: Formation Tops MDbkb SV6 SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (N sands) WS1 (0 sands) Obf Base CM2 (Colville) THRZ V-102 Drilling Program 48Dat 2175' MD /' " All 'wells pass major risk criteria. ./ Standard MWD surveys (IFR+MSA Correction) Drilling: MWD / GR Open Hole: PEX/Dipole Sonic, Gas Detection Cased Hole: None Drilling: MWD / GR / Res Open Hole: PEX/Sonic, CMR/MDT, Gas Detection, Cuttings samples Cased Hole: US IT cement evaluation (contingency) TVDss 880' 1535' 1665' 1700' 2050' 2220' 2545' 2850' 3090' 3570' 3870' 4125' 4290' 4670' 4990' 6090' ~S{ç.;~ ;;~~~ ~~ Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing, 2000 psi, 8.9 ppg EMW../ ./ Page 2 ) ) BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TMLV (Miluveach) TD Criteria 6290' 6340' 6390' 6395' 6535' 6665' 6740' Hydrocarbon Bearing, 10.0 ppg EMW Hydrocarbon Bearing, 10.0 ppg EMW Hydrocarbon Bearing, 10.0 ppg EMW 150' below Miluveach top Note: Kuparuk reservoir pressure may be drawn by approximately 100-200 psi based on ongoing production on L-Pad. CasinglTubing Program: Hole Csgl Wt/Ft Grade Conn Length Top Btm Size TbQ O.D. MDITVD MDITVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110/11 0 9-7/8" 7 5/8" 29.7# L-80 BTC 3189' GL 3189'/2682' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 8200' GL 8200'/6248' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 746' 8200'/6248' 8946/6967' Tubing 3-1 /2" 9.2# L-80 IBT-mod 8200' GL 8200' /6248' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW/" 13.2 ppg (minimum for a 25bbl kick tolerance) Cement Calculations: The following surface cement calculations are based upon a single stage job The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader with 1000 psi compressive strength and covering the entire Kuparuk interval with 2000 psi compressive strength cement. If logs indicate the Schrader not to be oil bearing, the program will be amended to provide 2000 psi compressive strength cement above the top of the Kuparuk only. Casing Size 17-5/8" Surface I Basis: Lead: Based on 1875' of annulus in the permafrost @ 250% excess and 564' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ;r Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2439' MD (2180' TVDbkb) ./ Total Cement Volume: Lead 292 bbl I 1638fe I )70 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/s,k. Tail 41 bbl I 230 tt) 197 sks of Dowell Premium 'G' at 15.8 ppg and 1 .17 cf/sk. V-102 Drilling Program Page 3 ) ) Casing Size 5-1/2"x3-1/2" Production Longstring Basis: Lead: Based on TOe 500' above the top of the Schrader Bluft,form2:tion + 300/0 excess and Base of cement 500' above top of Kuparuk formation at t928' (5732' TVDbkb). Tail: Based on TOe 590' ab~ve top of KURaruk formation + 30% excess + 80' shoe track volume. 'TO c. 45 81 J 14 ò . v.t!fÆ / Total Cement Volume: Lead 65 bbl I 3ß5fe I 142sks of Dowell LiteCrete at 11.5 ppg and 2.56 cf/sk. ./ Tail 38 bbl I 213 fe I 182 sks of Dowell ~mium 'G' (KUP Latex Design) at 15.8 ppg and 1.17 cf/sk. V -102 Drilling Program 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 Jest for future frac job considerations, the BOP equipment will be tested to 4500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: / . Planned BOP test pressure: . Planned completion fluid: /10.0 ppg EMW (3322 psi) @ 6390' TVDss - TKUP 2683 psi @ surface (based on 3322 psi at TKUP and a full column of gas @ 0.10 psi/ft) /' 4500 psi (for future frac stimulation treatments) 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. H2S: . H2S has not been recorded on V-Pad wells. As a precaution Standard Operating Procedures for H2S should be followed at all times. V-102 Drilling Program Page 5 ') "), DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed November 2001. 1. If necessary, level the pad and prepare location for rig move. 2. Ensure any required plugs and I or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES on Slot NL. /'; 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. ./1 /"". 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3189' MD I 2682' TVD. An intermediate Ibit trip to surface will be performed prior to exiting the Permafrost. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. 4. POH. Rig up Schlumberger",and run PEX/Dipole Sonic on e-line. Rig down Schlumberger. , 5. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar may be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. /" 6. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4500 psi. /,,, 7. MU 6-3/4" drilling assembly with MWD/GR/RES and RIH to float collar. Test the 7-5/8" casing to 3500 psi for 30 minutes. 8. Drill out shoe joints and displace well to 9.3 ppg LSND drilling fluid. Drill new formation to 20' below 7- 5/8" shoe and perform Leak Off Test. /' , ./ 9. Drill to :t100' above the HRZ, ensure mud is condition to 10.3 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. Drill ahead to -150' of rat hole into the Miluveach formation. 10. Perform open hole logging program. PEX/Sonic (e-line conveyed) and CMR/MDT (pipe conveyed) 11. Condition hol~for running longstring and POOH. 12. Run and cement the tapered production casing as required from TD to 500' above the Schrader. Displace the casing with seawater during cementing operations and freeze protect the 5 %" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test belo~he 7 5/8" shoe. Record on chart and submit to town.) 13. Test the casing to 4500 psi for 30 min. 14. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly.....Girculate around corrosion inhibitor. Sting seal assembly into tieback receptacle and test to 4500 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 15. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 16. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to reach the lower GLM. 17. Rig down and move off. V-102 Drilling Program Page 6 ') ) I Job 1: MIRU Hazards and Contingencies / >- V-Pad is not designated as an H2S site. As a precaution however Standard Operating Procedures for H2S precautions should be followed at ~times. ~ The closest surface location will be V-201. V-102 will be -15' wellhead to wellhead. The well is not perforated and will not require a surface shut-in. ~ Check landing ring height on V-102, the BOP/Diverter nipple up may need review. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~:............W,"""'Y.:'.m",-,,"';H:~¥,","'''''''W'''''''''''''nn,'m_.J_.'.,-~:::.'t..~... :~:W:"'X-''''-~:::'~i'''i";~;h:~~:«'W_''''''''-'''''','--~'.,,..iælI««-''''''JN'''''''......,--,......_,u'--,.,,«*,,.*:'-'':~~''''~'''',.''''WN.J'''_~ '''~''''''';';'Jo!.............,...-.J..¡.,.,.....,''t Job 2: DrillinQ Surface Hole Hazards and Contingencies >- No faults are expected to be penetrated by V-102 in the surface interval. >- Drilling Close Approach: All wells pass BP Close Approach Guidelines. The nearest close approach well is V-201 which will have a center-center distance of approximately 15' from surface to 500' MD. All well pass under Major Risk Rules. >- A limited amount of gas hydrates have been observed on the surface holes drilled on V-Pad from 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 >- Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. "Successfully Drilling Surface Hole. See Attached document .:. Follow Schlumberger logging practices and recommendations. .~~"".,~;!,I;:,:¡,-m¡,I,:!~¡J.m¡.;¡,~ ~~,'¡JJ~.;,--,'I/:o~,I¡,'~J,:,~,~~,:,-,~;¡~.~»m-~~;',:;J¡.¡;.,-JÆ-¡¡¡';'¡!;'~ Job 3: Install surface CasinQ Hazards and Contingencies >- It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. If hole conditions indicate that cement to surface may be an issue, a 7-5/8" port collar will be positioned at :t1 OOO'MO to allow a secondary circulation. >- "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVO above shoe, (using 30% excess.) 3. Casing - Shoe set -100' TVO below SV1 sand. V-102 Drilling Program Page 7 ) ) Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Dowell Cement Program" .:. "Surface Casing Port Collar Procedure" ~m~~:.~'~ ", ,I.','~ Job 7: DrillinQ Production Hole Hazards and Contingencies ...'" » KICK TOLERANCE: The reservoir pressure of the Kuparuk has been determined to be 10.00 ppg. In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.2 ppg at the surface casing shoe, 10.4 ppg mud in the hole the kick tolerance is 25 bbls~ (LOT of 14.9ppg was recorded in offset well V-201) An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.7 ppg. >- A fault is expected to be penetrated by V-102 at the base of the UgnufTop Schrader @ -2850' TVDss. The throw is estimated @ -100' and is not considered a high risk for loss circulation. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. Consult Lost Circulation Decision Tree for recommended LCM treatments. >- V-Pad development wells may 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 are no "Close Approach" issues with the production hole interval of V-1 02. >- The expected maximum pore pressure in the Kuparuk reservoir is 3464 psi (10.0 ppg EMW). Ongoing L-Pad production may have depleted that reservoir some 100-200 psi resulting in a 9.5ppg EMW. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" ..... . .-_-0 -.................. .........,.... ..,. -...- . - -'-"'-----".'''".'--....-.-................. "1'""" " ,-r', ",,,\~"m"'l~t- ....,.. .:--' ., ... .,-''''-,.._''"~-,,.,... ,',P',"',-. --'1'-1'- ,..1 'ro.. .n_~._'I--'-"- . ,...n;lp"'_"'T"', HI. !I .'d .- '-""'- Job 8: LOQ Production Hole Hazards and Contingencies » Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. » If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 Y2" x 3 Y2" longstring casing. V-102 Drilling Program Page 8 ) ') Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" """..";;~¡,IJ;J¡';;;;~;mffl;;¡>;;;,;;;,:;;;~,,,,"""';,o1i'I:'A""m»~>""'I'I¡'m¡;;";';~;¡"h,mx.'))y);",,.;~~m¡m¡~,,,,~~!~~~"m;~»),)')_~'h,'~;m")"",,_)",»))~m,¡;l)m;;,~J}; Job 9: Case & Cement Production Hole Hazards and Contingencies > The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand or 500' above the top of the Schrader depending on log evaluation. ~ A TAM port collar may be utilized in the 5-1/2" longstring to allow for a two stage cement job. It will be positioned above the Kuparuk taking into consideration any potential loss zone above This will depend on mud losses while drilling, hole conditions and the cement coverage required. > If losses are encountered while running the production casing, be prepared to treat with Barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. ,/ ,/., > After freeze protecting the 5 Y2" x 7-518" casing annulus to 2200' with 36 bbls of dead crude, the hydrostatic pressure will be assuming a diesel column to 2127' TVD, with 1000' of 15.8 ppg cement above the top of Kuparuk at 5732' TVD and 10.3 ppg mud to 2127' TVD, the hydrostatic pressure will be equivalent to 10.0 ppg or 3437 psi. This is roughly the same as the reservoir pressure of 3322 psi at the top of Kuparuk. (If cement is brought up to provide coverage of the Schrader Bluff formation the underbalance concern will be negated.) It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. (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. Loss of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. > The well will be under-balanced after displacing the cement with heated sea-water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. ~ The X- Nipples, with 1.0. of 2.813" is the tightest tolerance for the Weatherford Oual- Plug system, (tapered cement plugs to be used in the 5 Y2" X 3 Y2" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been milled down to an O.D. of 2.5". Caliper to confirm, prior to use. Note: Based on ongoing studies relating to wiper plug failures, we may elect to drop the top and bottom plug together prior to displacement of cement. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Dowell Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" V-102 Drilling Program Page 9 ') ') Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" ~~"",-"-,.,~.,,,_._,'~~,~,~~,~~,~~~~"!""'¡""i~r:"~f~;:¡:::;;:,:::,~~~~"''f~~'Y~'''''''''''''''~N~...:~,-~::, ¡:,;~,¡'::,'~,~"~~Y~ ,':;;~,::~liI1::I¡::~I,:tl,:C¡,-,,~'~ 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 .:. Standard practices apply. .:. Freeze Protection of Inner Annulus. l'II::--'-:~:':::::':::m:.'¡:'''''::::~*»::::+ml:ll:ml:I':,,111:111111.,1. _1',-:I'_II\:III_II',I:_:I:~_I!I::1!I!:II'II':I"""'<-"""''''~.""'-v/.~'.I.',.~m:+....h';¡:~(#I"::::' ":.':""'''.'''''''\N.''''''.~'''\o'''''''''''.''~I\o'':''''I':I'::I.':I-1.1 """-""""".""'''''1''''\0''1:,',11111. .11. _nl"III,:'IIIII'III::II_..::- V-102 Drilling Program Page 1 0 )1 ') V-102 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in all offset wells. These are expected to be encountered near the base of the Permafrost at 1890' and near the TD 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 and yield point is maintained to avoid stuck pipe situations. Production Hole Section: . The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure adequate mud weight in the Kuparuk formation. . 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. . FAULTS: The well trajectory is expected to intersect a fault while drilling V-1 02,in the base of the Ugnu/Top Schrader @ ....2850' TVDss. The throw is estimated @ ....100' and is not considered a high risk for loss circulation. Consult Lost Circulation Decision Tree for recommended LCM treatments. . KICK TOLERANCE: With 10.0 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.2 ppg at the surface casing shoe, 10.4 ppg mud in the hole, the kick tolerance is 25 bbls. (The V-201 offset well had a fracture gradient of 14.9 ppg at the SV-1 surface shoe depth.) . V-Pad development "Microbores" are expected to have "kick tolerances" in the 25-50 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. . The expected maximum pore pressure in the Kuparuk reservoir is 3464 psi (10.0 ppg EMW). Ongoing L-Pad production may have depleted that reservoir some 100-200 psi resulting in a 9.5ppg EMW. HYDROGEN SULFIDE - H2S /' This drill-site not designated as an H2S drill site. RFT test data from V-100 does not indicate H2S is present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 ) ) Borealis V-102 Proposed Completion TREE: 3-1/8" - 5M CIW L-80 WELLHEAD: 11" - 5M FMC G5 J'" 7-5/8",29.7 #/ft, L-80, BTC I 3189' ,/ 5-1/2",15.5 lIft, L-80, BTC-Mod Plug Back Depth I 8,865' 3-1/2",9.2 #/ft, L-80,IBT Mod I 8946' Date 1/9/02 Rev By NM IJI Cellar Elevation = 47' RKB - MSL = 77' I I- 3-1/2" SSSVLN with 2.813" bore. I 2200' I ~ 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. L # 1 2 3 GAS LIFT MANDRELS TVD Type Valve Type RP DV DV TBD 5300' 3500' KBG-2-9 KBG-2-9 KBG-2-9 L -,------.---.,...--- ---_.__.__._.~-_..,,-_._.__. ------,.----------.----.- . ~ 3-1/2" 9.2# IBT Mod L-80, Tubing L 0 3-1/2" Baker 'CMD" 20' above PBR "'. ~ 3-1/2" Seal Stack Assembly 4-: 3-1/2" seal bore in 17' PBR 7' , 5-1/2" x 3-1/2" XO ./ ~ ., 3-1/2" 'X' Landing Nipple with 2.813" seal bore . 3-1/2" 'X' Landing Nipple with 2.813" seal bore +/- 150' above Kuparuk I / I Comments Borealis WELL: V-102 API NO: 50-029-????? Proposed Completion BP Alaska Drilling & Wells Vertical Section Departure at 343.73 deg from (0.0, 0.0). (1 in = 1000 feet) TO / 5-1/r C.g pt 6 8946 MO 6967 TVO . , 5.00' 343.73' az 5037 departure I 5000 End Drp / Tgt 8434 MO 6472 TVO 15.00' 343.73' az 4905 departure ..... '-,''''. .-.---- Drp 2/100 i 6781 MO .5083.:¡jvO 48.06' 343.73' ~z 4052 departure . ", i ! .....t.... ; ....¡.... Schlumberuer End Bid 1844 MO 1757 TVO / 37.~2' 343.73' az 407 departure / I / I / !.......Bld4l1001907MO 1807TVID /~:~.~:~;~>-.:r"~7.3.~~ ~3.73~ a~:"445:·~ep~trå"" End Bid 2175 MO 2004 ryo 48.06' 343.73' az 627 deþarture ................... ......................!..... . ~~t:'~c;g:e~;·~Vo·..· 48)·06··..343·.73··az . . 13~ 1 departure 4000 3000 ....i i i ..1"......... ..¡. ..... ..... ... ..... ..... ....I ' , , / tOld Angle 48,06°1 .¿' ! ' :·:o:!', rJ.i:) ;?:~;)':~ 'T\/O ... i ... ~"v1.' 2:iiïr ~,1ï5 iï32 TVD'" ...\ .................................. ....1........·.. ................................................. ..~.."."... ......................... i .... ..... ....i :,nrvo I i I 2000 I 1000 I o 7000 - r.:.¡: i·iF·~'<: ~ -: :~~ :-'-10 $1 f~:: :\"0 6000 5000 ........ +-- Q)- Q)...J ~Cf) g~ 0 Q) T"" > II 0 ..0 £: co T""¢:: _0 ..c:~ +--N a.CX) Q) ......... om Cõ~ l)'¡": .- Q) ~a:: > > Q)Æ :JW l.- I- '(~~ir .~.,!~'8~' MïS' ,1.¡:~Š'2 '!\ib "'w~~r ~rnë r~1{) .1:·~'·1:.? '¡:vt) .. 4000 2000 -.... Bid 2/100 60P MO 600 TVO 3.00' 343.7~· az 8 departure Bid 31100 eço MO 8e8 TVO ............ .. ................~:~~.:....~.~~:r..~~...~.~.~~~~.~~:.~.... .................. .....i...... ------ KOP Bid 1/100300 MO 300 TVO .--:::::---::-- - --- 0.00' 343'T3' az 0 departure ............,.,.......~"......... o Structure: V-Pad Section At: 343.73 deg Date: January 09, 2002 V-102 (P2) Prudhoe Bay Unit - WOA Well: Field: VERTICAL SECTION VIEW Client: BP Exploration Alaska ) I 1000 I o EAST »> I -1000 I -2000 «< WEST I -3000 -1 000 -1000 '-. '-.'-.. KOP Bid 11100 . 300 MO 300 TvO 0.00' 343.73' az ON OE Bid 2/100 GOO MD 600 TVO 3.00' . 343.73" az 8N 2W Bid 3/100 / 900 MO 898 TVO 9.00' 343.73" az 38N 11W End Bid 1844 MO 1757 TVO .....3.l,;¡2.~....34.3.7.3.~..az...... . 390N 114W 0-· .. ·..·.......··..····..···..·-0 i ___ Bid 41100 : ./ 1907 MO 1807 TVO 37.32' 343. 7~' az 427 N 125 wi End Bid / ~.E~.MD....~º.º4..:ND... ................ ..................... - 1 000 / 48.06" 343. 73" a~ , 601N 176W . "...,..,.."."........,....................... ....,.........."...¡..... "."". 1 000 _... I I- :J o Cf) V V V 7-5/8" C.g Pt ...- 3189 MO 2682 TVO 48.06" 343.73' az 1326 N 387 W -, 2000 _. .~ 2000 - 3000 :s:. 9- 0- 3000 - ......... ............................... ..................................................................~:... . % s (jJ ~ "-l (jJo ^ ^ ^ I I- a:: o z . - 4000 Drp 2/100 678rMO'''5083'T1iO'' 48.06' 343.73' a~ 3890N 1135W ! \ ;. End Drp/Tgt <\ J./.. ...--....... .........,¡....-.! .... 8434 MO 6472 TVO \ - I. 15.00' 343.73' az I .' 4708 N 1374 W i i .\.....................Im..._~: ..~.-+--.- I I ! i i 4000 -- - 5000 5000 - ........- 6000 1000 , ·..···......·....··.....·.............1....· True North Mag Dec ( E 26.10° TD / 5-1/2" Csg pt 8946 MD 6967 TVD 15.00' 343.73" az 4836 N 1411 W ..... ...........................................". 6000 _................. . o , -1000 , -2000 , -3000 1 in = 1000 ft 09-Jan-2002 Scale: Date: ·..t .,. Schlumbørgør PLAN VIEW Client: BP Exploration Alaska Well: V-102 (P2) Field: Prudhoe Bay Unit - WOA Structure: V-Pad ") bp ~tÀ{ "'~"t bp V-102 Schlumbøpuøp Proposed Well Profile - Geodetic Report Report Date: January 9, 2002 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 343.730° Field: Prudhoe Bay Unit - WOA (Drill Pads) stlddY Vertical Section Origin: N 0.000 ft, E 0.000 fI Structure I Slot: V-Pad/V-102 feasibility TVD Reference Datum: KB Well: V-102 TVD Reference Elevation: 82.1 ft relative to MSL Borehole: V-102 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWI/API#: 50029 Magnetic Declination: 26.101° Survey Name I Date: V-102 (P2) 1 January 9, 2002 Total Field Strength: 57473.344 nT Tort I AHD I DDII ERD ratio: 81.111° 15037.22 ft/5.720 10.72~ Magnetic Dip: 80.754° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: March 15, 2002 .~ Location LatlLong: N 70.32801954, W 149.26570849 Magnetic Declination Model: BGGM 2001 Location Grid N/E Y/X: N 5970089.060 ftUS, E 590540.350 ftUS North Reference: True North Grid Convergence Angle: -+0.69143910° Total Corr Mag North -> True North: +26.101° Grid Scale Factor: 0.99990931 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates 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) 0.00 0.00 343.73 0.00 0.00 0.00 0.00 0.00 5970089.06 590540.35 N 70.32801954 W 149.26570849 300.00 0.00 343.73 300.00 0.00 0.00 0.00 0.00 5970089.06 590540.35 N 70.32801954 W 149.26570849 322. 10 0.22 343.73 322.10 0.04 0.04 -0.01 1.00 5970089.10 590540.34 N 70.32801965 W 149.26570857 400.00 1.00 343.73 399.99 0.87 0.84 -0.24 1.00 5970089.90 590540.10 N 70.32802184 W 149.26571043 500.00 2.00 343.73 499.96 3.49 3.35 -0.98 1.00 5970092.40 590539.33 N 70.32802869 W 149.26571643 600.00 3.00 343.73 599.86 7.85 7.54 -2.20 1.00 5970096.57 590538.06 N 70.32804014 W 149.26572633 700.00 5.00 343.73 699.61 14.83 14.23 -4.15 2.00 5970103.24 590536.03 N 70.32805842 W 149.26574214 800.00 7.00 343.73 799.06 25.28 24.27 -7.08 2.00 5970113.24 590532.98 N 70.32808585 W 149.26576590 900.00 9.00 343.73 898.08 39.20 37.63 -10.98 2.00 5970126.55 590528.92 N 70.32812234 W 149.26579753 965.00 10.95 343.73 962.10 50.46 48.43 -14.14 3.00 5970137.31 590525.63 N 70.32815185 W 149.26582315 -' 1000.00 12.00 343.73 996.40 57.42 55.12 -16.09 3.00 5970143.98 590523.60 N 70.32817013 W 149.26583896 1100.00 15.00 343.73 1093.62 80.76 77.53 -22.63 3.00 5970166.30 590516.79 N 70.32823135 W 149.26589200 1200.00 18.00 343.73 1189.49 109.16 104.79 -30.58 3.00 5970193.46 590508.51 N 70.32830582 W 149.26595647 1300.00 21.00 343.73 1283.75 142.53 136.83 -39.93 3.00 5970225.39 590498.78 N 70.32839335 W 149.26603229 1400.00 24.00 343.73 1376.13 180.80 173.56 -50.65 3.00 5970261.98 590487.61 N 70.32849369 W 149.26611922 1500.00 27.00 343.73 1466.37 223.85 214.88 -62.71 3.00 5970303.15 590475.06 N 70.32860658 W 149.26621702 1600.00 30.00 343.73 1554.25 271.56 260.68 -76.08 3.00 5970348.78 590461.14 N 70.32873170 W 149.26632545 1673.41 32.20 343.73 1617.10 309.47 297.08 -86.70 3.00 5970385.04 590450.08 N 70.32883114 W 149.26641157 I KBE KOP Bid 1/100 Base Gubik Bid 2/100 Bid 3/100 SV6 SV5 Station ID Page 1 of 3 1/9/2002-3:24 PM V-102 (P2) report. xis Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ.S EJ-W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftU5) (ftU5) 1700.00 33.00 343.73 1639.50 323.80 310.83 -90.72 3.00 5970398.74 590445.89 N 70.32886870 W 149.26644418 1800.00 36.00 343.73 1721.90 380.43 365.20 -106.58 3.00 5970452.91 590429.38 N 70.32901724 W 149.26657280 SV4 1831.33 36.94 343.73 1747.10 399.06 383.08 -111.80 3.00 5970470.73 590423.95 N 70.32906608 W 149.26661513 End Bid 1843.88 37.32 343.73 1757.10 406.63 390.34 -113.92 3.00 5970477.96 590421.74 N 70.32908592 W 149.26663232 Base Permafrost 1875.31 37.32 343.73 1782.10 425.69 408.64 -119.26 0.00 5970496.19 590416.18 N 70.32913591 W 149.26667563 Bid 4/100 1906.75 37.32 343.73 1807.10 444.74 426.93 -124.60 0.00 5970514.42 590410.62 N 70.32918588 W 149.26671894 2000.00 41.05 343.73 1879.37 503.65 483.48 -141.10 4.00 5970570.76 590393.44 N 70.32934036 W 149.26685276 2100.00 45.05 343.73 1952.44 571.89 548.99 -160.22 ~.OO 5970636.03 590373.53 N 70.32951933 W 149.26700782 End Bid 2175.23 48.06 343.73 2004.17 626.50 601.41 -175.52 4.00 5970688.25 590357.60 N 70.32966254 W 149.26713191 SV3 2366.63 48.06 343.73 2132.10 768.86 738.08 -215.39 0.00 5970824.42 590316.09 N 70.33003591 W 149.26745528 SV2 2620.96 48.06 343.73 2302.10 958.03 919.68 -268.37 0.00 5971005.35 590260.93 N 70.33053202 W 149.26788499 --- SV1 3107.19 48.06 343.73 2627.10 1319.69 1266.86 -369.67 0.00 5971351.25 590155.45 N 70.33148047 W 149.26870668 ~ -5/8" Csg Pt 3189.48 48.06 343.73 2682.10 1380.89 1325.61 -386.81 0.00 5971409.78 590137.61 N 70.33164097 W 149.26884572 UG4A 3563.50 48.06 343.73 2932.10 1659.09 1592.67 -464.73 0.00 5971675.86 590056.48 N 70.33237054 W 149.26947783 UG3 ¡'or:- 3922.56 48.06 343.73 3172.10 1926.16 1849.05 -539.53 0.00 5971931.29 589978.60 N 70.33307094 W 149.27008467 UG1 4640.68 48.06 343.73 ~2.10 2460.29 2361.81 -689.13 0.00 5972442.16 589822.84 N 70.33447172 W 149.27129847 Ma 5089.51 48.06 343.73 3952.10 2794.13 2682.28 -782.63 0.00 5972761.45 589725.48 N 70.33534719 W 149.27205718 WS2 5471.01 48.06 343.73 4207.10 3077.89 2954.68 -862.11 0.00 5973032.85 589642.73 N 70.33609134 W 149.27270217 WS1 5717.87 48.06 343.73 4372.10 3261.50 3130.94 -913.54 0.00 5973208.46 589589.18 N 70.33657285 W 149.27311956 CM3 5987.17 48.06 343.73 4552.10 3461.80 3323.23 -969.64 0.00 5973400.04 589530.77 N 70.33709815 W 149.27357487 Obf Base 6286.38 48.06 343.73 4752.10 3684.35 3536.88 -1031.97 0.00 5973612.90 589465.87 N 70.33768180 W 149.27408078 CM2 6765.13 48.06 343.73 5072.10 4040.44 3878.72 -1131.71 0.00 5973953.48 589362.02 N 70.33861564 W 149.27489038 Drp 2/100 6781.06 48.06 343.73 5082.75 4052.29 3890.09 -1135.02 0.00 5973964.81 589358.58 N 70.33864670 W 149.27491724 6800.00 47.68 343.73 5095.45 4066.34 3903.57 -1138.96 2.00 5973978.24 589354.48 N 70.33868352 W 149.27494923 6900.00 45.68 343.73 5164.06 4139.08 3973.41 -1159.33 2.00 5974047.82 589333.27 N 70.33887431 W 149.27511458 7000.00 43.68 343.73 5235.16 4209.39 4040.90 -1179.03 2.00 5974115.06 589312.76 N 70.33905868 W 149.27527450 7100.00 41.68 343.73 5308.68 4277.17 4105.97 -1198.01 2.00 5974179.89 589292.99 N 70.33923644 W 149.27542858 -- 7200.00 39.68 343.73 5384.52 4342.35 4168.54 -1216.27 2.00 5974242.23 589273.98 N 70.33940736 W 149.27557682 7300.00 37.68 343.73 5462.58 4404.84 4228.52 -1233.77 2.00 5974301.99 589255.76 N 70.33957122 W 149.27571888 7400.00 35.68 343.73 5542.78 4464.57 4285.86 -1250.50 2.00 5974359.12 589238.34 N 70.33972786 W 149.27585470 7500.00 33.68 343.73 5625.01 4521.46 4340.48 -1266.43 2.00 5974413.54 589221.76 N 70.33987707 W 149.27598403 7600.00 31.68 343.73 5709.18 4575.44 4392.30 -1281.56 2.00 5974465.17 589206.00 N 70.34001863 W 149.27610686 7700.00 29.68 343.73 5795.18 4626.46 4441.28 -1295.85 2.00 5974513.97 589191.12 N 70.34015243 W 149.27622288 7800.00 27.68 343.73 5882.91 4674.45 4487.34 -1309.29 2.00 5974559.86 589177.13 N 70.34027826 W 149.27633199 7900.00 25.68 343.73 5972.26 4719.34 4530.44 -1321.86 2.00 5974602.80 589164.04 N 70.34039599 W 149.27643405 V-102 (P2) report. xis Page 2 of 3 1/9/2002-3:24 PM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim TVD I VSec NI-S EI.W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftU5) (ftU5) 8000.00 23.68 343.73 6063.12 4761.09 4570.51 -1333.56 2.00 5974642.72 589151.86 N 70.34050546 W 149.27652904 8100.00 21.68 343.73 6155.39 4799.64 4607.52 -1344.36 2.00 5974679.60 589140.62 N 70.34060656 W 149.27661672 Top H RZ 8117.96 21.32 343.73 6172.10 4806.22 4613.84 -1346.20 2.00 5974685.89 589138.70 N 70.34062382 W 149.27663166 8200.00 19.68 343.73 6248.94 4834.95 4641.42 -1354.25 2.00 5974713.37 589130.32 N 70.34069917 W 149.27669702 8300.00 17.68 343.73 6343.67 4866.97 4672.15 -1363.22 2.00 5974743.99 589120.98 N 70.34078311 W 149.27676985 Base H RZ 8329.79 17.08 343.73 6372.10 4875.87 4680.70 -1365.71 2.00 5974752.51 589118.39 N 70.34080647 W 149.27679007 K-1 8381.95 16.04 343.73 6422.10 4890.73 4694.97 -1369.88 2.00 5974766.72 589114.04 N 70.34084545 W 149.27682392 8400.00 15.68 343.73 6439.46 4895.67 4699.70 -1371.26 2.00 5974771.44 589112.61 N 70.34085837 W 149.27683513 Top Kuparuk 8433.84 15.00 343.73 6472.09 4904.62 4708.29 -1373.76 2.00 5974779.99 589110.00 N 70.34088184 W 149.27685543 End Orp / Tgt 8433.85 15.00 343.73 6472.10 4904.62 4708.30 -1373.76 2.00 5974780.00 589110.00 N 70.34088187 W 149.27685543 Kuparuk C 8439.02 15.00 343.73 6477.10 4905.96 4709.58 -1374.14 0.00 5974781.28 589109.61 N 70.34088536 W 149.27685851 ~ LCU 8583.96 15.00 343.73 6617.10 4943.47 4745.59 -1384.65 0.00 5974817.16 589098.67 N 70.34098373 W 149.27694385 Kuparuk A 8718.55 15.00 343.73 6747.10 4978.30 4779.03 -1394.41 0.00 5974850.47 589088.50 N 70.34107508 W 149.27702309 Top Miluveach 8796.19 15.00 343.73 6822.10 4998.40 4798.32 -1400.04 0.00 5974869.69 589082.64 N 70.34112778 W 149.27706880 0/ TO /5-1/2" Csg pt 8946.19 15.00 343.73 6966.99 5037.22 4835.59 -1410.92 0.00 5974906.82 589071.31 N 70.34122959 W 149.27715714 LeQal Description: Surface: 4842 FSL 1760 FEL S11 T11N R11E UM End Orp / Tgt: 4270 FSL 3130 FEL 82 T11 N R11 E UM BHL: 4397 FSL 3167 FEL S2 T11N R11E UM Northinq (Y) rftUSl Eastinq (X) rftUSl 5970089.06 590540.35 5974780.00 589110.00 5974906.83 589071.32 - V-102 (P2) report. xis Page 3 of 3 1/9/2002-3:24 PM ) Schlumberger Anticollision Report ) Conipany; , Fieldf Reference'Site: " RefëdmceWeU: . ReferenceWellpath; BPAmqco , , Prudhoel3ay ÞBVPad V;.;102 ' " PlanV-t02, ' , 1/9/2002 ,Time:,' 14;50:38 ,Påge: , , , Cð-oÏ"itiôäte(NE)Reference: , Y~rtibÜ(TVD)Refê..encë: Db: '.' Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method; MD Interval: 50.00 ft Depth Range: 28.50 to 8946.19 ft Maximum Radius: 2000.00 ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 9/12/2001 Validated: No Planned From To Survey ft ft 28.50 1000.00 1000.00 8946.19 Version: Toolcode 2 Tool Name Planned: Plan #2 V1 Planned: Plan #2 V1 CB-GYRO-SS MWD Camera based gyro single shots MWD - Standard Casing Points 1_,' " " '7, :,~'~,C'":",', """"':~7"""':''''7, '""", '-~, "'7""'7, "'7, "T'~:"":~, :, ',' ,"'MD' .,:""",,' TVD" " Diameter' : .ft ' ft ' "in' ~~~~-~ .. ... I 3189.58 2682.10 8946.19 6966.65 7.625 5.500 9.625 6.750 75/8" 5 1/2" x 3 1/2" Summary "~",--''''''''''''''''~."'''',"'-'"''~'''''''''-'''~~''''''''''-''-''~'-'''''''-~'.-""'''''''''''.:''''''~''''''''''''''''":'--'''''''''''~''''''''''''''-'-'''''''~''-:''''T'''''''''-'-~-'-~'~''-'~''''-''-'''':'''---:''--:--",:",''''~~'---''''-'-'__"'''_'T~''__'~'''---~'-~''-'--'-''''''~'-'''''''~-''''-'''''--'...._.....~~.._._.,~._._,-..-..._......"..._....._-_..~...~..~"'.'~'--"'--"~"h.....~. Reference Offset Cti"~Ctr. Nó'-Gó Állowable 'MD MD ' Distance. Area Deviation' , ft ft ' ft' ft ft., EX WKUPST-01 PB V Pad PB V Pad WKUPST-01 V-100 V-201 WKUPST-01 V1 V-100 V7 V-201 V8 396.79 400.00 263.66 500.04 500.00 17.74 Out of range 7.93 255.73 Pass: Major Risk 9.65 8.10 Pass: Major Risk "--"'._"~~-'--'----"-'-"-'-""--'---"------'----'-'-_W.'''------'----'-~-------'------"'----'--''- ---.----.-..--...----.--,,-...----- Site: PB V Pad Well: V-100 Rule Assigned: Major Risk Wellpath: V-100 V7 Inter-Site Error: 0.00 ft I..~m"'èm"-,,', "~,"',',',m_,',',",',-" "-, ',,',',"', ~7, ,,:,'-',"', "::,'7,-" ",.'''''''7''-'''''-''',-, ',',".,,', ',',',",,',",',',",", ',,"'.',",',"~,"',","',~, mm'..,'7"'".",',~,,",',,','''~'':,,"', ..,',"',',",',~" "-,."""--~~,,,,,,_,,'m,"'.',,-',,'-,',-,.' ",-'-"-.,,-, ,,'7.,,-, , "'7,' '", -,"-.,"T", . :,'~, ~".,' '"',', 7-,~", ."'7, " -,',,-m,', ",-, ., ,'-',,-, ',,'-,-. -, '-, ',--"---" , C',' " '.," " ,', " ,~" ,'"-,-,,-,, ,,'-, "', ""', ,",."~' -" ""-"., ".. ":",....n,,,,__--- 'Reference" ,Offset," Semi~Major Axis" ,',' ,," ,. " ..Ctr-Ctr No'-Go Allowable, " MD " ' ' TVD ',. 1\:1D " ,TVD Ref ',Offset TFO+AZI TFO;.HS Casing Distance Area Deviation"" Warning ,ftft ft ft ft " ft deg deg' in ' ft 'ftft , ,", , , , 50.00 50.00 50.00 50.00 0.05 0.03 119.16 119.16 9.625 261.64 1.25 260.39 Pass 100.00 100.00 100.00 100.00 0.16 0.05 119.17 119.17 9.625 261.65 2.16 259.48 Pass 150.00 150.00 150.00 150.00 0.33 0.08 119.18 119.18 9.625 261.66 3.25 258.41 Pass 200.00 200.00 200.00 200.00 0.50 0.13 119.23 119.23 9.625 261.65 4.41 257.24 Pass 250.00 250.00 250.00 250.00 0.61 0.17 119.30 119.30 9.625 261.78 5.36 256.42 Pass 299.99 299.99 300.00 299.99 0.72 0.20 119.38 119.38 9.625 262.20 6.28 255.91 . Pass 348.40 348.40 350.00 349.99 0.81 0.22 119.51 135.78 9.625 262,84 7.10 255.73 Pass 396.79 396.78 400.00 399.99 0.91 0.24 119.71 135.98 9.625 263.66 7.93 255.73 Pass 445.15 445.14 450.00 449.98 0.99 0.27 119.99 136.26 9.625 264.78 8.77 256.01 Pass 493.48 493.45 500.00 499.98 1.08 0.30 120.33 136.60 9.625 266.25 9.58 256.67 Pass 541 .77 541.70 550.00 549.97 1.16 0.31 120.73 137.00 9.625 268.07 10.35 257.72 Pass 590.02 589.90 600.00 599.97 1.24 0.31 121.18 137.45 9.625 270.23 11.08 259.16 Pass 636.96 636.75 650.00 649.96 1.33 0.29 121.69 137.96 9.625 272.72 11.73 261.00 Pass 683.46 683.13 700.00 699.96 1.41 0.27 122.31 138.58 9.625 275.74 12.36 263.38 Pass 729.82 729.31 750.00 749.96 1.49 0.25 123.00 139.27 9.625 279.41 13.00 266.42 Pass 776.03 775.26 800.00 799.96 1.58 0.23 123.76 140.03 9.625 283.74 13.63 270.13 Pass 822.06 820.95 850.00 849.95 1.68 0.21 124.59 140.86 9.625 288.75 14.26 274.51 Pass 867.89 866.35 900.00 899.95 1.78 0.22 125.47 141.74 9.625 294.44 15.02 279.47 Pass 912.99 910.91 950.00 949.95 1.86 0.24 126.42 142.69 9.625 300.86 15.77 285.19 Pass 956.59 953.84 1000.00 999.95 1.91 0.27 127.44 143.71 9.625 308.16 16.37 291.89 Pass I 1000.00 996.40 1050.00 1049.95 1.96 0.29 128.54 144.81 9.625 316.35 16.96 299.51 Pass 1042.63 1038.00 1100.00 1099.95 1.99 0.30 129.68 145.95 9.625 325.51 17.43 308.22 Pass 1085,01 1079.13 1150.00 1149.95 2.01 0.31 130.84 147.11 9.625 335.67 17.90 317.91 Pass 1126.91 1119.57 1200.00 1199,95 2.06 0.34 132.02 148.29 9.625 346.88 18.53 328.58 Pass 1168.28 1159.25 1250.00 1249.95 2.13 0.38 133.21 149.48 9.625 359.14 19.19 340.29 Pass I 1209.09 1198.13 1300.00 1299.95 2.20 0.41 134.40 150.67 9.625 372.49 19.96 353.06 Pass 1249.30 1236.18 1350.00 1349.95 2.30 0.45 135.59 151.86 9.625 386.89 20.76 366.89 Pass ~--- -""-----.-'-. ----..- -------- - .-- -------------..,.-.- .-"'.---. .._---'--- - -- - -----,,--.-.------.-. ----'-'--"'-'--'-"----'..-' - ______n_.. -.-.-.-- ---. -.- ~--_. - - -,-, ---,. ---- "'--'-' ---.--.-- -,--'" ---- ..-.. __m____u -- . --- ') Schlumberger ) Anticollision Report n.. , , COlDpany; , BP Amoco Date: 1/9/2002 TÌlne: '14:50:38 ,P~ge:, . 2> ,Field: ' " Pr9dhoeBay . . . . "Well:Vj102, TrÜeNbrth .' Refeh~Ï1ce:Site: PB V Pad' , Cò-orê:linate<N'E).~~ferenc~: . Reference Well: V-102 ". ',' , ' 'Vertical (TVD)J{éferencë:" ," V-102plan82.1 " , " ,Refer~nëeWellpäth:" Plan.v~102 ,Db:Sybasé , Site: PB V Pad Well: V-100 Rule Assigned: Major Risk Well path: V-100 V7 Inter-Site Error: 0.00 ft Reference 'Offset. , SerrihMåjor¡\xis ' Ctr~Ctr Nô'-Go, Allowable MD' TVD MD" TVD Ref' OffSet TFO+AZI TFP':HSCasing , ' Distance :Area Deviåtiôn, Warning ft ,ft ,ft, ft .,' ft ft ,deg' dØg, in " ft ft ft " 1288.89 1273.36 1400.00 1399.94 2.41 0.48 136.80 153.07 9.625 402.29 21.53 381.74 Pass 1327.84 1309.67 1450.00 1449.94 2.54 0.50 137.99 154.26 9.625 418.69 22.40 397.60 Pass 1366.16 1345.09 1500.00 1499.94 2.69 0.52 139.14 155.41 9.625 436.10 23.22 414.48 Pass 1400.00 1376.13 1550.00 1549.93 2.82 0.55 140.25 156.52 9.625 454.56 24.06 432.47 Pass 1440.75 1413.17 1600.00 1599.93 3.03 0.57 141.33 157.60 9.625 474.04 25.12 451.33 Pass 1477.00 1445.82 1650.00 1649.92 3.21 0.59 142.37 158.64 9.625 494.46 26.04 471.23 Pass 1512.62 1477.60 1700.00 1699.92 3.40 0.61 143.36 159.63 9.625 515.69 27.06 491.96 Pass 1547.55 1508.47 1750.00 1749.91 3.62 0.63 144.31 160.58 9.625 537.81 28.07 513.55 Pass 1581.80 1538.44 1800.00 1799.91 3.83 0.65 145.20 161.47 9.625 560.81 29.05 536.06 Pass 1615.37 1567.53 1850.00 1849.90 4.05 0.67 146.05 162.32 9.625 584.62 30.17 559.37 Pass 1648.29 1595.76 1900.00 1899.90 4.28 0.69 146.85 163.12 9.625 609.19 31.21 583.44 Pass 1680.52 1623.11 1950.00 1949.89 4.52 0.71 147.60 163.87 9.625 634.58 32.24 608.35 Pass 1700.00 1639.50 2000.00 1999.89 4.66 0.73 148.32 164.59 9.625 660.89 33.05 634.37 Pass 1742.91 1675.22 2050.00 2049.88 5.00 0.76 149.02 165.29 9.625 687.60 34.64 660.36 Pass 1773.11 1700.04 2100.00 2099.86 5.25 0.78 149.69 165.96 9.625 715.10 35.70 687.41 Pass 1800.00 1721.90 2150.00 2149.85 5.46 0.80 150.31 166.58 9.625 743.21 36.68 715.12 Pass 1831.71 1747.40 2200.00 2199.84 5.74 0.82 150.89 167.16 9.625 771.90 37.85 743.32 Pass 1866.69 1775.24 2250.00 2249.83 6.05 0.83 151.44 167.71 9.625 801.15 39.24 772.02 Pass 1906.47 1806.88 2300.00 2299.82 6.41 0.85 151.96 168.23 9.625 830.54 40.84 800.74 Pass 1931.59 1826.73 2350.00 2349.81 6.65 0.88 152.45 168.72 9.625 860.35 42.07 830.12 Pass 1955.96 1845.71 2400.00 2399.80 6.88 0.90 152.91 169.18 9.625 890.86 43.04 860.24 Pass 1979.70 1863.96 2450.00 2449.78 7.10 0.92 153.35 169.62 9.625 921.99 43.99 891.00 Pass 2000.00 1879.37 2500.00 2499.77 7.30 0.94 153.77 170.04 9.625 953.78 44.99 922.47 Pass 2025.27 1898.28 2550.00 2549.76 7.56 0.96 154.17 170.44 9.625 986.18 46.06 954.4 7 Pass 2047.14 1914.40 2600.00 2599.75 7.79 0.98 154.55 170.81 9.625 1019.19 46.99 987.13 Pass 2068.42 1929.87 2650.00 2649.73 8.01 0.99 154.90 171.17 9.625 1052.78 47.83 1020.40 Pass 2100.00 1952.43 2700.00 2699.72 8.34 1.00 155.24 171.50 9.625 1087.02 49.02 1054.16 Pass 2100.00 1952.43 2750.00 2749.71 8.34 1.01 155.55 171.82 7.000 1121.73 49.00 1089.03 Pass 2128.61 1972.44 2800.00 2799.70 8.66 1.03 155.87 172.14 7.000 1157.15 50.21 1123.98 Pass 2147.29 1985.28 2850.00 2849.67 8.87 1.04 156.18 172.45 7.000 1193.38 50.99 1159.91 Pass 2175.23 2004.15 2900.00 2899.66 9.18 1.06 156.42 172.69 7.000 1230.38 52.19 1196.44 Pass 2189.91 2013.97 2950.00 2949.62 9.35 1.06 156.55 172.82 7.000 1267.80 52.86 1233.60 Pass 2222.75 2035.91 3000.00 2999.45 9.73 1.06 156.58 172.85 7.000 1305.49 54.45 1270.71 Pass 2255.50 2057.80 3050.00 3049.04 10.11 1.05 156.51 172.78 7.000 1343.23 55.86 1307.85 Pass 2288.27 2079.70 3100.00 3098.30 10.49 1.05 156.35 172.62 7.000 1380.80 57.31 1344.78 Pass 2321.01 2101.58 3150.00 3147.14 10.87 1.06 156.11 172.38 7.000 1418.13 59.04 1381.42 Pass 2353.59 2123.36 3200.00 3195.47 11.25 1.08 155.80 172.07 7.000 1455.23 60.58 1417.78 Pass 2385.85 2144.92 3250.00 3243.18 11.62 1.14 155.42 171.69 7.000 1492.14 62.18 1453.83 Pass 2417.43 2166.03 3300.00 3290.14 11.99 1.20 154.97 171.24 7.000 1529.05 63.99 1489.83 Pass 2448.11 2186.53 3350.00 3336.23 12.35 1.32 154.46 170.73 7.000 1566.06 65.63 1525.74 Pass 2477.51 2206.18 3400.00 3381.37 12.70 1.45 153.90 170.17 7.000 1603.42 67.19 1561.98 Pass 2505.76 2225.07 3450.00 3425.36 13.03 1.65 153.29 169.56 7.000 1640.82 69.00 1598.04 Pass 2533.02 2243.28 3500.00 3467.98 13.35 1.85 152.61 168.88 7.000 1677 .92 70.53 1633.80 Pass 2559.53 2261.00 3550.00 3509.33 13.66 2.13 151.90 168.17 7.000 1714.65 72.06 1668.97 Pass i 2585.46 2278.33 3600.00 3549.54 13.96 2.40 151.15 167.42 7.000 1750.97 73.54 1703.74 Pass 2610.05 2294.77 3650.00 3588.51 14.25 2.73 150.39 166.66 7.000 1787.51 75.19 1738.57 Pass I 2632.89 2310.03 3700.00 3626.14 14.52 3.07 149.60 165.87 7.000 1824.50 76.56 1773.84 Pass 2653.70 2323.94 3750.00 3661.95 14.77 3.45 148.79 165.06 7.000 1861.70 77.86 1809.24 Pass 2672.44 2336.46 3800.00 3695.77 14.99 3.85 147.95 164.22 7.000 1898.95 79.12 1844.69 Pass 2689.87 2348.12 3850.00 3727.90 15.19 4.27 147.09 163.36 7.000 1935.98 80.46 1879.87 Pass 2706.42 2359.18 3900.00 3758.75 15.39 4.68 146.23 162.50 7.000 1972.84 81.92 1914.95 Pass --~_...._-- --~ --- ---.--'.-.. - -- --.-. '-'''----''''.'-' -- ".- -...-- ) Schlumberger Anticollision Report , , , CQmpany: BPAmo,co "ineld: ' '. Prüdhþ6 Bay' RêferenceSite: PBVPád' , 'RefereliceWell: ",', V~t02 ' ReferenceWellpath:.' PlanW1 02 PB V Pad V-100 V-100 V7 " 1/9/2002 . . .. Co~ordiriatê(NE) ;Rdêrê~ce: Vedicål(TVD)RêCèrenté, ) , TjlD,e: ,. ,14:50:38'" Rule Assigned: Inter-Site Error: Major Risk 0.00 ft Offset ' Sê~i-'Majo¡' Axis .. Ctr';Ctr , ,.NølGo Allowåble MD TV!>' , Ref' , Offset '. "TFü+AZI TFO-HSCåsing' '. DiStance Area ' Deviätiori War~ing , ; -'--_'_~~'M' Site: PB V Pad Well: V-201 Wellpath: V-201 V8 -,~~-"""""""''''''''''''''''-'.'''''''''''''''''' Reference' , Offset MD , ¡VD MD." TvD" ft ft ft ft 28.50 28.50 28.50 28.50 50.00 50.00 50.00 50.00 100.00 100.00 100.00 100.00 150.00 150.00 150.00 150.00 200.00 200.00 200.00 200.00 .~"....".........~......._._,_..............~.....,.........,...,........~......._--........_~_...........- , Sen1i-'Majö.. Axis Ref.' Offset 1'FO+A?:1 TJö'Q-H~G~sing 'ft, ' ft dEig' -,-~~~ in 0.00 0.00 255.67 255.67 9.625 0.05 0.02 255.66 255.66 9.625 0.16 0.04 255.54 255.54 9.625 0.33 0.11 255.37 255.37 9.625 0.50 0.16 255.19 255.19 9.625 250.00 250.00 250.00 250.00 0.61 300.00 300.00 300.00 300.00 0.72 350.00 350.00 350.00 349.99 0.82 400.01 400.01 400.00 399.98 0.91 450.03 450.01 450.00 449.95 1.00 500.04 500.00 500.00 499.92 1.09 550.05 549.97 550.00 549.85 1.18 600.04 599.90 600.00 599.74 1.26 650.05 649.82 650.00 649.56 1.35 700.03 699.64 700.00 699.30 1.44 749.96 749.34 750.00 748.93 1.53 799.84 798.91 800.00 798.43 1.63 849.69 848.32 850.00 847.79 1.74 899.49 897.58 900.00 897.04 1.85 949.28 946.65 950.00 946.18 1.90 999.00 995.42 1000.00 995.17 1.96 1048.67 1043.87 1050.00 1043.99 1.99 1098.24 1091.93 1100.00 1092.57 2.02 1147.70 1139.54 1150.00 1140.88 2.09 1197.01 1186.65 1200.00 1188.84 2.17 1246.15 1233.21 1250.00 1236.44 2.29 1295.11 1279.18 1300.00 1283.64 2.42 1343.90 1324.55 1350.00 1330.45 2.61 1392.47 1369.24 1400.00 1377.00 2.79 1440.80 1413.22 1450.00 1423.27 3.03 1488.92 1456.49 1500.00 1469.18 3.27 1536.81 1499.01 1550.00 1514.67 3.55 1584.45 1540.75 1600.00 1559.63 3.84 1631.82 1581.67 1650.00 1604.26 4.17 1678.85 1621.70 1700.00 1649.00 4.50 1725.47 1660.77 1750.00 1693.66 4.86 1771.67 1698.86 1800.00 1738.01 5.24 1817.42 1735.95 1850.00 1782.08 5.62 1863.57 1772.76 1900.00 1825.92 6.02 1910.38 1809.98 1950.00 1869.46 6.45 1953.78 1844.03 2000.00 1912.64 6.86 I 1996.36 1876.62 2050.00 1955.38 7.26 2038.16 1907.81 2100.00 1997.64 7.69 2079.43 1937.79 2150.00 2039.52 8.12 '---,-~-_...._-~---- ------ - --'-"".------.---.----,-"---'---'-- -- 0.17 255.39 255.39 9.625 0.19 256.80 256.80 9.625 0.19 258.68 274.95 9.625 0.20 260.28 276.55 9.625 0.24 261.17 277.44 9.625 0.29 261.34 277.61 9.625 0.34 261.80 278.07 9.625 0.39 262.61 278.88 9.625 0.45 262.87 279.14 9.625 0.51 262.31 278.58 9.625 0.57 261.39 277.66 9.625 0.64 260.36 276.63 9.625 0.70 259.40 275.67 9.625 0.77 258.32 274.59 9.625 0.83 256.77 273.04 9.625 0.90 254.99 271.26 9.625 0.96 253.24 269.51 9.625 1.03 251.56 267.83 9.625 1.11 249.99 266.26 9.625 1.20 248.57 264.84 9.625 Rule Assigned: Inter-Site Error: ----- Major Risk 0.00 ft "~'-n~"__---'- ._-_.~_.._..~---,~.__........ " Ctr-Ctr ;,No';Go Allowable. DiStånceArea, Deviåtion Warning" , f~_.--_~~~-~~~~.,---~--,-, 15.24 0.80 14.44 Pass 15.25 1.23 14.01 Pass 15.28 2.14 13.14 Pass 15.33 3.36 11.97 Pass 15.38 4.49 10.89 Pass 15.48 5.38 15.61 6.25 15.87 7.04 16.30 7.86 16.92 8.75 17.74 9.65 18.98 10.55 20.71 11.47 23.04 12.39 25.97 13.34 29.61 14.29 33.84 15.26 38.53 16.26 43.57 17.28 48.84 18.12 54.28 18.97 59.85 19.76 65.78 20.55 72.19 21.51 79.28 22.47 1.29 247.31 263.58 9.625 87.09 23.64 1.39 246.20 262.47 9.625 95.52 24.79 1.50 245.18 261.45 9.625 104.57 26.18 1.61 244.03 260.30 9.625 114.21 27.53 1.73 242.80 259.07 9.625 124.44 29.10 10.10 Pass 9.37 Pass 8.84 Pass 8.44 Pass 8.18 Pass 8.10 Pass 8.43 Pass 9.25 Pass 10.65 Pass 12.65 Pass 15.33 Pass 18.60 Pass 22.30 Pass 26.32 Pass 30.75 Pass 35.34 Pass 40.12 Pass 45.26 Pass 50.71 Pass 56.83 Pass 63.46 Pass 70.74 Pass 78.39 Pass 86.68 Pass 95.34 Pass 1.85 241.65 257.92 9.625 135.15 30.63 104.53 Pass 1.97 240.60 256.87 9.625 146.36 32.40 113.99 Pass 2.10 239.71 255.98 9.625 158.15 34.10 124.09 Pass 2.18 238.80 255.07 9.625 170.45 35.87 134.66 Pass 2.25 237.57 253.84 9.625 183.21 37.54 145.81 Pass 2.33 236.21 252.48 9.625 196.58 39.42 157.39 Pass 2.41 234.90 251.17 9.625 210.72 41.21 169.83 Pass 2.56 233.63 249.90 9.625 225.57 43.30 182.73 Pass 2.71 232.40 248.67 9.625 241.09 45.47 196.23 Pass 2.86 231.41 247.68 9.625 257.45 47.75 210.45 Pass 3.00 230.50 246.77 9.625 275.25 49.80 226.38 3.15 229.62 245.88 9.625 294.40 51.85 243.65 3.29 228.77 245.04 9.625 314.64 54.13 261.84 3.43 227.95 244.22 9.625 335.33 56.23 280.67 - -.---- - - ...---- ---." -- -- .- --- '----- ----.-.-- -- - -----"'-."------"-----'--'----'- -- - -- Pass Pass Pass Pass --'-~'----'---- -----"0 ) Schlumberger ) Anticollision Report , , , ÇÒißpany: BPAmóco ,Date: '1/9/2002 Ti~e: .., 14:50:38 ' ' ,Field: , Pr~dbc>eBay , " , Réference Site:. , PBVpäd . "Co~ortlinate(NErReference:' WeU:V~102;True " ReferenceWeU: " 'V~102 " ' , 'Vertiêål(TVD)Refereriêe:. . . 'I-:1Ö2pIØn82.1. - R.eferenceW~lIpath:.. Plan V~102 . .. . Site: PB V Pad Well: V-201 Rule Assigned: Major Risk Wellpath: V-201 V8 Inter-Site Error: 0.00 ft I . Reference Offset Selßi~Major A.xis " " Ctr~Ct.. "", NóLGô Allowable [ " I, MD' ' TVD, MD ,TVD' Ref,". Offset TFO+AiL TF041S Çasing Distance ,Area, Deviatiolr ' ft ft ' ft ft ft, ft, . deg' deg in ' ft, ' " ft " ft 2120.29 1966.66 2200.00 2081.06 8.56 3.56 227.14 243.41 9.625 356.10 58.49 299.46 Pass 2160.71 1994.39 2250.00 2122.22 9.02 3.69 226.35 242.62 9.625 377.08 60.64 318.59 Pass 2203.98 2023.37 2300.00 2162.99 9.51 3.83 225.61 241.88 9.625 398.18 63.20 337.45 Pass 2249.32 2053.67 2350.00 2203.63 10.04 3.97 224.95 241 .22 9.625 418.74 65.60 355.92 Pass 2294.97 2084.18 2400.00 2244.25 10.57 4.09 224.35 240.62 9.625 438.63 67.97 373.76 Pass 2340.93 2114.90 2450.00 2285.10 11.10 4.19 223.74 240.01 9.625 457.71 70.51 390.67 Pass 2387.17 2145.81 2500.00 2326.24 11.64 4.28 223.09 239.36 9.625 475.99 72.82 407.01 Pass 2433.55 2176.81 2550.00 2367.83 12.18 4.36 222.38 238.65 9.625 493.68 75.34 422.63 Pass 2480.08 2207.90 2600.00 2409.84 12.73 4.45 221.62 237.89 9.625 510.71 77.68 437.81 Pass 2526.94 2239.22 2650.00 2451.99 13.28 4.55 220.83 237.10 9.625 526.61 80.25 451.69 Pass 2574.10 2270.74 2700.00 2494.20 13.83 4.65 220.03 236.30 9.625 541.49 82.67 464.72 Pass 2621.37 2302.33 2750.00 2536.48 14.39 4.75 219.24 235.51 9.625 555.89 85.32 477.13 Pass 2668.71 2333.97 2800.00 2578.82 14.94 4.86 218.46 234.73 9.625 570.05 87.74 489.50 Pass 2716.00 2365.58 2850.00 2621.22 15.50 4.95 217.71 233.98 9.625 584.42 90.38 501.94 Pass 2763.16 2397.10 2900.00 2663.90 16.05 5.04 216.95 233.22 9.625 599.06 92.77 514.91 Pass 2810.03 2428.42 2950.00 2707.19 16.61 5.13 216.12 232.39 9.625 614.08 95.37 528.16 Pass 2856.92 2459.76 3000.00 2750.47 17.16 5.25 215.33 231.60 9.625 629.17 97.84 541.59 Pass 2903.72 2491.04 3050.00 2793.88 17.71 5.37 214.56 230.83 7.000 644.55 100.41 555.29 Pass 2950.24 2522.13 3100.00 2838.07 18.26 5.44 213.65 229.92 7.000 659.64 102.75 569.02 Pass 2996.51 2553.06 3150.00 2882.97 18.81 5.51 212.55 228.82 7.000 673.57 105.07 581.80 Pass 3042.40 2583.73 3200.00 2928.40 19.35 5.57 211.32 227.59 7.000 687.09 107.58 594.19 Pass 3087.84 2614.10 3250.00 2974.27 19.89 5.63 210.02 226.29 7.000 700.66 109.83 606.98 Pass 3132.53 2643.97 3300.00 3020.75 20.42 5.68 208.62 224.89 7.000 714.99 112.24 620.58 Pass 3176.32 2673.23 3350.00 3067.86 20.94 5.72 207.15 223.42 7.000 730.39 114.37 635.59 Pass 3219.35 2701.99 3400.00 3115.33 21.45 5.75 205.60 221.87 7.000 746.19 116.54 651.19 Pass 3261.67 2730.28 3450.00 3162.98 21.95 5.78 203.98 220.25 7.000 762.19 118.59 667.22 Pass 3303.41 2758.17 3500.00 3210.59 22.44 5.81 202.30 218.57 7.000 777.96 120.81 683.07 Pass 3344.49 2785.63 3550.00 3258.08 22.93 5.83 200.56 216.83 7.000 793.56 122.42 699.44 Pass 3384.35 2812.27 3600.00 3305.62 23.40 5.85 198.75 215.02 7.000 809.86 123.92 716.79 Pass 3422.90 2838.04 3650.00 3353.17 23.86 5.86 196.88 213.15 7.000 827.12 125.57 735.19 Pass 3460.52 2863.18 3700.00 3400.68 24.31 5.87 195.00 211.27 7.000 845.41 126.96 754.86 Pass 3497.44 2887.85 3750.00 3448.13 24.75 5.87 193.15 209.42 7.000 864.70 128.33 775.63 Pass 3534.30 2912.49 3800.00 3495.55 25.18 5.88 191.37 207.64 7.000 884.81 129.91 797.10 Pass 3571.04 2937.05 3850.00 3542.98 25.62 5.89 189.67 205.94 7.000 905.83 131.28 819.56 Pass 3607.32 2961.30 3900.00 3590.51 26.05 5.90 188.03 204.30 7.000 928.09 132.83 843.18 Pass 3643.33 2985.36 3950.00 3638.10 26.48 5.91 186.46 202.73 7.000 951 .40 134.16 867.93 Pass 3679.45 3009.50 4000.00 3685.71 26.91 5.91 184.98 201.25 7.000 975.36 135.50 893.27 Pass 3715.68 3033.72 4050.00 3733.33 27.34 5.93 183.57 199.84 7.000 999.91 137.08 919.04 Pass 3751.99 3057.98 4100.00 3780.94 27.77 5.95 182.24 198.51 7.000 1024.95 138.45 945.34 Pass 3788.38 3082.31 4150.00 3828.55 28.20 5.96 180.98 197.25 7.000 1050.45 139.84 972.00 Pass I 3824.86 3106.68 4200.00 3876.14 28.63 5.98 179.77 196.04 7.000 1076.35 141.44 998.94 Pass ! 3861.43 3131.13 4250.00 3923.71 29.07 6.01 178.63 194.90 7.000 1102.57 142.85 1026.19 Pass : 3898.10 3155.64 4300.00 3971.25 29.50 6.03 177.53 193.80 7.000 1129.08 144.24 1053.66 Pass 3934.28 3179.82 4350.00 4018.77 29.93 6.04 176.47 192.74 7.000 1156.33 145.81 1081.77 Pass 3969.71 3203.50 4400.00 4066.27 30.35 6.05 175.43 191.70 7.000 1184.51 147.13 1110.85 Pass 4004.96 3227.06 4450.00 4113.78 30.77 6.05 174.44 190.71 7.000 1213.20 148.65 1140.33 Pass 4040.27 3250.66 4500.00 4161.29 31.19 6.06 173.49 189.76 7.000 1242.20 149.97 1170.00 Pass 4075.69 3274.33 4550.00 4208.80 31.61 6.08 172.59 188.86 7.000 1271.43 151.32 1199.77 Pass 4111.24 3298.09 4600.00 4256.29 32.04 6.10 171.73 188.00 7.000 1300.82 152.88 1229.64 Pass 4146.87 3321.91 4650.00 4303.79 32.46 6.12 170.91 187.18 7.000 1330.45 154.24 1259.65 Pass 4182.59 3345.78 4700.00 4351.31 32.89 6.14 170.13 186.40 7.000 1360.28 155.61 1289.80 Pass ~-_._,-_._--~"-~~--~- - -".'-- - ----- - ------.-.------.--..--,- ---.-- - .- ,,_. ,--,--'----_._- ------ . _u_.- '-_.- ,.-- ". -" --,------~------,-,-".-_.._.._-- ) Schlumberger Anticollision Report ) , Date:' 119/2002 , Time: 14:50:38 , çompal1Y: , , BP.Amoco Field: " prucJh()~ Bay , Refefel1êëSite:' " PBVPad' , Referel1ceWell: , V~102 " _~ef~rt!ceWëllpath:PlanV";1 02 Site: PB V Pad Well: V-201 Wellpath: V-201 V8 Reference, MD "'TVD" ft ft . .. . . , , Ço~rdinatë(NË)Referëncë: "'Nell: V,,; 1 02,ThJeNorth" 'VertièåI(TVD)'R~fefence:' V;;;102pli:m82:r'" , Rule Assigned: Inter-Site Error: Major Risk 0.00 ft Offset . Sëilii~MajofAxis ' ' Ctr~Ctr No';Go Allowable MD 'TVD 'Ref'" Offset TFØ-t-AZITFO';II~Casing' Distance: Area" D~viåtion' Warning' ,ft ftft ,ft degdeg '. in .,ft 'ft, 'ft'" 4218.38 3369.70 4750.00 4398.83 33.31 6.16 169.39 185.66 7.000 1390.30 157.19 1320.07 Pass 4254.24 3393.67 4800.00 4446.34 33.74 6.18 168.68 184.95 7.000 1420.47 158.57 1350.39 Pass 4290.21 3417.71 4850.00 4493.81 34.16 6.20 167.99 184.26 7.000 1450.70 159.95 1380.72 Pass 4326.27 3441.80 4900.00 4541.25 34.59 6.22 167.34 183.61 7.000 1480.99 161.56 1411.03 Pass 4362.36 3465.93 4950.00 4588.66 35.02 6.25 166.71 182.98 7.000 1511.40 162.95 1441.40 Pass 4398.48 3490.07 5000.00 4636.04 35.45 6.27 166.10 182.37 7.000 1541.93 164.34 1471.83 Pass 4434.61 3514.22 5050.00 4683.42 35.88 6.29 165.51 181.78 7.000 1572.60 165.95 1502.34 Pass 4470.76 3538.38 5100.00 4730.80 36.31 6.31 164.95 181.22 7.000 1603.41 167.33 1532.98 Pass 4506.95 3562.56 5150.00 4778.21 36.74 6.33 164.41 180.68 7.000 1634.39 168.93 1563.74 Pass 4543.23 3586.81 5200.00 4825.65 37.17 6.35 163.90 180.17 7.000 1665.46 170.28 1594.58 Pass 4579.60 3611.12 5250.00 4873.12 37.61 6.37 163.41 179.68 7.000 1696.62 170.97 1625.76 Pass 4594.15 3620.84 5270.00 4892.11 37.78 6.38 163.22 179.49 7.000 1709.12 171.24 1637.78 Pass --.-...--" Page: " ) V-102 Production Cement Job Correction Casing Size 5-1/2"x3-1/2" Production Longstring Basis: Lead: Based on TOC 500' above the top of the Schrader Bluff formation + 300/0 excess and Base of cement 500' above top of Kuparuk formation at 7928' (5996' TVDbkb). Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe track volume.TOC 500' above top of Schrader 4589' (3615' TVDbkb) ~ Total Cement Volume: Lead 65 bbl/365ft3 /142sks of Dowell LiteCrete at 11.5 ppg and 2.56 cf/sk. Tail 38 bbl/213 ft3 /182 sks of Dowell Premium 'G' (KUP Latex Design) at 15.8 ppg and 1.17 cf/sk. . . ') ') i 204433 DATE 01/17/02 CHECK NO. 00204433 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 )11602 CK011602 PYMT COMMENTS: HANDLING INST: 100.00 Per~it to Drill 7ee S/H - Terrie Hub3le X4628 r:"~:,.... F-r/ ~ -"" .. J ~>. v~ } O~ A/..."., . . d,¡t.2 0;- c;' .. 'oC '>. C;¡f¡',ìl/¡,ÚÛ.'i ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 204433 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 --:m- 00204433 JAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 AMOUNT $100.00 fo The JRDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 n\ t jJ(3.' .. Iv{ l~ .1 :,,~'. (""':o<:::'-_~~"" . .'..... '.- . III 2 0 ... ... ~ ~ III I: 0... . 2 0 ~ a g 5 I: 0 0 a ...... ¡. g III ) ") TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN T%S:MITTAL LETTER WELL NAME (-(1Lf. . V~ /0 Z-. CHECK 1 ST ANDARD LETTER DEVELOPMENT I' DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) .- / ANNUL~D~,R DI OSAL . VNO ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a Dew wenbore segment of existing weD ----' Permit No, ,API No. . " Próduction should continue to be reported as a function of the original API number stated above. ' In accordance with 20 AAC 25.005(1), all records, data and logs acquired for' the pilot hole mu'st be clearly , differentiated in both name (name on permit plus PH) and API number (50 ..70/80) from records, data and logs acquired for wel~ (na,me on permit). Annular disposal has ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS <--J YES + , SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to drill the above referenced wen. The permit is approved ,subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to tbe spacing exception that may occur. ~û WELL PERMIT CHECKLlS] ~OMPANY 1t.6fk. WELL NAME ~~ 102- FIELD & POOL (;2'1f) I 30 INIT CLASS ~-~..(3V I' ()/ L ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N /:) 4. Well located in a defined pool.~. . . . . . . . . . . . . . . . N ::;¡<-rBt"'- K~ [>~ ¿ C'Q0 ( 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N APW DATE 0 t.- 12. Permit can be issued without administrative approval.. . . . . N ?H 2, {3' 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . to N \.(1 (i) i i 0 TV f) 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N A . -I.. f 16. CMT vol adequate to circulate on conductor & surf csg. . . . . @ N dRqUa ~ e/1.- Cø;( U#(€-1A.-- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y @ V 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N ~~: ~~:~~a~:~~~~~:~~i~:~~~~ ~¡t:.' ~ ~ :~r~~fr.o~t.. ~ ~ ~ ~ ~ ~ ~ ~ ^'~~v(;. q Eg 21. If a re-drill, has a 10-403 for abandonment been approved. . . i1 /'Í fA 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N 24. Drilling fluid program schematic & equip list adequate. . . . . N /Il..ðt-'? I/{ IJJ :10 . 5 e P1 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N -' t APPR DATE 26. BOPE press rating appropriate; test to if-Ç;O() psig. éi2 N MAS p:= ttP \5 f (-{. [$1 fes '-ISOD pc/. ît£;Æ 4Utlo( 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . tV N ~~ 28. Work will occur without operation shutdown. . . . . . . . . . . 0j) N I1P /II '3 !t::;-ö:l 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y QD GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures. . . . . G N 31. Data presented on potential overpressure zones. . . . . . . .' ~ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. ~~ ~ AP£R DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . ..f Y N pf~ "l- ./3 '02---:f4. Contact namelphone for weekly progress reports [e~ry only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N J I~ ' 1 ' (B) will not contaminate freshwater; or cause drilling waste. .. Y N /JO íÙ/l i/uÁAc¿¡/ CÛJ~ aot;.c,,-/l ('er,,{RÇ.Ce d. to surface; ( tI (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: TEM W~1!? WGA ~Æ- PROGRAM: Exp - Dev vi Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA [1'1 {) UNIT# 0//6 Ç7) ON/OFF SHORE ()ÞJ ENGINEERING ( ~1\r~ ~ ý"~?;-' tt::::"-I.J ~ ~ /0,1::> ~' Efit~;/ tþA:d /~d-1/Z!1.k~ /?~~s-c:6¿-- ~ ,~~ Ä~.AD>I- r.. /70&) ~ (¡ ~Ç'l5- /' ~ 1::> -.. ,/~... tl ( APPR DATE Com mentsllnstructions: RPC SF~þ COT, ' DTS(?:3 ¡6 7 ¡é/ z- JMH d'\V\ Vc 2>1 -'1 \OY' G:\geology\permits\checklist.doc