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Home My WebLink About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y Samantha Carlisle at 10:04 am, Jan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�ON REPORT OF SUNDRY WELL OPERATIONS SEP 1 0 2012 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Alaska aleit§as Cons. Cornmtss o Performed: Alter Casing ❑ Pull Tubing] Stimulate - Frac ❑ Waiver ❑ Time Extensiorai fchoc ae Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wee 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IO Exploratory ❑ — 202 -155 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 23108 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: a ADL0028240 as V -107 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, BOREALIS OIL 11. Present Well Condition Summary: Total Depth measured 7428 feet Plugs measured None feet true vertical 7137.44 feet Junk measured 7308 feet Effective Depth measured 7315 feet Packer measured 6584 feet true vertical 7028.57 feet true vertical 6327.37 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 6872 - 6910 feet 6964 - 6982 feet True Vertical depth 6603.39 - 6639.78 feet 6691.46 - 6708.67 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 22 - 6635 22 - 6376.26 '""'"'"' Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker SABL -3 Pac 6584 6327.37 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED MAR 0 4 2013, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 350 298 1217 1451 371 Subsequent to operation: 340 125 1350 1417 380 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ID ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil e U Gas ❑ WDSPI.0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature SinA.47 t "" Phone 564 -4424 Date 9/6/2012 1,' t, 2' , 4i% RSDMS SEP 111012 / ORIGINAL a �E 2 Form 10-404 Revised 10/2010 Submit Original Only 1 Casing / Tubing Attachment ADL0028240 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 PRODUCTION 6615 5 -1/2" 15.5# L -80 25 - 6640 25 - 6381.05 7000 4990 PRODUCTION 778 3 -1/2" 9.2# L -80 6640 - 7418 6381.05 - 7127.81 10160 10530 SURFACE 82 7 -5/8" 29.7# L -80 27 - 109 27 - 109 6890 4790 SURFACE 2518 7 -5/8" 29.7# S -95 109 - 2627 109 - 2593.11 8180 5120 SURFACE 31 7 -5/8" 29.7# L -80 2627 - 2658 2593.11 - 2622.11 6890 4790 SURFACE 126 7 -5/8" 29.7# S -95 2658 - 2784 2622.11 - 2740.01 8180 5120 • TUBING 6613 3 -1/2" 9.2# L -80 22 - 6635 22 - 6376.26 10160 10530 • • Daily Report of Well Operations ADL0028240 * ** JOB CS 1 • _ , * ** RUN 1: PERFORATE INTERVAL BETWEEN 6964- 6982FT WITH 2.5" PJ 2506 HMX GUNS. 6 SPF. 60 DEG PHASE. RUN 2: PERFORATE INTERVAL BETWEEN 6890- 6910FT WITH 2.5" PJ 2506 HMX GUNS. 6 SPF. 60 DEG PHASE. RUN 3: PERFORATE INTERVAL BETWEEN 6872- 6890FT WITH 2.5" PJ 2506 HMX GUNS. 6 SPF. 60 DEG PHASE. FINAL T /I /O = 1310 / 1450 / 250 WELL SHUT IN ON DEPARTURE • 7/30/2012 * ** JOB COMPLETED * ** r p TREE= 3-1/8" 5M • AFETY NOTES: waLFEAD = 11" FMC V -10 7 ACTUATOR = NA KB. ELEV = 822 BF. ELEV = 53.50' KOP = 300' —I 1019' H7-5/8" TAM FORT COLLAR, D = 6.875" Max Angle = 22° @ 2983' Datum MD = 6954' Datum TVD = 6600' SS I I ( 1852' H 3- 1 /2"FESX NP, ID= 2.813" I I7 -5/8" CSG, 29.7 #, L -80, D = 6.875" H 85' I-- 17 -5/8" CSG, 29.7 #, S-95, D = 6.875" H 2784' I- GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DALE L 7 1996 1991 10 KBG-2 I7MY IN T 0 01/00/00 6 2696 2658 21 KBG-2 DMY INT 0 04/24/11 5 3491 3397 22 KBG-2 DONE NT 16 04/24/11 4 4256 4117 19 KBG-2 DMY M 0 04/24/11 Minimum ID = 2.750" @ 6607' 3 4991 4808 19 KBG-2 DONE NT 16 04/24/11 3 -1/2" XN NIPPLE 2 5713 5493 17 KBG-2 DONE NT 16 04/24/11 1 6508 6255 16 KBG-2 SO NT 24 04/24/11 I 6663' I-{ 3-112" I-ES X NP? D = 2.813" I g 't 6684' I- 15 -1/2" X 3-1/2" BKR SABL PKR D = 2.78" I I I 6607' I-{3 -1/2" HES XN NP, D = 2.75" I 6626' 1—[TOP OF 3-1/2' TBG STLB (02101/05) l I3 -1/2" TBG, 9.2#, L -80 BT -M, .0087 bpf, D = 2.992" H 6627 I 6636' H BKR PDORBOY OVERSHOT I 15_1/2- CSG. 15.5ft, L-80, B 1C:, U = 4.950" H 6630' L 6639' H BKR LOC SEAL ASSY , D = 3.00" I [3-1/2" TBG. 9.2#, L -80 BT -M, .0087 bpf, D = 2.992" H 6639' I ' 6642' I—{ TOP OF BKR PBR D = 4.00" 4 -314" X 3 -1/2" XO, D = 3.000" H 6661' I I 6667' HSTM OF 3-1/2" BKR SEAL ASSY, D = 3.00" I I 6681' H 3 -1/2" HES X MP D= 2.813" I PERFORATION SUMMARY I 6701' H 3-1/2" HES X MP D = 2.813" I REF LOG: SWS VISION RES ON 10/07/02 ANGLE AT TOP PERF: 17° @ 6877 Note: Refer to Production DB br historical perf data SIZE SPF _ INTERVAL O�n1Stg, DATE 2 -1/2' 6 6872 -6910 R 07/30/12 6837' PUP JT W / RA TAG 2 /2" MO 6872 - 910 0 2/ 02 0 4 I 6064 - 699r - 4 O 07/30/1 7076' —I P.P JT W/ RA TAG [7308' CTM — FISH - HES FASDRLL, M LED & PUSIED TO BTM (07/14/12) I PBTD H 7317 I -4w4v1•4•4•1 — ••• I3 -1/2" CSG, 9.2#, L -80, D= 2.992" — 7418' DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 10115/02 DAC/KK ORIGINAL COMPLETION WELL: V -107 02/04/05 AM RWO PERMIT No: "2021550 04/27/11 GJB/PJC GLV C/O (04/24/11) API No: 50-029 -23108 07/16/12 TTW /JMD MILL FASORILL FCO /FISH (07/14/12) SEC 11, T11N, R11E, 4835' NSL & 1789' WEL 07/31/12 JCM /JMD REPERF & ADPERF (07/30/12) 08/19/12 PJC PERF CORRECTION 11 BP Exploration (Alaska) ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 kz?`4~/~~~rGL~ f~v ~E~ ,~ `'`4° LUL'~.i ~ bp ~~~~ ~~~ ~ OCT A ~ 2Q09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~ca ~il ~i Gas Con~. Cammi~:io~, Anchorape a,p~- ~SS ~~ ~ ~ ~ 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 r ! 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 Voi. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al V-Ot 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 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 5U029230740000 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 7/11l2009 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-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 5002923328000o NA 1.5 NA 6.8 5/10/2009 V-2o~ 2012220 5002923054000o SC leak NA 4 NA 90.6 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-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ".-~~^ 2080200 50029233830000 NA 1.75 NA ~ 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 Page 1 of 2 • Regg, James B (DOA) • From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, November 03, 2008 12:22 PM ~ ~~ f I ~ ~ (z-' To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: PBU V-107 (PTD 2021550) Hi Jim, A conductor top joky was completed on V-107 (PTD #2021550) on 11/1/08. The cement top is 21/2" from the circ ports in the conductor. .~, Please let us know if you need any additional information. Thank you, Anna ~u6e, 2'. E. eII lnte/yrit~/ Coordinator ~;.~ '~'"~~ ~ f ~^!~4 GPB Wells Group !Alone: (907) 659°5102 PageC: {907) 659°5900 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, October 24, 2008 5:28 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer Subject: RE: PBU V-107 (PTD 2021550) Ni Jim, We°re finishing up the top job procedure and will begin prepping the well. I expect it will take another 7 to 10 days to schedule and complete the work. I will set a reminder to notify you again by November 3rd, Thank you, ,,~nna ~u6e, ~'. E. Well Integrity Coordinator GPB ells Group Phone: {907) 659-5102 Pager: {907) 659-5100 ~c995~4 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, October 24, 2008 11:46 AM To: NSU, ADW Wel! Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: PBU V-107 (PTD 2021550) 11/3/2008 Page 2 of 2 • Spoke with Andrea about this well on 10/15 -fluted hanger was not on seat and wellhead was very unstable according to Inspector out witnessing SVS tests. Would appreciate a status update. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11 /3/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 30, 2008 3:58 PM To: NSU, ADW Well Integrity Engineer Cc: Regg, James B (DOA); Engel, Harry R Subject: RE: PBU V-107 (PTD 2021550) Anna, Sorry about missing the name. Thanks for the reply. Jim and I were curious since CPAI at Kuparuk has been surveying and topping off [with cement and inhibitor] many OOAs. They have also performed a number of excavation projects known as "Big Digs". Their problem has been actual shallow surface casing leaks which does not appear to have manifested itself as greatly in your "world". Please keep us informed regarding the repair work. It is probably appropriate to submit a 404 documenting the work. Thanks much. Call or message with any questions. Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, October 30, 2008 3:41 PM To: Maunder, Thomas E (DOA) Cc: Regg, lames B (DOA); NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: PBU V-107 (PTD 2021550) Hi Tom, Here are answers to your questions. 1. Yes, we will be conducting a conductor top job with cement. 2. The void is 25 feet deep on V-107 3. Voids in the surface casing by conductor annulus is common across the field. New wells are required to have a top job completed after the rig moves off which includes a polymer which adheres to the casing and helps to mitigate corrosion. We are also beginning work to evaluate older wells for this same treatment. 4. BP has not yet performed a survey or assessment but that is part of the evaluation project I mentioned. I hope this helps. Please let me know if you have any additional questions. Thank you, Anna ~u6e, ~ ~. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 30, 2008 1:59 PM To: NSU, ADW Well Integrity Engineer Cc: Regg, James B (DOA) Subject: RE: PBU V-107 (PTD 2021550) Andrea, 12/16/2008 Page 2 of 2 ~J Thanks for the update; a couple of questions ... 1. Will you be using cement to fill the void in the conductor x surface casing annulus (OOA)? 2. Is it known how deep the void is? 3. Do you and your colleagues know if voids in the OOA are common occurrences in wells in BP operated fields? 4. Has BP considered or performed any survey/assessment for the existence of voids in OOA's? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, October 24, 2008 5:28 PM Ta: Regg, lames B (DOA) Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer Subject: RE: PBU V-107 (PTD 2021550) Hi Jim, We're finishing up the top job procedure and will begin prepping the well. I expect it will take another 7 to 10 days to schedule and complete the work. I will set a reminder to notify you again by November 3rd. Thank you, Anna dude, ~ ~. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Regg, James B (DOA) (mailto:jim.regg@ataska.gov] Sent: Friday, October 24, 2008 11:46 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: PBU V-107 (PTD 2021550) Spoke with Andrea about this well on 10/15 -fluted hanger was not on seat and wellhead was very unstable according to Inspector out witnessing SVS tests. Would appreciate a status update. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 12/16/2008 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc -, STATE OF ALASKA ' ALASIV-. JIL AND GAS CONSERVATION Cl..JMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS"MAR 0'32005 . 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 82.2' 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Alaska Oil & GII Con,. Commi ssion 0 <A¥M1torage 0 Time Extension 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 202-155 6. API Number: 50-029-23108-00-00 9. Well Name and Number: PBU V-107 8. Property Designation: 10. Field / Pool(s): ADL 028240 11. Present well condition summary Total depth: measured 7428 feet true vertical 7137 feet Plugs (measured) None Effective depth: measured 6952 feet Junk (measured) 6952 true vertical 6680 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 34" x 20" 108' 108' 1490 470 Surface 2757' 7-5/8" 2784' 2740' 6890 4790 Intermediate Production 7394' 5-1/2" x 3-1/2" 7418' 7128' 7000 4990 Liner Prudhoe Bay Field / Borealis Pool SCANNED MAR 0 4: 2005 Perforation Depth MD (ft): Perforation Depth TVD (ft): 6872' - 6910' 6603' - 6640' Tubing Size (size, grade, and measured depth): 3-1/2", 9.2# L-80 6657' Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" Baker 'SABL' packer; 3-1/2" HES 'X' Nipple 6584' 1852' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Fl MAR 0 3 2005 13. Oil-Bbl Prior to well operation: 396 Subsequent to operation: 133 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure 203 646 983 64 1,414 1 ,500 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing Îs true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Shane Gagliardi, 564-5251 N/A TubinQ Pressure 320 280 Printed Name Terrie Hubble Signature -1f2.fVÙil ~ ~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date °o/Ot/O<; Prepared By Name/Number: Terrie Hubble, 564.4628 Submit Original Only 564-4628 r,\ [, r ('''\ i N ^ L IlJ r< [ LJ " /-\ ) ) Well: Field: API: Permit: V -107 Rig W orkover Prudhoe Bay Unit 50-029-23108-00-00 202-155 Accept: Spud: Release: RiQ: 01/31/05 N/A 02/04/05 Nabors 9ES PRE-RIG WORK 01/04/05 DRIFTED TBG WI 2.80" TO 6750' SLM, SET 2.813" X PLUG AT 6685' SLM. RAN 2.813' CHECK-SET TO 6685' SLM (GOOD SET). SET P-PRONG AT 6685' SLM. SET 2.70" JUNK CATCHER AT 6678' SLM. PULLED SIO FROM STA# 1 AT 6547' SLM, SET DGLV AT SAME. RAN IN W 2.35" GAUGE CUTTER TO RATTLE POCKETS. RUNNING 3 1/2" SHIFTING TOOL AT REPORT TIME. 01/05/05 RAN LlBS TO ALL POCKETS. ATTEMPED MIT TWICE, STILL FAILED. RIG DOWN DUE TO HIGH WINDS. 01/06/05 RAN 3 Y2" BO SHIFTING TOOL, SAT DOWN AT 6608' SLM. JARRED DOWN TO OPEN SLEEVE, POOH, PIN NOT SHEARED, SLEEVE OPEN, DID C-MIT WI TRIPLEX. TBG-350 IA-500 OA-840, PRESSURED UP TBG- 3500 IA-3550 OA-840. NO PRESSURE CHANGE, FIRST 15 MIN, TBG-3510 IA-3525 OA-840 SECOND TEST. C-MIT PASSED, BLED DOWN TBG/IA TO 1000#. RDMO. 01/23/05 SET A 3" CIW BPV PRE RIG. BAIL 1/2 CUP SAND FROM TOP OF JUNK BASKET. 01/24/05 BAIL 2 GAL. SAND OFF TOP OF JUNK CATCHER. 01/25/05 BAILING SAND FROM TOP OF JUNK CATCHER. 01/26/05 PULL JUNK CATCHER FROM 6,665' SLM. BAIL 3 GAL. SAND OFF TOP OF PRONG. 01/27/05 PULL PRONG & PLUG, SET 3.5" XX PLUG W/PUMP OFF SUB (2600 +1- 10%) AT 6687' SLM, SET 3.5 WHIDDON AT 6686' SLM, PULL DGLV STA. # 1 AT 6549' SLM, (POCKET LEFT EMPTY) PULL WHIDDON. ) ) BP EXPLORATION. Operatiol1sSÚmm~ry.R~port Page.1.of3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 WORKOVER Start: Rig Release: Rig Number: 1/21/2005 Spud Date: 10/8/2002 End: 1/24/2005 Date From - To Hours Task .Code NPT Phase Description of Operations 1/27/2005 00:00 . 02:00 2.00 MOB P PRE Blow down steam and water lines in pits, disconect power and service lines to pits. Rig down, prep for move from L-Pad to V-pad. 02:00 - 03:30 1 .50 MOB P PRE Move pits from L- Pad to V- pad 03:30 - 05:00 1.50 MOB P PRE Pull sub off L-1 07 and position at Pad entrance. 05:00 - 08:00 3.00 MOB P PRE Load Camp & shop and move to V-Pad, spot camp and shop on V-Pad. 08:00 - 11 :00 3.00 MOB P PRE Rig down topdrive and bridle up, secure lines in derrick, prep floor to lay down derrick. 11 :00 - 12:00 1.00 MOB P PRE PJSM and lay down and secure derrick for move. 12:00 - 15:00 3.00 MOB P PRE Move sub from L-pad to V-Pad, Position sub for Tire and bridle line swap. Suspend operations on V-1 07, @ 15:00 hrs. 1/27/2005, Begin Rig maintenance AFE# ORD5M3568 1/31/2005 00:00 - 03:00 3.00 MOB P PRE Set mats and herculite, spot and level sub on V-107. 03:00 - 04:00 1.00 MOB P PRE Set mats for pits, spot same, set cuttings tank. Accept Rig @ 02:30 hrs 1/31/2005 04:00 - 04:30 0.50 RIGD P DECOMP Hookup mud, choke and service lines in pits. 04:30 . 07:00 2.50 RIGD P DECOMP Take on heated seawater in pits. Install secondary valve on lA, Rig up floor. 07:00 - 08:00 1.00 WHSUR P DECOMP Rig up DSM lubricator, pull BPV, rig down lubricator. Zero pressure on tubing and annulus. 08:00 - 09:00 1.00 WHSUR P DECOMP Rig up circulating lines to tree and cuttings tank, pressure test lines to 3,500 psi, 2" high pressure hose leaked. 09:00 - 12:00 3.00 WHSUR P DECOMP Blow down lines, replace hose, and re-test to 3,500 psi ok. 12:00 - 14:30 2.50 WHSUR P DECOMP Pump down annulus with 8.5 ppg heated seawater @ 3.5 bpm, 220 psi, displace 38 bbls diesel from tubing, switch over and pump 50 bbl soap pill down tubing @ 3.5 bpm, 240 psi, displace remaining diesel 109 bbls total diesel and contaminated seawater to cuttings tank. 14:30 - 15:00 0.50 WHSUR P DECOMP Monitor well for flow, zero pressure, blow down circulating lines. 15:00 - 15:30 0.50 WHSUR P DECOMP Set TWC and test from below to 1,000 psi 15:30 - 17:00 1.50 WHSUR P DECOMP Nipple down tree and adapter flange, inspect lifting threads. 17:00 - 19:30 2.50 BOPSUR P DECaMP Nipple up BOP, riser and mouse hole. 19:30 - 20:00 0.50 BOPSUR P DECOMP Rig up BOP test equipment. 20:00 - 00:00 4.00 BOPSUF P DECOMP Test BOPs and related equipmnet to 250 psi low, 3,500 psi high per Nabors testing procedure. Jeff Jones with AOGCC waived witness of BOP test. 2/1/2005 00:00 - 00:30 0.50 BOPSUP P DECOMP Test BOPS to 250 psi low, 3,500 psi high. 00:30 - 01 :30 1.00 BOPSUR P DECOMP Blown down lines, rig down test equipment. 01 :30 - 02:30 1.00 WHSUR P DECOMP Pickup lubricator extension and lubricator, pull TWC, rig down lubricator. 02:30 - 03:30 1.00 PULL P DECOMP Install short bails and 4" elevators thaw ice plug in IBOP on topdrive. 03:30 - 04:00 0.50 PULL P DECOMP Makeup landing joint and topdrive, shear pump out plug with 2350 psi, BOLDS. 04:00 - 07:30 3.50 PULL P DECOMP Unseat hanger with 100k work seal assembly out of PBR pulling max of 195k. worked seals 5-7' out of PBR unable to make any more progress, hole taking 120 - 130 bph. 07:30 - 08:00 0.50 ZONISO N DPRB INTERV Pump 30 bbl high vis pill @ 2bpm, 50 psi, while working seal assembly, no progress, continue lossing 130 bph. Printed: 2/7/2005 9:39:02 AM ) ) BPEXPLORA TION Operations Summary-Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 WORKOVER Date From-To Hours Task Code NPT Phase 2/1/2005 08:00 - 10:00 2.00 ZONISO N DPRB INTERV 10:00 - 12:00 2.00 ZONISO N DPRB INTERV 12:00 - 13:30 1.50 ZONISO N DPRB INTERV 13:30 - 14:00 0.50 ZONISO N DPRB INTERV 14:00 - 15:00 1.00 ZONISO N DPRB INTERV 15:00 - 18:00 3.00 DHB N DPRB INTERV 18:00 - 19:00 1.00 DHB N DPRB INTERV 19:00 - 20:00 1.00 DHB N DPRB INTERV 20:00 . 22:30 2.50 DHB N DPRB INTERV 22:30 - 23:00 0.50 EV AL N DPRB INTERV 23:00 - 00:00 1.00 EVAL N DPRB INTERV 2/2/2005 00:00 - 00:30 0.50 EV AL N DPRB INTERV 00:30 - 03:30 3.00 EVAL N DPRB INTERV 03:30 - 04:00 0.50 EV AL N DPRB INTERV 04:00 - 04:30 0.50 EV AL N DPRB INTERV 04:30 - 06:00 1.50 PULL P DECOMP 06:00 - 13:30 7.50 PULL P DECOMP 13:30 - 14:30 1.00 BOPSUP P DECOMP 14:30 - 22:30 8.00 CLEAN P DECOMP 22:30 - 23:00 0.50 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP Start: Rig Release: Rig Number: Spud Date: 10/8/2002 End: 1/24/2005 1/21/2005 Description of Operations Mix and pump 25 bbl high vis sweep @ 2 bpm, 50 psi. Monitor well for losses, loss rate 108 bph. Fluid lost in last 12 hrs = 776 bbls Fill hole from backside through secondary kill line, pumping @ 3 bpm, hole taking 132 bph. Unable to work seal assembly back down to land tubing hanger, hanger within 6" of being fully landed. Back out landing joint and XO. Make up 5" 20' pup joint, XO and TIW valve, test valve to 3,500 psi. make up to tubing hanger. Rig up Schlumberger slick line unit. RIH with GS retrieving tool to 6615' and pull pump out plug set in Sliding sleeve, POH with plug. Rig down slick line unit. Pull out Schlumberger slick line unit and spot Schlumberger E-line unit. Rig up Schlumberger E-line RIH with Halliburton composite Fasdrill bridge plug on E-line, correlate depth with CCl, logged up from 6,850' to 6,550' to confirm that seal assembly had moved 6'. Set bridge plug @ 6,758' set down on plug to confirm set, POH with setting tool. Losses for last 10.5 hrs = 1,090 bbls. Rig down Schlumberger sheeve, latch up to landing joint pickup on string to 125k, set slips, Rig up Sheeve, Make up string shot. RIH with string shot and set on depth @ 6615'- 6627', POH with string shot. POH with string shot, lay down same PJSM, handling chemical cutter, makeup chemical cutter, RIH tie in with CCl, cut tubing @ 6,625', positive indication that tubing cut, POH with chemical cutter. PJSM, handling chemical cutter, lay down chemical cutter, rig down sheeves, Latch onto landing joint, tubing pulled free with 160k, string weight 82k. Rig down Schlumberger, clear floor of all related tools. Pull hanger to floor, back out landing joint, lay down tubing hanger, rig up to lay down tubing. POH lay down 3.5" L-80 IBT-M completion equipment, layed down a total of 207 joints 3.5" tubing, 3 GLM's, 1 X Nipple, 1 Siding sleeve, 2 space out pups, 2' cut off stub. Rig up BOP test equipment, Test lower pipe rams to 250 psi low, 3,500 psi high, rig down test equipment, install wear ring. Make up Baker poor boy overshot, RIH picking up 3.5" 9.2# L-80 IBT-M tubing to 6,614' Make up head pin and cement hose, break circulation, 4 bpm @ 605 psi, wash down to top of tubing stub, no increase in pressure as overshot washed over stub, set down 6k sheared screws washed down 4' to no go, 6,636' pressure increased to 900 psi, Picked up 3' off stub. Pump 40 bbl high vis sweep surface to surface, 6 bpm 2 1,143 psi. shut down pumps, pulled above tubing stub, worked overshot back down to no go with out pumping, without problems. Printed: 2/7/2005 9:39:02 AM ) ) . BPEXPLORATION OpØrations SL.ni1mary Re.port Page 30f3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 WORKOVER Start: Rig Release: Rig Number: 1/21/2005 Spud Date: 10/8/2002 End: 1/24/2005 Date From ~To Hours Task Code NPT Phase Description of Operations 2/3/2005 00:00 - 08:30 8.50 CLEAN P DECOMP POH Lay down 3.5" 9.2# L-80 tubing, inspect threads and replace seal rings, lay down poor boy overshot. 08:30 - 09:00 0.50 CLEAN P DECOMP Service rig and topdrive. 09:00 - 10:00 1.00 RUNCOMP RUNCMP Pull wear ring, P/U landing joint and tubing hanger, make dummy run with hanger. 10:00 - 11 :00 1.00 RUNCOMP RUNCMP Change over to long bails. 11 :00 - 12:00 1.00 RUNCOMP RUNCMP PJSM, with Co Rep, Toolpusher, Baker Rep and rig crew. Make up and run poor boy overshot, X nipple assembly, Baker 5.5" x 3.5" SABL packer, X nipple assembly, baker-Ioc connections below packer. 12:00 - 21 :30 9.50 RUNCOMP RUNCMP RIH with 3.5" 9.2# L-80 completion equipment per running order, make up torque = 2,400 ftllbs, picked up joint #212 and #213, shear screws, bottom out on tubing stub, POH, lay down joints #213 - #211, pickup 9..80' space out pup and joint # 211 21 :30 - 22:30 1.00 RUNCOMP RUNCMP Make up Circulating head on joint # 211, pump 41 bbls clean 8.5 ppg seawater followed by 37 bbls seawater treated with inhibitor, followed by 58 bbls clean seawater @ 2 bpm, 245 psi. 22:30 - 23:00 0.50 RUNCOMP RUNCMP Make up landing joint and tubing hanger, land tubing, RILDS. Up weight = 90k, Dn weight = 82k 23:00 - 00:00 1.00 ZONISO P OTHCMP Drop 1 5/16" ball and rod, back out and lay down landing joint. 2/4/2005 00:00 - 01 :30 1.50 ZONISO P OTHCMP Pressure up on tubing to 4,500 psi to set packer, leak on kill line union, bled off and repair, pressure up to 4,500 psi held pressure for 30 min record on chart, Bled tubing pressure to 2,000 psi, pressure up on backside to 3,500 psi held for 30 min record on chart, bled annulus pressure to zero, bled tubing pressure to zero, pressure up to shear DCK shear valve, sheared at 2,300 psi, pumped 3 bbls through valve @ 3 bpm 11 00 psi. 01 :30 - 02:00 0.50 WHSUR P WHDTRE Install TWC and test from below to 1,000 psi. 02:00 - 04:00 2.00 BOPSUP P OTHCMP Nipple down BOP, and riser. 04:00 - 08:00 4.00 WHSUR P WHDTRE Nipple up adapter flange change out tree, test to 5,000 psi. 08:00 - 08:30 0.50 WHSUR P WHDTRE Rig up DSM lubricator, pull TWC. 08:30 - 10:00 1.50 WHSUR P WHDTRE Rig up Little Red, test lines to 2,500 psi, Freeze protect annulus and tubing to 2,000' with 45 bbls diesel, @ 2 bpm, 1500 psi. 10:00 - 11 :00 1.00 WHSUR P WHDTRE U- Tube diesel. 11 :00 - 12:00 1.00 WHSUR P WHDTRE Install BPV with lubricator, test from below to 1,000 psi, Rig down Little Red. 12:00 - 14:00 2.00 WHSUR P WHDTRE Remove secondary valve on IA install flange, clean cellar secure well. Release Rig From V-107 @ 14:00 hrs 2/4/2005 Printed: 2/7/2005 9:39:02 AM ') ) Well: Field: API: Permit: V -107 Rig W orkover Prudhoe Bay Unit 50-029-23108-00-00 202-155 Accept: Spud: Release: Rig: 01/31/05 N/A 02/04/05 Nabors 9ES POST RIG WORK 02/12/05 PULLED BALL & ROD AND STA # 2 DGLV. JOB IN PROGRESS. 02/13/05 PULLED 1" DUMMY GLV'S FROM STA #6 #4 & #3. PULLED SHEARED DCK FROM STA #5. INSTALLED DEEP DESIGN: SET LGLV'S IN STA #6 - 2699' SLM, STA #5 (DUMMY) - 3505' SLM, STA #4 - 4277' SLM, STA #3 - 5018' SLM, & SET OGLV IN STA #2 - 5745' SLM. PULLED 3 1/2" X-RHC FROM X NIPPLE AT 6642' SLM. 02/14/05 RIH WI 2.7" MILL. START PUMPING XS 1% KCL TO DISPLACE METH FROM CT. PRESSURE JUMPED TO 3500 PSI AFTER 9 BBLS IN. POOH. BREAK OFF TOOLS BELOW DUAL FLAPPER CHECKS. STAB BACK ON WELL. ATTEMPT TO PUMP METH TO TANKS. COIL FROZEN. PLACE HEATERS AND TARPS ON COIL TO THAW. THAW COIL. FLUSH COIL WI WATER/METH. MUIRIH W/2 118" MOTOR/2.7" FIVE BLADE MILL. 02/15/05 RIH WI 2.7" FIVE BLADE MILL. DRY TAG FASDRIL PLUG. BEGIN MILLING FROM 6754'. MILLEDI PUSHED PLUG TO 6981'. PIPE DIFFERENTIALLY STUCK. FREEZE PROTECT COIL. PUMP 60/40 METH DOWN BACKSIDE TO FREE CT. PU TO 6500' THEN RIH TO TAG PLUG. TAG AT 6952' CTMD. COULD NOT PUSH PLUG ANY FURTHER DOWN HOLE. RDMO. TREE = 3-1/8" 5M CIW '" WELLPI'EAD = 11" FMC .."..... .............. "....,. ..... ...... ACTUATOR= NA -_.,...,.""...'I,.~,.\"~.,,,,,,.,"" .... .... ..... . KB. ELEV = 82.2' "'",,,. ..,,,..,,......... ....., """..0" ....."... BF. ELEV = 53.50' .. ... .~.. . ............... KOP = 300' '.~~.~"A~g.ïe'; '..'2?~".~..~9~~:. Datum MD = 'Õãfum'i\lõ";' ..", ) 17-5/8" CSG, 29.7#, S-95, ID = 6.875" 1- 2784' 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 1-1 6639' I 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" 1-1 6630' 14-3/4" X 3-1/2" CSG XO, ID = 3.000" 1-1 6661' ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 1/2 6 6872-6910 Opn/Sqz 02/04/05 PBTD 1-1 13-1/2" CSG, 9.2#, L-80, .0087 bpf, ID = 2.992" 1-1 7418' 7317' V-107 J I I ~ l- I~ :J1¡ r-- i'l: r---1 f---J I I I I ----¡ ~ DA TE REV BY DATE 07/25/02 10/15/02 02/04/05 02/13/05 REV BY COMMENTS jdf Proposed Completion TWA Final Completion AM Tubing swap final completion RMHlPJC GL V C/O COMMENTS ~ )SAFETY NOTES: From DRlG~DRAFT 1019' 1-17-5/8" TAM Collar, ID = 6.875"1 1852' l-i 3-1/2" HES 'X' NIP, ID = 2.813" 1 ~ 6563' 6584' 6607' 6627' 6639' 6642' 6657' 6681' 6701' 6758' 6837' GAS LIFT MANDRELS TYÆ VLV LATCH KBG2-9 DMY INTG KBG2-9 DOME INTG KBG2-9 DMY INTG KBG2-9 DOME INTG KBG2-9 DOME INTG KBG2-9 SO INTG KBG2-9 DMY INTG PORT TRO DA TE 02/04/05 16 1697 02/13/05 02/13/05 16 1704 02/13/05 16 1692 02/13/05 24 02/13/05 02/04/05 ST MD TVD DEV 7 1995 1989 10 6 2695 2657 20 5 3490 3396 21 4 4256 4115 19 3 4991 4809 19 2 5712 5493 17 1 6508 6254 15 1-13-1/2" HSE "X" nipple with ID = 2.83" 1 1-15.5 x 3.5 Baker SABL Packer 2.78" ID 1 1-13-1/2" HSE "XN" nipple with ID = 2.75" 1 1-1 Baker "Poor Boy" Overshot with 3.96" ID 1 1-1 BKR LOC SEAL ASSY, ID = 3.00" 1 1-1 TOP OF BKR PBR, ID = 4.00" I IjBTM OF 3-1/2" BKR SEAL ASSY, ID = 3.00" 1 1-13-1/2" HES X NIP, ID = 2.813" I 1-13-1/2" HES X NIP, ID = 2.813" I 1-1 Halliburton FasDril plug,~ ~ ~ lø Cf$¿' 1-1 PUP JT W / RA TAG 1 jt 1 oz..U;.os labove TKUPC 7076' 1-1 PUP JT W / RA TAG 1 jt I I above TKUPA PRUDHOE BAY UNIT WELL: V-107 ÆRMIT No: 202-155 API No: 50-029-23108 SEC 11, T11 N, R11 E, 4835' NSL & 1789' WEL BP Exploration (Alaska) ;;l-'8 J~'~\- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021550 Well Name/No. PRUDHOE BAY UN BORE V-107 Operator BP EXPLORATION (ALASKA) INC MD 7428--/ TVD 7137 /'.~ Completion Date 12/28/2002~' Completion Status 1-01L --------- ------ REQUIRED INFORMATION Mud Log No Samples No --------- --------_._--~---- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, RES/AIT, DT/BHC, CNL, LDL, GR, Caliper, SP, MR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No ~---~-----~ -Erf C '1'1251 See Notes ~'D iA:)fr~ctional Survey I nd uction/Resistivity vOìrectional Survey Caliper log Log ~./ Log Log Log Log tÆD C Sonic Neutron Induction/Resistivity -11232 See Notes Log Density "ED e Las f 1765 Directional Survey I / ED e Las 11765 I nd uction/Resistivity v'ED e Las 1765 Neutron 25 Blu -_.__._-~-~-~------- Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01L )pd g ot1-~ .z API No. 50-029-23108-00-00 UIC N Directional surve~~_<>.~ (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Lr Received Comments 75 6944 Open 11/1/2002 LDWG edit of Runs 1 & 2 PEX AIT BHe logs 70 2794 Open 11/1/2002 0 7425 Open 75 6954 Open 75 6954 Open Sample Set Number Comments Platform Express / DSL T Platform Express / DSL T Platform Express / DSL T Platform Express / DSL T LDWG edit of PowerPulse and IMPulse data L 0 7428 Open 1 0/24/2002 25 Blu 108 7428 Open 1 0/25/2002 0 7428 Open 1 0/24/2002 2 Blu 2620 6960 Open 11/1/2002 25 Blu 70 2794 Open 11/1/2002 25 Blu 70 2794 Open 11/1/2002 25 Blu 70 2794 Open 11/1/2002 100 7428 Open 1 0/25/2002 Platform Express / DSL T DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021550 Well Name/No. PRUDHOE BAY UN BORE V-107 Operator BP EXPLORATION (ALASKA) INC MD 7428 TVD 7137 Completion Date 12/28/2002 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Y@ Chips Received? ~ Well Cored? Daily History Received? ~/N GIN Formation Tops Analysis Received? ~. ------------ ~---~------- Comments: --------_._~~ ~ Date: -~~~--~-~---~ Compliance Reviewed By: API No. 50-029-23108-00-00 UIC N )(J~~~~ .L L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service < <..~ 2. Name of Operator 4 t BP Exploration (Alaska) Inc. j j,:PfI~-pi,- j -_..~-'" r 3. Address ¡i 'I'Œ'~<'"<'~' $ 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ ,"-~~,j 50-029-23108-00 4. Location of well at surface;~"-""';"("--""_\""'¡¡ 9. Unit or Lease Name 4835' NSL, 1789' WEL, SEC. 11, T11 N, R11 E, UM X = 590512, Y = 5970082 Prudhoe Bay Unit At top of productive interval 538' NSL, 3059' WEL, SEC. 02, T11 N, R11 E, UM X = 589229, Y = 5971049 10. Well Number At total depth 625' NSL, 3192' WEL, SEC. 02, T11N, R11E, UM X = 589095, Y = 5971135 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Borealis Pool Plan RKB = 82.2' ADL 028240 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 10/8/2002 l 10/13/2002 . 12/2812002 NIA MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7428 7137 FT 7315' 7029 FT 1m Yes 0 No (Nipple) 2210' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, RES I AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, BHC Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 34" X 20" 91.5# H-40 Surface 108' 42" ,260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 I S-95 27' 2784' 9-7/8" 311 sx PF 'L', 200 sx Class 'G' 5-1/2Ux3-1/2" 15.5#/9.2# L-80 24' 7418' 6-3/4" 130sxClass'G',198sxClass'G' Classification of Service Well 7. Permit Number 202-155 303-019 V-107 AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD 6872' - 6910' 6603' - 6640' SIZE 3-1/2",9.2#, L-80 TUSING RECORD DEPTH SET (MD) 6657' PACKER SET (MD) N/A 25. MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED FP wI 78 Bbls Diesel Frac'd w/ 104,900# of 16/20 Carbolite 88,300# of Proppant left behind pipe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 7,2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-Bsl 1/7/2003 4 TEST PERIOD 486 Flow Tubing Casing Pressure CALCULATED Oll-Bsl Press. 24-HoUR RATE 28. CORE DATA Ù ~<~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiPsl~\. t GAs-McF 857 GAs-McF WATER-Bsl -0- WATER-Bsl CHOKE SIZE 176 I 64ths Oil GRAVITY-API (CORR) GAS-Oil RATIO 1,765 i''''' t I"~ ~ it!;,~,,- ~~ E No core samples were taken. & Form 10-407 Rev. 07-01-80 RHUMS BfL Gt-::: 'ì 0 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 2990' 2931' Ugnu M Sands 4082' 3952' Schrader Sluff N Sands 4331' 4187' Schrader Sluff 0 Sands 4503' 4349' Base Schrader / Top Colville 4898' 4720' HRZ 6647' 6388' Kalubik 6744' 6481' Kuparuk C 6856' 6588' Kuparuk S 6988' 6714' Kuparuk A 7104' 6826' Miluveach 7184' 6902' 31. List of Attachments: Summary of Daily Drilling Reports and Post Drilling Summary, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHUbble~~. ~ Title Technical Assistant Date 01.6[).n,"-~ V-107 202-155 303-019 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: James Franks, 564-4468 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: V-107 Common Name: V-107 Test Date 10/11/2002 Test Type LOT Test Depth (TMD) 2,784.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 2,740.0 (ft) AMW 9.70 (ppg) Surface Pressure 680 (psi) Leak Off Pressure (BHP) 2,061 (psi) Page 1 of 1 EMW 14.48 (ppg) ~ '--. Printed: 10/21/2002 8: 51: 14 AM ') " ) BP EXPLORATION Operations Summary Report Page 1 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/7/2002 Rig Release: 10/16/2002 Rig Number: 9ES Spud Date: 10/8/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 10/7/2002 12:00 - 17:00 5.00 RIGU P PRE Move sub base to V-107. Spot pit module and connect service lines. Spot cuttings tank, mud lab, MWD and geologist trailers. Accept rig at 17:00 hr on 7 Oct 2002 17:00 - 20:30 3.50 RIGU P PRE Receive water. Mix spud mud. Install spool and riser on 20" conductor. 20:30 - 21 :30 1.00 RIGU P PRE Service top drive and change out saver sub. Change out bails. 21 :30 - 22:00 0.50 RIGU P PRE Pre spud, safety and environmental meeting with all rig personnel. 22:00 - 00:00 2.00 DRILL P SURF Pick up 5" HWDP, jars and non-mag drill collars and stand in derrick. Pick up 9 7/8" bit, mud motor and BHA. 1 0/8/2002 00:00 - 00:30 0.50 DRILL P SURF Pick up 9 7/8" bit, mud motor and BHA and tag up at bottom of 20" conductor at 108'. 00:30 - 01 :30 1.00 DRILL P SURF Drill 9 7/8" directional hole from 108' to 263'. WOB 10. RPM 80. GPM 650. PSI 800. TO 500 Spud well at 00:30 8 Oct 2002. 01 :30 - 02:30 1.00 DRILL P SURF Rig up E-line. Run gyro survey. 02:30 - 16:00 13.50 DRILL P SURF Drill from 263' to 1658'. Start kick off at 300'. WOB 25. RPM 80. GPM 650. PSI 2340. TO 3000 AST=3.73 hrs ART=5.82 hrs Run gyro surveys at 263' and 727'. Rig down E-line and gyro. 16:00 - 16:30 0.50 DRILL P SURF Circulate hole clean. Reciprocate pipe and rotate at 110 rpm. 16:30 -19:00 2.50 DRILL P SURF POH. No hole problems. Change bit. 19:00 - 19:30 0.50 DRILL P SURF Service top drive, blocks and crown. 19:30 - 20:30 1.00 DRILL P SURF RIH. Taking weight intermittently. 20:30 - 21 :00 0.50 DRILL P SURF Wash last stand to bottom as precaution. Stage pumps up slowly to 650 gpm with 2400 psi. 21 :00 - 00:00 3.00 DRILL P SURF Drill from 1658' to 2123'. WOB 35. RPM 80. GPM 650. PSI 2540. TO 4700 AST=.77 ART=.84 10/9/2002 00:00 - 02:30 2.50 DRILL P SURF Drill from 2123' to 2794'. WOB 35. RPM 80. GPM 650. PSI 3000. TO 4700 AST=1.19 hrs ART=1.2 hrs 02:30 - 03:00 0.50 DRILL P SURF Circulate hole clean and condition mud. 03:00 - 05:30 2.50 DRILL P SURF POH for wiper trip. Hole swabbing on first stands. Back ream to 1748'. POH to 540' no swabing and no hole problems. 05:30 - 06:30 1.00 DRILL P SURF RIH. Hit obstruction at 2681'. Wash and ream to bottom with no problems. 06:30 - 07:00 0.50 DRILL P SURF Circulate hole clean and condition mud. 07:00 - 08:30 1.50 DRILL P SURF POH for logs. No hole problems 08:30 - 09:30 1.00 DRILL P SURF Stand back drilling BHA. 09:30 - 11 :00 1.50 DRILL P SURF PJSM with logging and rig crews. Rig up Schlumberger logging unit. 11 :00 - 15:30 4.50 EVAL P SURF Run logs PEX, Litho Density, Comp Neutron, Induction, Sonic and Gamma Rey from 2794'. 15:30 - 16:30 1.00 EVAL P SURF Rig down logging unit. 16:30 - 18:00 1.50 DRILL P SURF Lay down drilling BHA from derrick, mud motor, MWD, drill Printed: 10/21/2002 8:51 :21 AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/7/2002 Rig Release: 10/16/2002 Rig Number: 9ES Spud Date: 10/8/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 1 0/9/2002 16:30 -18:00 1.50 DRILL P SURF collars, HWDP and jars. . 18:00 - 20:00 2.00 CASE P SURF Rig up to run 7 5/8" casing. Install fill up tool, change out bails, make a dummy run with landing joint. PJSM with crew. 20:00 - 00:00 4.00 CASE P SURF Run 7 5/8" 29.7# BUT-M S-95 casing. Check floats and make up all all joints to torque mark. Install centralizers as per program. Top 2 jts L-80. 10/10/2002 00:00 - 00:30 0.50 CASE P SURF Run 64 joints 7 5/8" 29.7# BUT-M S-95 casing and 2 jionts 7 5/8" 29.7# BUT-M L-80 and hang off with shoe at 2784'. Top 2 jts L-80. 00:30 - 01 :00 0.50 CEMT P SURF Lay down fill up tool. Install cementing head, rig up lines. 01 :00 - 02:00 1.00 CEMT P SURF Break circulation and stage up pumps to 6 bpm. Circulate and condition mud, lower YP and vis. Reciprocating pipe. PJSM with Cementers and drilling crew. 02:00 - 04:00 2.00 CEMT P SURF Halliburton pump 5 bbl water, test lines to 3000 psi. Pump 5 bbl water, 75 bbl Alpha Spacer weighted to 10.5 ppg. Mix and pump PermaFrost L lead slurry, 230 bbl (350 sx) at 10.5 ppg, followed by Premium tail slurry, 41 bbl (216 sx) at 15.8 ppg. Displace with 124 bbl drilling mud with rig pumps at 8 bpm. 50 bbl cement return to surface. Bump plugs. Float held. CIP 03:45 9 Oct 2002 04:00 - 05:30 1.50 CEMT P SURF Rig down cement head and lines. Pull landing joint. 05:30 - 07:00 1.50 BOPSUR P PROD1 Nipple down 20" riser and spool. 07:00 - 08:00 1.00 BOPSURP PROD1 Install FMC GEN-5 Split head and test to 5000 psi. 08:00 - 10:30 2.50 BOPSUR P PROD1 Nipple up 135/8" 5000 psi BOP. 10:30 - 14:00 3.50 BOPSUR P PROD1 Test BOP and related equipment to 250 psi low and 4500 psi high. Test witness waived by Jeff Jones of AOGCC. 14:00 - 16:30 2.50 DRILL P PROD1 Pick up 4" drill pipe from shed and stand in derrick. 16:30 - 19:00 2.50 DRILL P PROD1 Make up new bit, pick up mud motor, MWD and drilling BHA. 19:00 - 21 :00 2.00 DRILL P PROD1 RIH with BHA to 2577' picking up 51 jts 4" drill pipe from shed. Tested Tam port collar to 1000 psi. OK. 21 :00 - 22:00 1.00 DRILL P PROD1 Circulate. Test casing to 3500 psi for 30 minutes. 22:00 - 23:00 1.00 DRILL P PROD1 Drill 7 5/8" casing float at 2699', cement in shoe track and float shoe at 2784'. 23:00 - 23:30 0.50 DRILL P PROD1 Drill out cement in rat hole and 20' of new hole to 2814'. 23:30 - 00:00 0.50 DRILL P PROD1 Circulate and change out drilling mud for new 9.7 ppg LSND mud. 10/11/2002 00:00 - 00:30 0.50 DRILL P PROD1 Perform Leak Off Test. EMW 14.5 ppg. Obtain benchmark for ECD of 10.5 ppg. 00:30 - 16:30 16_00 DRILL P PROD1 Drill from 2814' to 5001'. Back ream each connection. Pump 15 bbl high vis sweeps every 500' drilled. WOB 10. RPM 80. GPM 329. PSI 2630- TQ 3500 AST=0.85 hrs ART=7.89 hrs 16:30 - 17:00 0.50 DRILL P PROD1 Circulate hol eclean. Pump around high vis sweep. 17:00 - 18:30 1.50 DRILL P PROD1 POH to 7 5/8" casing shoe. Intermittent overpull of 25K for first 900'. 18:30 - 19:00 0.50 DRILL P PROD1 Circulate bottoms up. 19:00 - 19:30 0.50 DRILL P PROD1 Service top drive, blocks and crown. 19:30 - 20:30 1.00 DRILL P PROD1 RIH. Wash last stand to bottom as precaution. No fill. Printed: 10/21/2002 8:51:21 AM ) ) BP EXPLORATION Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/7/2002 Rig Release: 10/16/2002 Rig Number: 9ES Spud Date: 10/8/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 10/11/2002 20:30 - 21 :00 0.50 DRILL P PROD1 Circulate around a 15 bbl high vis sweep. Reciprocate and rotate pipe. 21 :00 - 00:00 3.00 DRILL P PROD1 Drill from 5001' to 5281'. Back ream each connection. Pump 15 bbl high vis sweeps every 500' drilled. WOB 10. RPM 80. GPM 329. PSI 2750. TO 3500 AST=0.18 hrs ART=1.02 hrs 10/12/2002 00:00 - 20:00 20.00 DRILL P PROD1 Drill from 5281' to 6967'. Back ream each connection. Pump 15 bbl high vis sweeps every 500' drilled. WOB 20. RPM 80. GPM 329. PSI 3050. TO 6000 AST=4.51 hrs ART=11.73 hrs 20:00 - 20:30 0.50 DRILL N DPRB PROD1 Partial loss of circulation. Stop drilling and pump Barfiber LCM to bit. Stage pump up to drilling rate with out further losses. Total 50 bbl mud lost. 20:30 - 00:00 3.50 DRILL P PROD1 Drill from 6967' to 7386'. Back ream each connection. Pump 15 bbl high vis sweeps every 500' drilled. WOB 20. RPM 80. GPM 329. PSI 3050. TO 6000 AST=O hrs ART=3.0 hrs 10/13/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Drill from 7386' to 7428'. Back ream each connection. Pump 15 bbl high vis sweeps every 500' drilled. WOB 20. RPM 80. GPM 329. PSI 3000. TO 6100 AST=O hrs ART=0.9 hrs 01 :00 - 02:00 1.00 DRILL P PROD1 Pump around high vis sweep. Circulate and clean hole. ECD 10.7 ppg. 02:00 - 03:30 1.50 DRILL P PROD1 POH to 7 5/8" casing shoe. Tight hole at 6890' with max over pull of 25K. 03:30 - 04:30 1.00 DRILL P PROD1 Slip and cut drilling line 40'. 04:30 - 05:00 0.50 DRILL P PROD1 Service top drive, crown and blocks. 05:00 - 06:30 1.50 DRILL P PROD1 RIH. Fill pipe at 5188'. RIH to 7334', fill pipe and break circulation. Stage pumps up to 329 gpm and wash to bottom. No fill. 06:30 - 07:30 1.00 DRILL P PROD1 Circulate to clean hole and condition mud. Pump around high vis sweep. ECD 10.6 ppg. 07:30 - 09:30 2.00 DRILL P PROD1 POH to 7 5/8" casing shoe. Tight hole at 6890' with max over pull of 25K. Monitor well at shoe. 09:30 - 10:00 0.50 DRILL P PROD1 Circulate two bottoms up volumes at casing shoe. Monitor well. 10:00 - 10:30 0.50 DRILL P PROD1 POH to BHA. 10:30 - 12:30 2.00 DRILL P PROD1 Lay down drilling BHA, Mud Motor, MWD and flex collars. Stand back HWDP. 12:30 - 20:00 7.50 EVAL P PROD1 Rig up Schlumberger E line logging unit. Run PEX/BHC Sonic. Logs unable to pass 6950'. Log up to 2784'. Rig down Printed: 10/21/2002 8:51 :21 AM ) ) BP EXPLORATION Operations Summary Report Page 4 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/7/2002 Rig Release: 10/16/2002 Rig Number: 9ES Spud Date: 10/8/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2002 12:30 - 20:00 7.50 EVAL P PROD1 logging unit. 20:00 - 20:30 0.50 EVAL P PROD1 Pick up clean out BHA. 20:30 - 21 :00 0.50 EVAL P PROD1 Service top drive and blocks. 21 :00 - 22:00 1.00 EVAL P PROD1 RIH to casing shoe. 22:00 - 22:30 0.50 EVAL P PROD1 Circulate bottoms up at casing shoe. 22:30 - 00:00 1.50 EVAL P PROD1 RIH with clean out BHA. Break circulation every 10 stands run. 10/14/2002 00:00 - 00:30 0.50 CASE P PROD1 RIH to 5100' with clean out BHA. Break circulation every 10 stands run. 00:30 - 01 :00 0.50 CASE P PROD1 Circulate bottoms up. No losses. 01 :00 - 01 :30 0.50 CASE P PROD1 RIH to 6950' unable to pass. Break circulation every 10 stands run. 01 :30 - 02:00 0.50 CASE P PROD1 Wash and ream through tight spot. 02:00 - 02:30 0.50 CASE P PROD1 RIH to 7336' with clean out BHA. 02:30 - 04:30 2.00 CASE P PROD1 Wash to bottom. No fill. Circulate and condition mud, pump sweep around and clean hole. Spot 50 bbl casing running lube pill on bottom. 04:30 - 05:30 1.00 CASE P PROD1 POH to 4900'. Tight hole at 6950', max over pull 25K. 05:30 - 06:30 1.00 CASE P PROD1 Circulate and spot 102 bbl Steelseal from botom of Schrader to 7 5/8" casing shoe. 06:30 - 08:30 2.00 CASE P PROD1 POH lay down 4" drill pipe. Monitor well at shoe. 08:30 - 09:30 1.00 CASE P PROD1 POH. Lay down clean out BHA and stand back 4" HWDP. 09:30 - 11 :30 2.00 CASE P PROD1 Ri gup to run casing. Make a dummy run with casing landing joint. 11 :30 - 13:30 2.00 CASE P PROD1 Make up 3 1/2" casing shoe track. Check floats. Run 21 joints 31/2" 9.2# L-80 BTC-M casing. 13:30 - 14:00 0.50 CASE P PROD1 Change out 3 1/2" handling tools. Rig up 5 1/2" casing running equipment and fill up tool. 14:00 - 17:00 3.00 CASE P PROD1 Make up cross over from 3 1/2" to 51/2" casing and run 5 1/2" 15.5# L-80 BTC-M casing to 7 5/8" casing shoe. Fill casing every joint, break circulation every 5 joints. 17:00 - 17:30 0.50 CASE P PROD1 Circulate bottoms up at casing shoe at 4 bpm with 550 psi. 17:30 - 19:30 2.00 CASE P PROD1 Run 5 1/2" 15.5# L-80 BTC-M casing to 3800'. Fill casing every joint, break circulation every 5 joints. 19:30 - 20:00 0.50 CASE P PROD1 Circulate bottoms up at 3800' at 4 bpm with 550 psi. 20:00 - 22:00 2.00 CASE P PROD1 Run 5 1/2" 15.5# L-80 BTC-M casing to 4900'. Fill casing every joint, break circulation every 5 joints. 22:00 - 22:30 0.50 CASE P PROD1 Circulate bottoms up at 4900' at 4 bpm with 475 psi. 22:30 - 00:00 1.50 CASE P PROD1 Run 5 1/2" 15.5# L-80 BTC-M casing, 125 joints run at end of tour. Fill casing every joint, break circulation every 5 joints. 10/15/2002 00:00 - 03:30 3.50 CASE P COMP Run total 161 Jts. 5.5" Casing. 03:30 - 04:00 0.50 CEMT P COMP RD Fill Up Tool. RlU Cement Head & Lines. 04:00 - 05:30 1.50 CEMT P COMP Break Circulation & stage up pumps to 4 BPM @ 570 psi. Reciprocate pipe while circ & cond mud. 150K UP - 108K DN- 05:30 - 07:00 1.50 CEMT P COMP With HOWCO: Pump 5 bbls. Water & test lines to 4000 psi. Pump 20 bbls. 108 ppg AlfaSpacer, Pump 55 bbls HOWCO, 12.5 ppg, SilicaLite Slurry. Batch mix and pump 41 bbls. 15.8 ppg, 'Premium' Slurry. All pumped @ 3.5 BPM. Drop latched Top & Bottom Plugs. Displace w/164 bbls sea water @ 3.5 BPM, slowing to 2 BPM prior to 3.5" XO. No losses throughout job. Bump Plug w/ 2000 psi. (500 psi. over final displacement pressure). Check Floats - OK. Reciprocated Throughuot Job. 07:00 - 08:00 1.00 CEMT P COMP RID Lines, valves & cement head. Break out landing Jt. Clear Printed: 10/21/2002 8:51 :21 AM ) ) BP EXPLORATION Operations Summary Report Page 5 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-107 V-107 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/7/2002 Rig Release: 10/16/2002 Rig Number: 9ES Spud Date: 10/8/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 10/15/2002 07:00 - 08:00 1.00 CEMT P COMP Floor. 08:00 - 08:30 0.50 CASE P COMP Set Pack off & R.1.l.D.S. Test to 5000 psi - OK. 08:30 - 09:00 0.50 RUNCOI\iP COMP M/U Hanger on Landing Jt. & Make Dummy run. 09:00 - 14:00 5.00 RUNCOI\iP COMP Run 3.5" Completion String to 4437'. 14:00 - 14:30 0.50 RUNCOI\iP COMP Test 3.5" X 5.5" Casing to 3500 psi fo 10 minutes. 14:30 - 17:30 3.00 RUNCOI\iP COMP Continue running 3.5" Completion String. While running tubing; Perform LOT on 7 5/8" X 5 1/2" Annulus. LOT = 13.9 ppg EMW- Inject 70 Bbls, 9.8 ppg. Mud. ICP = 587 psi. FCP = 822 psi. Freeze protect annulus w/ 38 bbls Diesel. 17:30 - 19:00 1.50 RUNCOI\iP COMP Space out seal assy. into PBR with two pup jts. M/U Hanger & landing Jt and verify space- out. 19:00 - 20:00 1.00 CHEM P COMP Reverse circulate 58 Bbls. clean sea water followed by 38 bbls sea water treated w/ corrosion inhibitor. 20:00 - 21 :00 1.00 RUNCOI\iP COMP Land Tubing Hanger. R.1.l.D.S. B/O Landing Jt. 21 :00 - 23:00 2.00 RUNCOI\iP COMP Test tubing to 4000 psi for 30 minutes. Bleed tubing to 2500 psi. & test Annulus to 4000 psi for 30 minutes. Bleed Annulus to 0 psi then bleed tubing to 0 psi. Pressure Annulus to 3200 psi to shear DCK valve. 23:00 - 00:00 1.00 BOPSURP COMP Install TWC. Test to 2800 psi. 10/16/2002 00:00 - 01 :30 1.50 BOPSUR COMP NO BOP stack. Set back & secure. 01 :30 - 03:00 1.50 WHSUR COMP NU adapter flange & tree. Test to 5000 psi-OK. 03:00 - 03:30 0.50 WHSUR COMP Pull TWC. 03:30 - 05:30 2.00 WHSUR COMP RU hot oiler. Test lines to 3000 psi-OK. Pump 78 bbls diesel down annulus, taking returns from tbg. Shut down & u-tube diesel to tbg. Blow down & RD lines. 05:30 - 06:00 0.50 WHSUR COMP Set BPV. Test f/ below to 1000 psi-OK. 06:00 - 07:00 1.00 WHSUR COMP Secure tree. Remove secondary annulus valves. Install blank flanges. Secure cellar. Release rig @ 0700 hrs 10/16/2002. Printed: 10/21/2002 8:51 :21 AM ) ) Well: Field: API: Permit: Date V-107 Prudhoe Bay Unit / Borealis Pool 50-029-23108-00 202-155 Accept: Spud: Release: Rig: 1 0/07/02 1 0/08/02 1 0/16/02 Nabors 9ES POST RIG WORK 12/24/02 SET "X" C-SUB. PULL DGLV'S FROM STA #1 & #3. 12/25/02 PULL DGLV FROM STA #2. SET LGLV'S IN STA'S #2 & #3. SET OGLV IN STA #1. DRIFT WI 2.5" DUMMY GUN TO TO @ 7261' SLM. WELL LEFT SHUT IN. 12/28/02 RAN JEWELRY LOG WITH PRESSrrEMP FROM TO (7284') TO 6400'. PERFORATED INTERVAL 6872'-6910' USING 2.5" GUNS WITH POWERFLOW 2506 BIG HOLE CHARGES. PERFORATED IN TWO RUNS. WELL LEFT SHUT IN. REQUIRES HOT TRTMNT TO POP. ~ 01/02/03 ATTEMPT TO HOT OIL IA TO POP WELL ONTO PRODUCTION. 5 BBLS OF METHANAL, 40 BBLS OF 1900 F DIESEL PUMPED DOWN IA. 01/06/03 PUMP 35BBLS METH AND 40BBLS DIESEL TO WARM UP WELL VIA IA. 01/13/03 ATTEMPT TO SET 3.5" X-CATCHER - RAN INTO PARAFIN. DRIFT W/2.2 CENT TO 1610'SLM, STOPPED DUE TO PARAFIN. NEED PUMP TRUCK - WILL BRUSH AND FLUSH AT LATER DATE. TURN WELL OVER TO DSO, DSO TO FLOW WELL. 01/21/03 JET TBG AND PERFS WI 150 DEG DIESEL WHILE TAKING RETURNS DOWN FLOWLINE. HEAVY PARAFFIN NOTED FROM 2200'-3000'. JET DIESEL TO 6950. NO PROBLEMS. POH JETTING HOT DIESEL. FREEZE PROTECT TUBING WITH 40 BBLS NEAT MEOH. FREEZE PROTECT FL WITH 5 BBLS 60/40. RDMO. PAD OPERATOR NOTIFIED THAT WELL REMAINS SI FOR PRE-FRAC WORK. 01/24/03 SET C-SUB - PULLED STA #1 (20/64 SIO INT LATCH) - PULLED STA #2 (16/64 TRO 1791 INT LATCH) - PULL STA-3 (16/641784 TRO) - SET BL-DGLV IN STA-3 & 2 - LOAD IA - SET BL-DGLV IN STA-1 - MITIA 3500# (PASS). BLEED IA TO 400# & FP FL - PULL CS. WELL LEFT SI FOR UPCOMING FRAC. LOAD IA & PT W/SLlCK LINE INT. PRESS. T/I/0=1050/1400/300. LOADED IA W/112 BBLS.D.C. HES SET DUMMY VALVE, PT IA TO 3500 PSI FOR 30 MIN., LOST 200 PSI, BUMPED UP TO 3500 PSI FOR 2ND TEST. GOOD TEST, NO PRESS. LOSS AFTER 30 MIN. RU TO FL FREEZE PROTECT FL W/5 BBLS 60/40 FINAL PRESS- T/I/O=420/480/300. 01/25/03 STATIC BOTTOM HOLE PRESSURE SURVEY. TAG PBTD @ 7262' MD. DEPTH CORRELATED TO SWS PERF RECORD DATED 28-DEC-2002. WELL SHUT IN 3 DAYS PRIOR TO LOG. LOG STATIC BHPrr @ 6764' MD (6500' TVD). 151.2 DEGF, 2925 PSI.! 6868' MD (6600' TVD). 152.8 DEGF. 2960 PSI.! 6973' MD (6700' TVD). 155.5 DEGF. 3001 PSI. LOG REPEAT STATION @ 6868' MD (6600' TVD). 154.3 DEGF. 2960 PSI, POOH. RDMO, LEFT WELL SHUT IN. NOTIFIED DSO OF WELL STATUS. JOB COMPLETE. V-107, Post Drilling Work Page 2 ) ) 01/28/03 FRAC'D C1-C4 PERFS 6872'-6910' WITH YF125LG SYSTEM AND 104.9 K# OF 16/20 CLlTE. NWBSO AT 75 BBLS OF 8 PPGA IN PERFS, 88.3 K# PROP BEHIND PIPE. MAX TREAT- 9157 PSI, AVG TREAT- 5608 PSI, LOAD TO RECOVER- 857 BBLS. LOST SMALL PIECE OF SEALING ELEMET AND ENTIRE DRIVE CUP (NOT METAL RING INSIDE), LOST CUP MAY STILL BE CIRCULAR IN SHAPE, SUGGEST SLlCKLlNE ATTEMPT TO GRAB IT. 16.7 K# (27 BBLS) SAND LEFT IN TBG/CSG, TOS AT SURFACE, NO FREEZE PROTECT IN TBG, HEATER ON WELLHEAD. 01/29/03 FISH MOST (ABOUT 80%) OF TREE SAVER ELEMENT (POST FRAC) AS DEEP AS 1300' WI 3-PRONG WIRE GRAB. RETRIEVE ICE/CARBOLlTE/RUBBER @ 680' AND 773' SLM WI 2-1/2", 2-1/4"PUMP BAILER'S. WELL LEFT SI. RIH WITH 2" JSN. HIT SAND AT -800'. CLEAN OUT TO 5810'. 01/30/03 CONTINUE FCO AFTER FRAC. CLEANED WELL OUT FROM 5810' TO 7100' CTMD. CLEANED OUT THRU PERF AREA WITH HEC GEL. LOSSES WERE UP TO 60% AFTER PERFS WERE OPENED UP. POOH, FREEZE PROTECT WELL TO 3000' WITH NEAT METH. LEAVE WELL SHUT IN. NOTIFY PAD OPERATOR OF STATUS. JOB COMPLETE. bp V-107 Survey Report - Geodetic Schlumberger Report Date: 13-0ct-02 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 307.320° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 f1 Structure I Slot: V.Pad / V-107 TVD Reference Datum: KB Well: V-107 TVD Reference Elevation: 82.200 ft relative to MSL Borehole: V-107 Sea Bed I Ground Level Elevation: 53.70 ft relative to MSL UWVAPI#: 500292310800 Magnetic Declination: +25.780° Survey Name I Date: V-107 / October 13, 2002 Total Field Strength: 57505.868 nT Tort I AHD I DDII ERD ratio: 76.551 ° /1841.60 ft / 5.166/0.258 Magnetic Dip: 80.771° ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: October 16, 2002 Location Lat/Long: N 701940.800, W 149 15 57.39~ Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5970081.570 ftUS, E 590511.600 ftUS North Reference: True North Grid Convergence Angle: +0.69121878° Total Corr Mag North .> True North: +25.780° Grid Scale Factor: 0.99990931 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970081.57 590511.60 N 70 1940.800 W 1491557.393 174.00 0.40 347.00 174.00 0.47 0.59 -0.14 0.23 5970082.16 590511.46 N 701940.806 W 1491557.396 300.00 1.04 158.10 299.99 -0.18 -0.04 0.19 1.14 5970081.53 590511.79 N 701940.800 W 1491557.387 363.00 1.94 157.00 362.97 -1.59 -1.55 0.82 1.43 5970080.03 590512.44 N 701940.785 W 1491557.369 456.00 2.93 158.90 455.89 -4.99 -5.22 2.29 1.07" 5970076.38 590513.95 N 701940.749 W 149 1557.326 546.00 3.48 156.20 545.75 -9.34 -9.86 4.22 0.63 5970071.76 590515.94 N 701940.703 W 1491557.269 639.00 3.78 155.80 638.56 -14.50 -15.24 6.62 0.32 5970066.41 590518.40 N 701940.650 W 149 1557.199 663.80 3.96 159.08 663.30 -15.95 -16.79 7.26 1.15 5970064.87 590519.06 N 701940.635 W 149 1557.181 754.73 3.51 162.84 754.04 -20.89 -22.38 9.20 0.56 5970059.30 590521.07 N 701940.580 W 149 1557.124 ~ 846.95 2.86 172.81 846.12 -24.80 -27.36 10.32 0.92 5970054.34 590522.25 N 701940.531 W 149 1557.091 940.61 2.37 183.24 .939.68 -27.52 -31.61 10.50 0.73 5970050.09 590522.48 N 701940.489 W 149 1557.086 1033.53 1.67 215.55 1032.54 -28.64 -34.63 9.61 1.41 5970047.06 590521.63 N701940.459 W1491557.112 1127.27 2.26 278.09 1126.24 -27.07 -35.48 6.98 2.24 5970046.18 590519.01 N 70 1940.451 W 1491557.189 1221.16 3.68 299.93 1220.00 -22.46 -33.72 2.54 1.91 5970047.89 590514.55 N 701940.468 W 1491557.318 1315.37 3.61 299.30 1314.02 -16.53 -30.76 -2.67 0.09 5970050.78 590509.30 N 701940.498 W 1491557.470 1408.85 3.58 306.53 1407.32 -10.70 -27.58 -7.58 0.49 5970053.90 590504.36 N 701940.529 W 1491557.614 1501.16 4.70 321 .80 1499.39 -4.15 -22.89 -12.23 1.69 5970058.53 590499.65 N 70 1940.575 W 1491557.750 1594.90 4.96 323.73 1592.80 3.45 -16.61 -17.01 0.33 5970064.76 590494.80 N 701940.637 W 149 1557.889 V-107 ASP Final Survey. xis Page 1 of 3 10/21/2002-2:47 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1685.24 4.61 319.49 1682.82 10.75 -10.70 -21.67 0.55 5970070.61 590490.06 N 70 19 40.695 W 149 15 58.025 1779.36 5.81 306.77 1776.55 19.21 -4.97 -27.95 1.76 5970076.26 590483.72 N 70 1940.751 W 149 1558.208 1872.51 7.42 304.13 1869.08 29.93 1.22 -36.70 1.76 5970082.35 590474.89 N 70 1940.812 W 149 1558.464 1965.59 9.62 309.35 1961 .13 43.71 9.53 -47.69 2.50 5970090.52 590463.80 N 70 1940.894 W 149 1558.785 2060.00 11.25 312.25 2053.98 60.77 20.72 -60.61 1.81 5970101.56 590450.75 N 70 1941.004 W 149 1559.162 2154.22 13.58 314.50 2145.99 80.90 34.66 -75.31 2.53 5970115.31 590435.89 N 70 1941.141 W 149 1559.591 2246.70 16.08 314.23 2235.38 104.39 51.20 -92.23 2.70 5970131.65 590418.77 N 70 1941.304 W 149 160.085 2340.00 18.61 312.63 2324.43 132.05 70.30 -112.45 2.76 5970150.51 590398.32 N 70 19 41 .492 W 149160.675 2433.51 21.01 310.35 2412.40 163.65 91.27 -136.20 2.70 5970171.18 590374.32 N 70 1941.698 W 149 161.369 2527.10 21.04 310.06 2499.76 197.18 112.94 -161.85 0.12 5970192.54 590348.42 N 701941.911 W 149 16 2.117 .~ 2620.20 20.72 311.23 2586.75 230.31 134.55 -187.03 0.56 5970213.84 590322.98 N 70 1942.123 W 149162.852 2713.20 20.54 311.21 2673.78 263.00 156.14 -211.67 0.19 5970235.13 590298.08 N 70 19 42.336 W 149 163.572 2731.70 20.47 311.40 2691.11 269.46 160.42 -216.54 0.52 5970239.35 590293.16 N 70 19 42.378 W 149 163.714 2796.43 21.21 311.67 2751.60 292.43 175.69 -233.78 1.15 5970254.41 590275.74 N 70 19 42.528 W 149 164.217 2889.67 22.36 311.86 2838.18 326.93 198.74 -259.59 1.24 5970277.15 590249.66 N 70 1942.755 W 149164.971 2983.33 22.51 313.07 2924.76 362.53 222.87 -285.95 0.52 5970300.96 590223.01 N 70 19 42.992 W 149 165.740 3076.56 21.95 313.56 3011.06 397.60 247.07 -311.62 0.63 5970324.84 590197.06 N 70 19 43.230 W 149 166.490 3169.00 22.23 314.60 3096.71 432.12 271.25 -336.59 0.52 5970348.72 590171 .80 N 70 19 43.468 W 149 167.219 3262.78 20.47 311.38 3184.05 466.08 294.55 -361.52 2.25 5970371.71 590146.58 N 70 19 43.697 W 149 167.947 3355.31 21.12 309.19 3270.56 498.88 315.78 -386.59 1.10 5970392.63 590121.27 N 70 19 43.906 W 149 168.678 3449.19 21.50 308.98 3358.02 532.98 337.29 -413.07 0.41 " 5970413.82 590094.53 N 70 19 44.117 W 149 169.452 3542.07 21.83 310.34 3444.34 567.24 359.17 -439.46 0.65 5970435.38 590067.88 N 701944.332 W 149 1610.222 3635.19 19.51 308.31 3531 .46 600.08 380.02 -464.86 2.61 5970455.92 590042.23 N 70 1944.537 W 149 1610.964 3728.21 19.37 310.16 3619.18 631.02 399.60 -488.84 0.68 5970475.21 590018.02 .N 70 1944.730 W 1491611.664 3821.40 19.32 312.10 3707.11 661.82 419.90 -512.09 0.69 5970495.23 589994.53 . N 70 19 44.930 W 149 16 12.343 .~. 3914.37 19.62 310.32 3794.76 692.73 440.31 -535.40 0.72 5970515.35 589970.97 N 701945.130 W 1491613.023 4007.86 20.08 310.96 3882.70 724.42 460.99 -559.49 0.54 5970535.74 589946.64 N 701945.334 W 1491613.727 4100.98 20.22 310.27 3970.12 756.45 481.87 -583.84 0.30 5970556.32 589922.04 N 701945.539 W 1491614.438 4195.58 19.01 313.66 4059.23 788.09 503.08 -607.46 1.76 5970577.24 589898.17 N 701945.748 W 149 1615.127 4288.12 19.10 313.24 4146.70 818.13 523.86 -629.40 0.18 5970597.75 589875.99 N 701945.952 W 149 1615.768 4380.78 19.48 314.57 4234.16 848.54 545.08 -651.45 0.63 5970618.71 589853.69 N 70 1946.161 W 149 16 16.411 4473.95 19.60 313.67 4321.96 879.48 566.78 -673.82 0.35 5970640.12 589831.06 N 701946.374 W 1491617.065 4567.21 19.51 313.19 4409.84 910.52 588.24 -696.49 0.20 5970661.31 589808.13 N 701946.585 W 149 16 17.726 4661.09 19.84 312.49 4498.24 941.98 609.73 -719.66 0.43 5970682.51 589784.70 N 701946.796 W 149 1618.403 4755.22 20.28 312.69 4586.66 974.13 631.58 -743.43 0.47 5970704.07 589760.67 N 70 1947.011 W 1491619.097 V-107 ASP Final Survey.xls Page 2 of 3 10/21/2002-2:47 PM ... ... - Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (°) n (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 4848.17 21 .43 314.67 4673.52 1007.01 654.44 -767.35 1.45 5970726.64 589736.48 N 701947.236 W 149 1619.795 4941.75 20.17 312.83 4761.00 1040.02 677.42 -791.34 1.52 5970749.34 589712.22 N 70 19 47.462 W 149 16 20.496 5033.96 18.15 305.49 4848.11 1070.21 696.58 -814.70 3.41 5970768.20 589688.63 N 701947.650 W 1491621.178 5127.50 18.24 305.15 4936.97 1 099.40 713.46 -838.53 0.15 5970784.80 589664.60 N 70 1947.816 W 1491621.874 5222.06 18.28 304.68 5026.77 1129.00 730.42 -862.83 0.16 5970801.46 589640.11 N 70 1947.983 W 149 1622.583 5315.74 18.23 303.93 5115.74 1158.30 746.96 -887.07 0.26 5970817.70 589615.67 N 701948.146 W 1491623.291 5410.27 18.40 304.40 5205.48 1187.96 763.64 -911.64 0.24 5970834.09 589590.90 N 701948.310 W 1491624.009 5503.43 18.20 304.94 5293.93 1217.18 780.28 -935.70 0.28 5970850.43 589566.64 N 70 1948.473 W 149 1624.711 5596.34 17.88 305.69 5382.27 1245.94 796.91 -959.18 0.43 5970866.78 589542.97 N 70 19 48.637 W 149 16 25.397 5689.20 17.41 305.02 5470.76 1274.07 813.20 -982.13 0.55 5970882.79 589519.82 N 701948.797 W 1491626.067 \~ 5783.90 16.56 304.17 5561 .33 1301.70 828.91 -1004.90 0.94 5970898.22 589496.86 N 701948.952 W 149 1626.732 5877.23 16.43 306.47 5650.82 1328.18 844.22 -1026.52 0.71 5970913.27 589475.06 N 701949.102 W 1491627.363 5969.86 15.50 304.51 5739.88 1353.64 859.02 -1047.26 1.16 5970927.82 589454.15 N 701949.248 W 1491627.968 6063.45 14.90 301 .67 5830.19 1378.11 872.43 -1067.80 1.02 5970940.97 589433.45 N 70 19 49.380 W 149 16 28.568 6156.43 15.66 301.27 5919.88 1402.48 885.22 -1088.70 0.83 5970953.51 589412.40 N 701949.505 W 1491629.178 6248.19 16.97 298.49 6007.95 1428.03 898.03 -1111 .06 1.66 5970966.05 589389.89 N 70 19 49.631 W 149 1629.831 6341 .22 20.08 296.81 6096.15 1457.16 911.72 -1137.25 3.39 5970979.42 589363.54 N 701949.766 W 1491630.596 6434.60 18.78 297.13 6184.21 1487.71 925.80 -1164.94 1.40 5970993.17 589335.69 N 701949.904 W 149 1631.404 6526.55 15.40 297.91 6272.09 1514.33 938.27 -1188.91 3.68 5971005.34 589311.57 N 701950.027 W 1491632.104 6619.10 16.69 297.70 6361.03 1539.56 950.20 -1211.53 1.40 5971017.00 589288.81 N 70 19 50.144 W 1491632.765 6713.30 16.84 298.60 6451.22 1566.38 963.02 -1235.49 0.32 5971029.53 589264.70 N 70 19 50.270 W 149 16 33.464 6806.87 16.27 299.97 6540.92 1592.78 976.05 -1258.74 0.74 5971042.28 589241 .29 N 701950.398 W 1491634.143 6900.13 16.77 300.61 6630.33 1619.10 989.43 -1281.64 0.57 5971055.38 589218.24 N 701950.530 W 149 1634.812 6993.46 17.02 301 .90 6719.63 1646.07 1003.51 -1304.82 0.48 5971069.17 589194.89 N 70 19 50.668 W 149 16 35.489 7086.23 16.33 302.34 6808.50 1672.58 1017.66 -1327.37 0.76 5971083.05 589172.17 N 701950.807 W 1491636.147 7180.40 15.89 303.84 6898.97 1698.64 1031.92 -1349.26 0.64 5971097.04 589150.11 N 701950.948 W 1491636.787 ~ 7275.63 15.54 304.89 6990.64 1724.39 1046.47 -1370.56 0.47 5971111.34 589128.65 N 701951.091 W 1491637.408 7367.62 15.54 305.73 7079.27 1749.02 1060.72 -1390.67 0.24 5971125.34 589108.37 N 701951.231 W 149 1637.996 7428.00 15.54 305.73 7137.44 1765.19 1070.17 -1403.80 0.00 5971134.63 589095.12 N 701951.324 W 149 1638.379 V-107 ASP Final Survey.xls Page 3 of 3 10/21/2002-2:47 PM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field....................: Borealis Well.....................: V-I07 API number...............: 50-029-23108-00 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.......: 53.70 ft KB above permanent.......: N/A DF above permanent.......: 82.20 ft ----- Vertical section origin---------------- La tit ude ( + N / S -) . . . . . . . . . : 0 . 0 0 f t 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: 309.47 degrees [(c}2002 Anadrill IDEAL ID6_1C_I0] 13-0ct-2002 05:59:24 Spud date. . . . . . . . . . . . . . . . : Last survey date.. ..... ..: Total accepted surveys. ..: MD of first survey.......: MD of last survey... .....: Page 1 of 4 7-0ct-02 13-0ct-02 82 0.00 ft 7428.00 ft ~ ----- Geomagnetic data ---------------------- Magnetic model.... .......: BGGM version 2001 Magnetic date............: 07-0ct-2002 Magnetic field strength..: 1149.66 HCNT Magnetic dec (+E/W-) .....: 25.91 degrees Magnetic dip. ...... ... ...: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.66 HCNT 80.77 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)... ..: 25.79 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 25.79 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N}........: No degree: 0.00 ~/ ANADRILL SCHLUMBERGER Survey Report 13-0ct-2002 05:59:24 Page 2 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 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 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 174.00 0.40 346.73 174.00 174.00 0.48 0.59 -0.14 0.61 346.73 0.23 GYR 3 300.00 1.04 158.11 126.00 299.99 -0.17 -0.04 0.19 0.19 102.68 1.14 GYR 4 363.00 1.94 156.96 63.00 362.97 -1.62 -1.55 0.82 1.76 152.28 1.43 GYR 5 456.00 2.93 158.89 93.00 455.89 -5.08 -5.22 2.29 5.70 156.32 1.07 GYR 6 546.00 3.48 156.27 90.00 545.75 -9.53 -9.87 4.22 10.73 156.86 0.63 GYR 7 639.00 3.78 155.82 93.00 638.56 -14.79 -15.25 6.61 16.62 156.57 0.32 GYR - ~ 8 663.80 3.96 159.08 24.80 663.30 -16.27 -16.79 7.25 18.29 156.65 1.15 MWD I FR MSA 9 754.73 3.51 162.84 90.93 754.04 -21.32 -22.38 9.19 24.20 157.68 0.56 MWD I FR MSA 10 846.95 2.86 172.81 92.22 846.12 -25.36 -27.36 10.31 29.24 159.35 0.92 MWD IFR MSA 11 940.61 2.37 183.24 93.66 939.68 -28.20 -31.62 10.49 33.31 161.64 0.73 MWD IFR MSA 12 1033.53 1.67 215.55 92.92 1032.54 -29.43 -34.64 9.60 35.94 164.51 1.41 MWD IFR MSA 13 1127.27 2.26 278.09 93.74 1126.24 -27.94 -35.49 6.97 36.17 168.88 2.24 MWD IFR MSA 14 1221.16 3.68 299.93 93.89 1220.00 -23.39 -33.72 2.53 33.82 175.71 1.91 MWD IFR MSA 15 1315.37 3.61 299.30 94.21 1314.02 -17.49 -30.76 -2.68 30.88 184.97 0.09 MWD IFR MSA 16 1408.85 3.58 306.53 93.48 1407.32 -11.68 -27.59 -7.59 28.61 195.38 0.49 MWD IFR MSA 17 1501.16 4.70 321.80 92.31 1499.39 -5.10 -22.90 -12.24 25.97 208.13 1.69 MWD IFR MSA 18 1594.90 4.96 323.73 93.74 1592.80 2.57 -16.61 -17.02 23.78 225.69 0.33 MWD IFR MSA 19 1685.24 4.61 319.49 90.34 1682.82 9.93 -10.70 -21.68 24.18 243.73 0.55 MWD IFR MSA 20 1779.36 5.81 306.77 94.12 1776.55 18.42 -4.98 -27.96 28.40 259.91 1.76 MWD IFR MSA 21 1872.51 7.42 304.13 93.15 1869.08 29.12 1.22 -36.71 36.73 271.90 1.76 MWD I FR MSA - - ~ 22 1965.59 9.62 309.35 93.08 1961.13 42.88 9.53 -47.70 48.65 281.29 2.50 MWD IFR MSA 23 2060.00 11.25 312.25 94.41 2053.98 59.97 20.72 -60.62 64.07 288.87 1.81 MWD IFR MSA 24 2154.22 13.58 314.50 94.22 2145.99 80.17 34.65 -75.32 82.91 294.71 2.53 MWD IFR MSA 25 2246.70 16.08 314.23 92.48 2235.38 103.75 51.20 -92.24 105.50 299.03 2.70 MWD IFR MSA 26 2340.00 18.61 312.63 93.30 2324.43 131.50 70.30 -112.46 132.62 302.01 2.76 MWD IFR MSA 27 2433.51 21.01 310.35 93.51 2412.40 163.16 91.26 -136.21 163.96 303.82 2.70 MWD IFR MSA 28 2527.10 21.04 310.06 93.59 2499.76 196.74 112.94 -161.86 197.36 304.91 0.12 MWD IFR MSA 29 2620.20 20.72 311.23 93.10 2586.75 229.91 134.55 -187.04 230.40 305.73 0.56 MWD IFR MSA 30 2713.20 20.54 311.21 93.00 2673.78 262.66 156.14 -211.68 263.04 306.41 0.19 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 13-0ct-2002 05:59:24 Page 3 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 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 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2731.70 20.47 311.40 18.50 2691.11 269.14 160.42 -216.55 269.50 306.53 0.52 MWD IFR MSA 32 2796.43 21.21 311.67 64.73 2751.60 292.15 175.69 -233.79 292.44 306.92 1.15 MWD IFR MSA 33 2889.67 22.36 311.86 93.24 2838.18 326.73 198.74 -259.60 326.93 307.44 1.24 MWD IFR MSA 34 2983.33 22.51 313.07 93.66 2924.76 362.42 222.87 -285.96 362.55 307.93 0.52 MWD I FR MSA 35 3076.56 21.95 313.56 93.23 3011.06 397.61 247.06 -311.63 397.68 308.41 0.63 MWD IFR MSA 36 3169.00 22.23 314.60 92.44 3096.71 432.26 271.25 -336.60 432.29 308.86 0.52 MWD IFR MSA 37 3262.78 20.47 311.38 93.78 3184.05 466.32 294.55 -361.53 466.33 309.17 2.25 MWD IFR MSA ~J 38 3355.31 21.12 309.19 92.53 3270.56 499.17 315.78 -386.60 499.17 309.24 1.10 MWD IFR MSA 39 3449.19 21.50 308.98 93.88 3358.02 533.28 337.29 -413.08 533.29 309.23 0.41 MWD IFR MSA 40 3542.07 21.83 310.34 92.88 3444.34 567.57 359.17 -439.47 567.57 309.26 0.65 MWD IFR MSA 41 3635.19 19.51 308.31 93.12 3531.46 600.43 380.02 -464.87 600.44 309.26 2.61 MWD IFR MSA 42 3728.21 19.37 310.16 93.02 3619.18 631.39 399.60 -488.85 631.39 309.26 0.68 MWD IFR MSA 43 3821.40 19.32 312.10 93.19 3707.11 662.24 419.90 -512.10 662.24 309.35 0.69 MWD IFR MSA 44 3914.37 19.62 310.32 92.97 3794.76 693.21 440.31 -535.41 693.21 309.43 0.72 MWD IFR MSA 45 4007.86 20.08 310.96 93.49 3882.70 724.95 460.99 -559.50 724.95 309.49 0.54 MWD IFR MSA 46 4100.98 20.22 310.27 93.12 3970.12 757.02 481.87 -583.85 757.02 309.53 0.30 MWD IFR MSA 47 4195.58 19.01 313.66 94.60 4059.23 788.73 503.07 -607.47 788.74 309.63 1.76 MWD IFR MSA 48 4288.12 19.10 313.24 92.54 4146.70 818.87 523.85 -629.41 818.88 309.77 0.18 MWD IFR MSA 49 4380.78 19.48 314.57 92.66 4234.16 849.39 545.08 -651.46 849.42 309.92 0.63 MWD IFR MSA 50 4473.95 19.60 313.67 93.17 4321.96 880.45 566.77 -673.83 880.50 310.07 0.35 MWD IFR MSA 51 4567.21 19.51 313.19 93.26 4409.84 911.59 588.23 -696.50 911.66 310.18 0.20 MWD IFR MSA - - ',-, 52 4661.09 19.84 312.49 93.88 4498.24 943.14 609.72 -719.67 943.23 310.27 0.43 MWD IFR MSA 53 4755.22 20.28 312.69 94.13 4586.66 975.38 631.57 -743.44 975.50 310.35 0.47 MWD IFR MSA 54 4848.17 21.43 314.67 92.95 4673.52 1008.38 654.43 -767.36 1008.53 310.46 1.45 MWD IFR MSA 55 4941.75 20.17 312.83 93.58 4761.00 1041.51 677.42 -791.35 1041.70 310.56 1.52 MWD I FR MSA 56 5033.96 18.15 305.49 92.21 4848.11 1071.71 696.57 -814.71 1071.90 310.53 3.41 MWD IFR MSA 57 5127.50 18.24 305.15 93.54 4936.97 1100.84 713.46 -838.54 1100.99 310.39 0.15 MWD IFR MSA 58 5222.06 18.28 304.68 94.56 5026.77 1130.38 730.42 -862.84 1130.48 310.25 0.16 MWD IFR MSA 59 5315.74 18.23 303.93 93.68 5115.74 1159.60 746.95 -887.08 1159.67 310.10 0.26 MWD IFR MSA 60 5410.27 18.40 304.40 94.53 5205.48 1189.18 763.64 -911.65 1189.22 309.95 0.24 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 13-0ct-2002 05:59:24 Page 4 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 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 5503.43 18.20 304.94 93.16 5293.93 1218.33 780.28 -935.71 1218.35 309.82 0.28 MWD IFR MSA 62 5596.34 17.88 305.69 92.91 5382.27 1247.03 796.91 -959.19 1247.04 309.72 0.43 MWD IFR MSA 63 5689.20 17.41 305.02 92.86 5470.76 1275.10 813.19 -982.14 1275.11 309.62 0.55 MWD I FR MSA 64 5783.90 16.56 304.17 94.70 5561.33 1302.66 828.91 -1004.91 1302.66 309.52 0.94 MWD IFR MSA 65 5877.23 16.43 306.47 93.33 5650.82 1329.09 844.22 -1026.53 1329.09 309.43 0.71 MWD IFR MSA 66 5969.86 15.50 304.51 92.63 5739.87 1354.50 859.02 -1047.27 1354.51 309.36 1.16 MWD IFR MSA 67 6063.45 14.90 301.67 93.59 5830.19 1378.88 872.42 -1067.81 1378.89 309.25 1.02 MWD IFR MSA ~< 68 6156.43 15.66 301.27 92.98 5919.88 1403.15 885.21 -1088.71 1403.17 309.11 0.83 MWD IFR MSA 69 6248.19 16.97 298.49 91.76 6007.95 1428.55 898.03 -1111.07 1428.61 308.95 1.66 MWD IFR MSA 70 6341.22 20.08 296.81 93.03 6096.15 1457.47 911.71 -1137.26 1457.60 308.72 3.39 MWD IFR MSA 71 6434.60 18.78 297.13 93.38 6184.21 1487.80 925.80 -1164.95 1488.02 308.47 1.40 MWD IFR MSA 72 6526.55 15.40 297.91 91.95 6272.08 1514.22 938.27 -1188.92 1514.55 308.28 3.68 MWD IFR MSA 73 6619.10 16.69 297.70 92.55 6361.03 1539.27 950.20 -1211.54 1539.71 308.11 1.40 MWD IFR MSA 74 6713.30 16.84 298.60 94.20 6451.22 1565.92 963.02 -1235.50 1566.48 307.93 0.32 MWD IFR MSA 75 6806.87 16.27 299.97 93.57 6540.91 1592.16 976.05 -1258.75 1592.84 307.79 0.74 MWD I FR MSA 76 6900.13 16.77 300.61 93.26 6630.32 1618.33 989.43 -1281.65 1619.13 307.67 0.57 MWD IFR MSA 77 6993.46 17.02 301.90 93.33 6719.63 1645.18 1003.50 -1304.84 1646.09 307.56 0.48 MWD IFR MSA 78 7086.23 16.33 302.34 92.77 6808.49 1671.58 1017.65 -1327.38 1672.59 307.48 0.76 MWD IFR MSA 79 7180.40 15.89 303.84 94.17 6898.97 1697.54 1031.91 -1349.27 1698.64 307.41 0.64 MWD IFR MSA 80 7275.63 15.54 304.89 95.23 6990.64 1723.23 1046.47 -1370.57 1724.40 307.36 0.47 MWD IFR MSA 81 7367.62 15.54 305.73 91.99 7079.26 1747.81 1060.72 -1390.68 1749.03 307.33 0.24 MWD IFR MSA - - ~ Projected to TD: 82 7428.00 15.54 305.73 60.38 7137.44 1763.96 1070.16 -1403.81 1765.20 307.32 0.00 Proj. [(c)2002 Anadrill IDEAL ID6_1C_10] bp January 21, 2003 ) ) .,. ,\,f.'". ~~~ ~~. ..-.- -~.. W~.....~. .'6'1'- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 . (907) 561-5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for V-1 07 Fracture Stimulation Program BP Exploration Alaska, Inc. proposes to fracture stimulate well V -107. Attached is the Fracturing procedure, which consists of 1500 bbls of water for /' diagnostics and fracturing with 200 Mlbs of 16/20 and 50 Mlbs of 12/18 CarboLite proppant. See pump schedule for details. The pump schedule is subject to change; fluid and proppant volumes should be adequate to address any contingencies. The procedure includes the following major steps: The procedure includes the following major steps: Category NaB STEP Description S 4500 1 Pull and dummy GLV. 0 4500 2 MIT IA /" 0 4500 3 Perform Data Frac & Frac. Shut-in. C 4500 4 FCO. Freeze protect. Shut-in. S 4500 5 Install GLV's. T 4500 6 Frac, Flowback, HOT tubing, Simultaneously POP. T 4500 7 Mobile Test Separator Test schedule. Last Test: Max Deviation: Perf Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S value: Reference Log: BHT & BHP: New Completion, never tested / 22° @ 2983' MD 17° @ 6954' MD 2.813" SSSVN at 2210' 7317' RKB MD New Well Static survey 0 ppm 12/02 Schlumberger PEX estimated 1580 F & 3200 psia @ 6600' TVDSS 1. Slickline ) ') a) Perforate and run static survey from prior programs before moving to this program. ~ b) Report well conditions. WHP, WHT, lA, OA. Production rate. Freeze Protect wellbore and flowline. c) Pull and dummy gas lift valves. d) Service Tree. 2. Fracture Treatment a) Load Frac tanks with - 100 of seawater; - 1500 bbls are required (excluding tank bottoms) . b) RU the tree-saver/isolation tool for 3Y2 "- 9.3 #/ft. tubing (see attached tubing detail). PT backside to 4000 psi and maintain 3500 psi throughout treatment (set /" inner annulus pop-off9t 4000psír-N te this well has a 10' floating seal assembly and maintenancefirl""2500 psi on .s required to stay in the PBR. Pressure test treating lines to 8500 ps' Nrtrogen pop-off valve at 7500 psig. Set pump trips afterwards to 7500 psi. This well is expected to treat at :t 6000 psi. It is recommended that 4 pumps be on location (1 backup). c) Breaker tests will be performed on fluids prior to frac. The breaker schedule will be designed to ensure fluid stability at end of pump time with complete break with-in one hour of shut down. A minimum of 100 cp @ 100 sec^-1 is required at shut down. d) Begin pumping Data Frac, initial rate will be 5 bpm while displacing wellbore fluid, /' after spotting Data Frac fluid a few feet above top perf increase rate to 25 bpm and displace data frac. Shut down for ISIP, monitor for closure time, calculate efficiency and re-design frac schedule as necessary (Pad size, fluid loss additive, etc.) e) Additional diagnostic tests may be performed after data frac analysis. Consult with engineer before proceeding with frac. f) Re-establish injection, when add rates are lined out start counting PAD. Pump the proppant schedule as detailed in the attached pump schedule. Flush with linear fluid. g) Bleed off excess annulus pressure. Rig down Service Company. 3. Post Fracture a) Perform CTU fill cleanout to original PBTD (-7076' MDRKB corr): / 1 Perform an overbalanced pressure fill clean-out, circulating gel and sand to a tank. A connection to a flowline will not be available. 2 Use filtered seawater to clean-out. If gel sweeps are required to clean-out, have lab verify that breaker loading is adequate to break polymer & mix water at 1500 F. 3 Freeze protect to 3000' with 50/50 diesel/ neat MEOH. a. Slickline to install gas lift design to lift from bottom. b. Shut-in pending frac flowback. 4. Frac Flowback ') ) a) As soon as possible flowback through portable flow-back separator: 1 For analog Kuparuk frac flowback, see L -110 & L -107 well files. 2 Kuparuk wells tend to hydrate-off, HOT oil IA with 100 bbls of hot diesel followed by 20 bbls of neat MEOH. Kick off well simultaneouslv with POP well. / 3 Expect FWHTs of 50 - 60°F and watercuts of 100°,,{, to begin with. Treat gas lift with methanol to prevent freezing. Attempt to quantify returned proppant flushed to tank. 4 Unload the well with 0.5 MMSCFGPD. 5 Conduct 4 hour well tests. If after 12 hours, solids are <0.10/0, then increase GL T to 1 MMSCFGPD. 6 Conduct 4 hour well tests. If after 12 hours, solids are <0.1 %, then increase GL T to 1.8 MMSCFGPD. 7 Do not surge well to flowback proppant. Surging could cause formation failure and sand production. 8 Continue producing to the flowback separator until the gel load has been recovered or watercut <10% and the solids production <0.1 %. g Schedule well bore for Pad Separator test. b) Place well on production at gas lift rate of 1.8 MMSCFPD, Place well on normal 15 day AOGCC required testing schedule. c) Service tree. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW @BP.com Sincerely, ~~~ Bruce W. Smith GPB Borealis Development Engineer J~ ') /' ) ~GÂ- M.~ ?J:f J I Z-l- lo"~ 01/ 1-vlo 3 1/<- Cf. jJ -3 '!ill STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: FRAC / Abandon- Suspend- Alter casing - Repair well- Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 445' FNL, 1789' FEL, Sec. 11, T11 N, R11 E, UM At top of productive interval 4739' FNL, 3063' FEL, SEC 02, T11 N, R11 E, UM At effective depth 4677'FNL,3160'FEL,Sec.02,T11N, R11E, UM At total depth 4654' FNL, 3192' FEL, See 02 T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Length 108' 2756' Surface Production 7390' Perforation depth: Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service- (asp's 590512,5970082) (asp's 589225, 5971052) (asp's 589127, 5971113) (asp's 589095,5971135) Re-enter suspended well - Time extension - Stimulate - X Variance - Perforate - 6. Datum elevation (OF or KB feet) RKB 82.2 feet 7. Unit or Property name // Other - Prudhoe Bay Unit 8. Well numbe~ V-107 /' 9. Permit number / approval number 202-155 --" 10. API number 50-029-23108-00 11. Field / Pool Prudhoe Bay Field / Borealis Pool Plugs (measured) TD Tagged @ 7284' (12/28/2002) 7428 feet 7137 feet 7284 feet 6999 feet Junk (measured) Size Cemented Measured Depth True vertical Depth 20" 260 sx Arctic Set (Aprox) 136' 136' 7-5/8" 350 sx PF 'l', 216 sx 2784' 2740' Class 'G' 55 bbls SilicaLite Class 5-1/2" x 3-1/2" 'G',41 bbls Class 'G' 7418' 7128' measured Open Perfs 6872'-6910' true vertical Open Perfs 6603'-6640' Tubing (size, grade, and measured depth 3-112",9.2#, L-80 TBG @ 6639' MD. Packers & SSSV (type & measured depth) Top of BAKER Packer @ 6642'. 3-1/2" HES X Nipple @ 2210' MD. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation / 15. Status of well classification as: January, 2003 16. If proposal was verbally approved Oil_X RECEIVED JAN 2 1 2003 AlasRaOil &Gas~1)ns. Commission - Anchorèlge BOP sketch - Gas- Suspended - Name of approver Date approved Service 17~ I hereby certify that the foregoing i~::; and COT' to the bes' of my knowledge. Questions? Can Bruce Smith, (907) 564.5093~ Signed {L~ / ~ Title: Borealis Development Petroleum Engineer Date January 21. 2003 Bruce Smith Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clßarance- Mechanical Integrity Test - Subsequent form required 10- Approved by order of the Commission ~;-~ . ':;'15 BFL Form 10-403 Rev 06/15/88 . 404 I Approval nO'3i-:Oj_--¿Y'i Commissioner JAN 2 7 20m Date e:> I / z-¥ /0 .s SUBMIT IN TRIPLICATE '. TREE = 3-1/8" 5M CIW WElLI-EAD = 11" FMC 'A CTÜÄrõlf;;--u ,mm ""NA ",^,,,,,,~,,,,,,,,,,^"......~,,,.,,,,,,,,..,,..,,,,,,,,,,,,,,^,,,.^.._.^..^"^"",,,^,^,,,,~^,,,,"^,,.~^,..^ KB. ELEV = 82.2' ,,,,,,,,,'''''''''''''''''''''''^''"^'''''''''''''''''''''''''''''''''''''^'''''''''W''''''''''''''''''''''''''''''''''''''''''''''^''''''''''''''''''''''''''' BF. ELEV = 53.50' KOP = 300' 'r;ífäX"'Ä¡:ïg'íe";""'''2~''''@''29ã3' "5atl;m"rvf6;"'~.'-"~'''''''~''''w""..,,, ,[)~:Ùürñ"T\FÕ";~«"""'''''~'''<>"''''''''''''''''<'<~''--«''''- 17-518" CSG, 29.7#, L-80, ID = 6.875" H 85' 1- 7-5/8"CSG, 29.7#, &95,ID= 6.875" 1--4 2784' r-J I 5-1/2"CSG,15.5#, L-80,BTC,ID=4.950" H 6630' ~ 3-1/2"TBG, 9.2#, L-80, .0087 bpf,lD =2.992" H 6639' 14-314" X 3-1/2" XO, ID = 3.000" H 6661' PERFORATION SlJ\¡11\t1A RY RS= LOG: SWS V ISION RES 10/07/02 ANGLEA TTOP PffiF: 16 @ 6872' f\bte: Refer to A"oductbn DB for historical perf data SIZ E SPF IN1£RV AL OpnlSqz DATE 2-1/2" 6 6872 - 6910 0 12/28/02 PB1D H 731T 13-1/2"CSG, 9.2#, L-80, .0087 bpf, ID =2.992" H 7418' [)6,TE 1 0/15/02 11108/02 12f25/02 12f28/02 RBI BY COM'v18\1TS DAC/KK ORßlNAL COM'LETION Ja=/tlh CSG CORRECTION JBltlh GL V C/O PWE/KK IPERF V-107 = I I L I I ') SAFETY NOTES: =-t 1019' -i7-5/8"TAM FQRTCOLLAR, ID =6.875" 2210' H3-1/2" I-ESX NIP, ID=2.813" I ~ ST rvD 3 3610 2 4667 1 6559 GAS LFT I\t1ANDRELS TVD DE\! TYPE VLV LATCH FQRf 3508 200 KBG2-9 DOME NT 16 4504 200 KBG2-9 DOME NT 16 6303 1 ßO KBG2-9 SO NT 20 DATE 12/25/02 12f25/02 12f25/02 6615' H3-1/2"BKROv1DSLDII\X3SLV,ID=2.813" I /" I 6639' HBKRLOC SEAL ASSY, ID= 3.00" ì \ :::. ~:::1~2~B:::;~:~Y. 10= &00" I 6681' H3-1/2" HES XNIP,ID= 2.813" 6701' H3-1f2" I-ESX NlP,ID =2.813" A DA 1£ REV BY COMIVENTS 6837' HpLP JT WI RA TAG I 707fj HpUPJTW I RA TAG PRLDHJE BA Y UNIT WELL: V-107 PERMIT No: 2021550 AA No: 50-029-23108 SEC 11, T11 N, R11 E, 4835' NSL & 1789' WEL BP Exploration (Alas ka) Schlum~ergel' Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-6711 ATTN: Beth Well Log Description Job # V-103 V-103 V-103 V~103 V.103 22476 OH EDIT PP, ARC & ADN LWD (PDC) 22476 MD VISION RESISTIVITY 22476 TVD VISION RESISÌlVITY 22476 MO VISION DENiNEUTRON 22476 TVD VISION DEN/NEUTRON dDd- 155 V-107 V-107 V-107 V-1Ó7 V-107 22474 OH EDIT PEX, AIT & BHC (PDC) 22474 PEX RESISTIVITY 22474 PEX SONIC 22474 PEX NEUTRON/DEN 22474 PEX CALIPER V-108 V-108 V-108 V-108 V-108 V-108 V-108 22468 OH EDIT MWD/GRlRES/DEN-NEUTRON (PDC) 22468 MD VISION RESISTIVITY 22468 TVD VISION RESISTIVITY 22468 MD VISION DENINEUTRON-QUADRANT 22468 TVD VISION DEN/NEUTRON-QUADRANT 22468 MD VISION-SERVICE 22468 TVD VISION-SERVICE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254~ " Date Delivered: U, ~ ~~ 10/01/02 10/01/02 10/01/02 10/01/Ó2 10/01/02 10/13/02 10/13/02 10/13/02 10/13/02 1 Ó/13/02 09118/02 09118/02 09/18/02 09/18/02 Ó9/18/02 09/18/02 09/18/02 NO. 2519 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date Borealis P.Bay Color Sepia BL SChlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Received by: 10/31/02 CD '-" ~/ RECEIVED NOV 0 1 2002 Alaska O¡i & Gas Cons. Commillion Anchorage Schlumbergol' Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth )~~ - ~... V.104 'Â,.'CP V.104 U. V.104 "'V-107 c:- V-107 \~~ V-107 (pod-' Well Job# Log Description 22424 OH EDIT MWD 22424 MD VISION GR 22424 TVD VISION GR 22475 OH EDIT POWERPULSE & IMPULSE 22475 MD VISION RESISTIVITY 22475 TVD VISION RESISTIVITY 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: RECEIVED OCT 2 5 2002 Alaska O¡~ & Gal Con£. Commileion And1Cnge 08/21/02 08/21/02 08/21/02 10/13/02 10/13/02 10/13/02 NO. 2509 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date Borealis P. Bay Color Sepia BL 10/24/02 CD -¡ . ~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Be~ . R.<ei-C; / ~cJbr~ I ~. ~ ) dDa-/55 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-107 Date Dispatche 16-0ct-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECEIV:D OCT 24 20J2 Alaska OK & Gas Cons. Commi88ion Anchorage Received By: ~ uJ>oo r~ 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 Re: V-I 07 Permit to Drill ) Subject: Re: V-I07 Permit to Drill Date: Thu, 03 Oct 2002 10:29:16 -0800 From: Winton Aubert <Winton_Aubert@admin.state.ak.us> Organization: AOGCC To: "Crane, Lowell R" <CraneLR@BP.com> I hope they raised down a window so the air can equalize. AOGCC hereby approves 4000 psi BOPE test pressure on your proposed well V-107 (PTD 202-155). All other permit stipulations apply. Winton Aubert AOGCC 793-1231 "Crane, Lowell R" wrote: > winton, > > I know you've communicated with James Franks recently concerning BOP test > pressures for N9ES on our Borealis wells. > > V-107 was permitted a couple months ago before we changed our view on frac > pressure loads and to what pressure our production casings needs to be > tested. For wells with planned fracture stimulations, we were testing to > 4500 psi and we have changed that requirement to 4000 psi based on actual > pressure data observed during the stimulations. We use this pressure to > determine our BOP test pressure because it is the "worst case" load in terms > of burst pressure for the well. > > The V-107 APD proposed a BOP test pressure of 4500 psi. We'd like to amend > that to 4000 psi. There was some confusion on this issue as the approved > permit that we received 7-31-02, did not have a BOPE test pressure indicated > in the "Conditions of Approval." > > Please advise. > > LRC > > PS I hear your relatives are re-sprouting gills there in So La. They are > huddled up side-by-each waiting on that blow to pass. f " ) ..\tAfI. bp ..........~...''''~~. ~..- ~~ ..~ ~...... .",~\. ) To: Winton Aubert, AOGCC Date: Sept. 25, 2002 From: J ames Franks ~D 'l ~, 1St; 7/3//01.. Subject: Dispensation for 20 AAC 25.035 (c) on V-t07 - already permitted BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the Borealis/Kuparuk wells at L-pad or V -pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All of the Borealis Development were drilled to the shale underlying the SVl sands. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is :1:200' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. V-I03 is planned to reach a 9.5 ppg mud weight before TD at -2,778' TVDss. This request is being made based on V-Pad data submitted regarding mud weight, surface open hole logging in the Borealis development (PEX/Dipole sonic), and a meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. Sincerely, ~ GPB Rotary Drilling Engineer 564-4468 RI€EfVED SEP 2 7 2002 Alaska 01& Gas Qons. Commission Anchorage Borealis Suñace Hole Mud Weight MW (ppg) 9 ) 8 0 8.5 x 500 1000 I I I .-. .c ~ 1500 c > I- ~ .c ...... 2- 2000 c 2500 3000 i I ....... L -01 . L -116 ):( Pore Pressure . L-107 - --. L-104 L-120 L-1 09 -_.-?'~~- L-1 08 ) 9.5 10 \ x *-L-110 --L-106 L-102 --- L-103 II-L-114 . L-115 L-119 L-105 Page 1 Borealis Suñace Hole Mud Weight MW (ppg) 9 ) ,. ,,. 8 0 i i I i i i 8.5 500 1000 .-.. .c ~ 1500 c > I- --- .c: Co 2000 Q) c 2500 I 3000 3500 9.5 10 [-+-V-101 ~Pore Pressure --*-V-102 V-106 ---- V-104i I ') -J ~~!Æ:E ]~ !ÆlfÆ~í fÆ AI,ASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Sr. Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit V-I 07 BP Exploration Alaska, Inc. Permit No: 202-155 Surface Location: 4835' NSL, 1789' WEL, Sec. 11, T11N, RIlE, UM Bottomhole Location: 661' NSL, 3131' WEL, Sec.02, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above development well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~1 dk/u'~,~OJ Ca~chsli Tayl~rO Chair BY ORDER OF THE COMMISSION DATED this~ day of July, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. 1 a. Type of work II Drill D Redrill D Re-Entry D 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 4835' NSL, 1789' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 599' NSL, 3057' WEL, SEC. 02, T11 N, R11 E, UM At total depth 661' NSL, 31311 WEL, SEC. 02, T11N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well It ADL 028241,2148' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications SIze Hole Casing WeiQht Grade CouDlina 42" 34" x 20" 91.5# H-40 Weld 9-7/8" 7-5/8" 29.7# L-80 BTC 6-3/4" 5-1/2" 15.5# L-80 BTC-M 6-3/4" 3-1/2" 9.2#' L-80 IBT-M i) STATE OF ALASKA .", ALASKÄ~ AND GAS CONSERVATION COMMdION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory D Stratigraphic Test II Development Oil D Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 82' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undofinod}¿n:r ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number V-107 / 9. Approximate spud d~ 08/12/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 73611 MD 170781 TVD 0 17. Anticipated pressure {,e 20 AAC 25.035 (e) (2)} 19 Maximum surface 2581 psig, At total depth (TVD) 6730' 13255 psig Setting Depth TQp Bot:om MD TVD MD TVD Surface Surface 110' 110' Surface Surface 2716' 2682' Surface Surface 6751' 6489' 6751' 6489' 7361' 7078' ~'A 7/27/0 L ~-7/~~ 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Length 80' 2716' 8200' 746' Quantity of Cement (include staQe data) ,260 sx Arctic Set (Approx.) 335 sx PF 'L', 200 sx Class 'GI 125 sx Class IGI, 166 sx Class IG' (5-1/2" x 3-1/2" 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 RECEI\/ED JUL 26 2002 true vertical Alaska Oil & Gas Cons. Comrmssion Anchorage Perforation depth: measured II Filing Fee D Property Plat D BOP Sketch D Diverter Sketch II Drilling Program II Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report D 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ja s Franks, 564-4468 Prepared By Name/Number: Terrie Hubble, 564-4628 ,21.1~:~~Y :::;~:;:~~{;~¿~~~~:t::¡~:;£~~~t:.k:~k;'~ Da~e 7-) ~ -. o~ Permit Number API Number Approv~1 D~te See cover letter 2- ð 2 - /- {"". ç 50- 02. f - ..2. 3 / ð r "1/-; I/° ~ for other reQuirements Conditions of Approval: Samples Required DYes 181 No Mud Log Required D Yes ~ No 4; Hydrogen Sulfide Measures DYes I)lNo Directional Survey Required fBI Yes DNa W Required Working Pressure for BOPE D 2K, D 3K D 4K D 5K D 10K D.} 5K D 3.5K psi for CTU ~ Other:'T~-S+ -r..O?F 'f:¿; ~p'-i - p~ý 1.oAAC l.5',"~~(k.}l¿J I ~v'Wteÿ" ~~'\.AÁN. ~~~t i::G 0nglnaISígn~By '-fOO~6A- 101-s10L by order of / w;ved. . Approved By Cammy Oechsll Taylor \ c,~i1n~!,-,.~ ~ ~N:' t~ ,ommission Date ,1 ~l Ó ~ 'llllJ Form 10-401 Rev. 12-01-85 V I \ l) i i .. Ii L Submit Ih Triplicate 20. Attachments I~ -J IWell Name: IV-107 Drill and Complete Plan Summary r Type of Well (service 1 producer 1 injector): 1 Producer Surface Location: As-Staked Target Location: Top Kuparuk Bottom Hole Location: x = 590,511.44' Y = 5,970,081.41' 4835' FSL (445' FNL), 1789' FEL (3490' FWL), Sec. 11, T11 N, R11 E X = 589,230' Y = 5,971,110' 599' FSL (4681' FNL), 3057' FEL (2222' FWL), Sec. 02, T11 N, R11 E X = 589,155.22' Y = 5,971,171.30' 661' FSL (4618' FNL), 3131' FEL (2148' FWL), Sec. 02, T11N, R11E I RiQ: I Nabors 9ES / I AFE Number: 15M4053 I Estimated Start Date: 18/12/2002 1 I MD: 17361' I TVD: 17078' 1 I OperatinQ days to complete: 113.3 1 BF/MS: 153.5' I I RKB: 182.0' I Well DesiQn (conventional, slimhole, etc.): 1 Microbore (Iongstring) I Objective: 1 Kuparuk Formation Mud Program: 9-7/8" Surface Hole (O-2716'): Initial below Permafrost interval TD Densitv Viscosity (ppg) (seconds) 8.5 - 8.6 300 9.3 - 9.5 200- 250 9.6 max /' 200 - 250 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) - 50-70 15-20 8.5-9.5 30-45 15-20 8.5-9.5 30 - 45 15 - 20 8.5 - 9.5 6 %" Intermediate 1 Production Hole (2716' - 7361 '): Interval Density Tau 0 YP PV (ppg) 9.7 Upper Interval Top of HRZ 4-7 20-25 8-12 pH 8.5-9.5 Fresh Water LSND API HTHP Filtrate Filtrate 4-6 10.0 /1 4-6 20-25 8-14 8.5-9.5 3-5 <10 by HRZ V-107 Drilling Permit Page 1 -) -J Hydraulics: Surface Hole: 97/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1782' 550 4" 17.5# 130 1600 10.2 N/A 18,18,18,16 .942 1782' -2716' 600 4" 17.5# 150 2600 10.4 N/A 18,18,18,16 .942 Production Hole: 6 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2716' -6670' 330 4" 17.5# 210 1700 - 2200 10.0 N/A 14,15,15 .495 6670' -8,946' 275 4" 17.5# 200 2200 - 2800 11.1 N/A 5x12 .552 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-2716' Su rface Superior hole cleaning practices at to SV-1 connections will greatly enhance cuttings transport particularly in sliding mode 210 60 500 9.5 Acceptable 250 60 600 9.5 Acceptable 300 60 700 9.5 Acceptable 250 90 500 9.5 Acceptable 315 90 600 9.5 Acceptable 300 90 700 9.5 Acceptable 2716'-4800' To Base ROP's greater than 400'/hr must be Schrader accompanied by a GPM of 330 and fully reamed connections to maintain minimum hole cleaning requirements 250 80 330 9.7 Marginal 250 100 330 9.7 Acceptable 300 80 330 9.7 MarginaVPoor 300 100 330 9.7 Marginal/Manageable 400 80 330 9.7 Very Poor 400 100 330 9.7 Poor 4800'- TD Base ROP's greater than 200'/hr must be Schrader accompanied by maximum pump rates toTD and fully reamed connections to maintain minimum hole cleaning requirements 150 80 330 10.0 Acceptable 200 80 330 10.0 Marginal V-107 Drilling Permit Page 2 Directional: Ver. Anadrill P2 Slot NJ KOP: 300' Maximum Hole Angle: Close Approach Wells: Survey Program: Logging Program: Surface Production Hole Formation Markers: Formation Tops SV6 SV5 Base Permafrost SV4 SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (Na sands) WS1 (Oa sands) Obf Base CM2 (Colville) CM1 THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TMLV (Miluveach) TD Criteria V-107 Drilling Permit ~ -J 19 degree~ at 2381' MD All Wells Pass Major Risk Criteria Require a Gyro on the first 1000' or until surface interference clears up. Standard MWD surveys (IFR+MSA Correction) Drilling: Open Hole: Cased Hole: None Drilling: MWD I GR I PWD Open Hole: e-line PEXlBHC Sonic, Gas Detection, Cuttings samples Cased Hole: USIT cement evaluation (contingency) MWD I GR TVDss 880' 1575' 1700' 1705' 2080' 2260' 2575' 2895' 3230' 3635' 3885' 4130' 4295' 4655' 5051' 5674' 6221' 6405' 6455' 6540' 6540' 6620' 6730' 6815' Estimated Pore Pressure Hydrocarbon Bearing, 8.5 ppg Hydrocarbon Bearing, 8.5 ppg Hydrocarbon Bearing, 8.5 ppg Hydrocarbon Bearing, 8.5 ppg Hydrocarbon Bearing, 9.3 ppg \°.0 150' below Miluveach top Page 3 ---) -J CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tba O.D. MDITVD MDITVD bkb 42" Insulated 91.5# H-40 WLD 80' GL 11 0/11 0 34"x20" 9-7/8" 7 5/8" 29.7# L-80 BTC 2716' GL 2716'/2682' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 8200' GL 6751 '/6489' 6-3/4" 3-1 /2" 9.2# L-80 IBT-mod 746' 6751 '/6489' 7361/7078' Tubing 3-1/2" 9.2# L-80 I BT -mod 8200' GL 6751 '/6489' Integrity Testing: Test Point Depth Test Type EMW Su rface Casing Shoe 20' min from LOT 12.7 ppg (minimum for a su rface shoe 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 Na sands with 1000 psi ultimate compressive strength and covering the entire Kuparuk interval with 2000 psi/24 hours compressive strength cement. Casinq Size 17-5/8" Surface I Basis: Lead: Based on 1782' of annulus in the permafrost @ 2500/0 excess and 184' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead Toe: To surface Tail: Based on 750' MD open hole volume + 300/0 excess + 80' shoe track volume. Tail TOe: At -1966' MD (1960' TVDbkb) Total Cement Volume: Lead 248 bbl I 1391fe 1335 sks of Halliburton Permafrost L at 10.7 ppg and 4.44 cf/sk. Tail 41 bbl I 230 fe I 200 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk. Casing Size 5-1 12"x3-1 12" Production Longstring Basis: Lead: Based on TOe 500' above the top of the Schrader Bluff Na formation + 30% excess and base of cement 500' above top of Kuparuk formation. Tail: Based on TOe 500' above top of Kuparuk formation + 300/0 excess + 80' shoe track volume. Total Cement Volume: Lead 52 bbl I 292ft~ I 125sks of Halliburton Premium 'G' at 12.5 ppg and 2.34 cf/sk. Tail 34 bbl I 191 ft~ I 166 sks of Halliburton Premium 'G' (KUP Latex Design) at 15.8 ppg and 1.15 cf/sk. V-107 Drilling Permit Page 4 ~) ~ Well Control: / Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future 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: l.3 ppg EMW (3255 psi) @ 6730' TVDss - KUP-A . Maximum surface pressure: 2581 psi @ surface (based on 3255 psi at TKUP and a full column of gas @ 0.10 psi/ft) / . Planned BOP test pressure: 4500 psi (for future frac stimulation treatments) . Planned completion fluid: 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-107 Drilling Permit Page 5 ~ -J DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor to be installed July 2002. 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. V-201is the closest well on surface and will need to be shut in at the surface prior to the rig moving on. Rig Operations: 1. MIRU Nabors 9ES on SlotyJ. 2. Nipple up diverter spool and riser. Function test diverter. PU 5" DP as required and stand back in derrick. 3. MU 97/8" drilling assembly with MWD/LWD (see page 4) and directionally drill to surface hole TD. 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. Run and cement the 7-5/8", 29.7# surface casing back to surface. A Tam port collar will be run as a contingency on the chance that cement returns are not seen at the surface. / 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4500 psi. 6. MU 6-3/4" drilling assembly with MyYD/LWD (see page 4) and RIH to float collar. Test the 7-5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below 7- 5/8" shoe and perform Leak Off Test. 8. Drill to :t200' above the HRZ, ensure mud is condition to 10,0 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./ 9. Perform open hole logging program. PEX/BHCSonic (e-line conveyed). If the logging run is unsuccessful on the first e-line attempt, the logs are to be run on drill pipe. 1 O. Condition hole for running longstring and POOH. This step may be done when pulling the drill pipe out after reaching TD at the Company Representatives discretion. 11. Run and cement the tapered production casing as required from TD to 500' above the Schrader. Displace the casing with heated filtered seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test bel9w the 7 5/8" shoe. Record on chart and submit to town.) 12. Test the casing to 4500 psi for 30 min. / / 13. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. Circulate 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. 14. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 15. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to reach the lower GLM. 16. Rig down and move off. V-107 Drilling Permit Page 6 ~ ~ V-107 Hazards and Contingencies 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 all times. ~ The closest surface location will be V-201. V-107 will be -15' wellhead to wellhead. The well is on production and will require a surface shut-in during move in. ~ Check landing ring height on V-107, the BOP/Diverter nipple up may need review. Reference RPs .:. uDrillingl Work over Close Proximity Surface and Subsurface Wells Procedure" ~~~W'J"......-_..... Job 2: DrillinQ Surface Hole Hazards and Contingencies ~ No faults are expected to be penetrated by V-107 in the surface interval. ~ Drilling Close Approach: The nearest well is V-201 which will have a center-center distance of approximately 15' at the surface ~ 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 .:. IIPrudhoe Bay Directional Guidelines" .:. IIWel1 Control Operations Station Bill" ~ff~,~ff1>,m1Þ,~m fflfflrrfflf.iJ9!:;....~,~"ff~'t~}.... ,':~>~mw~~~%1~~~'\.~~ffl1'ffl j;:jr>«ffm~""S.>.¡,..~:.'$~',..:*m1"w"",..w;."~ffl11'>,~%,,ffor»ff,~1i,')",,,,,:'t'....:,~~,,',',',',','>W%:::,*,~>~,,,,,,.,,,y~,,.~'>9';>~\)¡'»W,'\."""-'vÑJ»".¡;,.~....~';':,.;::fflr>ffý,1>i<>",,,,....~....~ Job 3: Install Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Plan 250°1<> 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 :1:1 OOO'MD to allow a secondary circulation. If there is a need to activate the TAM port collar, notify the AOGCC as they may want to observe the circulating of cement to the surface. ~ While the rig is still on location, verify the top of the cement in the annulus for a period of time following the surface cement job. Notify the AOGCC and town should the level drop enough so that remedial cementing is required. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 300/0 excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. Reference RPs .:. IICasing and Liner Running Procedure" V-107 Drilling Permit Page 7 .~ -J .:. IISurface Casing and Cementing Guidelines" .:. IIHalliburton Cement Program" .:. IISurface Casing Port Collar Procedure" :'Q-~""""-------"¡.x.;.y..:-»-~--~») ~m___)~--»m;...,d_»»_~ Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: The reservoir pressure of the Kuparuk has been estimated to be 9.3 ppg due to production in the area. Assuming gauge hole, a fracture gradient of 12.7 ppg at the surface casing shoe, 10.0 ppg mud in the hole the kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.7 ppg. ~ A fault is expected to be penetrated by V-107 at the Ma sands @ -3830' TVDss. The throw is estimated @ -200' and is not considered a high risk for loss circulation. It is feasible however that losses may be encountered when running the production casing string if adequate precautions are not taken including running speed, staging in and optimal mud properties. Consult Lost Circulation Decision Tree for recommended LCM treatments. ~ V-Pad development wells are expected to 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-107. ~ Utilize the PWD tool to review and refresh the importance of hole cleaning with the Rig Team. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. . IIShale Drilling- Kingak & HRZ" ~--~)IS$)ms;~;.. 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 V2" x 3 V2" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. IIDrillpipe Conveyed Logging" . .mT'!"I1I1"''''''- ."""'- ."- .,- >~"",,,,:,,-,,...,f.-"'';. Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The 5-1/2" casing will be cemented to 500' above the top of the Schrader Bluff. V-107 Drilling Permit Page 8 ~ -J > 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 1000/0 returns are not established. > Ensure a minimum hydrostatic equivalent of 10.0 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 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 Dual- Plug system, (tapered cement plugs to be used in the 5 Y2"X 3 Y2" tapered casing string.) Caliper and confirm the 1.0. 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 0.0. of 2.5". Caliper to confirm, prior to use. Note: Based on ongoing studies relating to wiper plug failures, drop the top and bottom plug together prior to displacement of cement. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" ~1'1''''1>",,''''''''''....'.....'m>''''''''''''''''>'''''''''''''''''''''i~'> 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" -"'.~''''''''''''''''''''''''No.iI'o>'''...''''''''''''';m''''''''''''.''¡''''''N.=''''''''-'''''-.:.:;~'Nn'¡"""¡'""''''''''v''..,.,~>'''''n.¡m=¡...'_.--¡-- ..¡.~.:~._~....:.- Job 13: ND/NU/Release Ria 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. Operational Specifics . Pull landing joint. Set TWC and test from below to 1000 psi, NO stack. NU tree. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull TWC . R/U hot oil truck and freeze protect well by reverse circulating in a sufficient volume of diesel to the bottom GLM. (Equalize to approximately 5000' in tubing/casing) . Install BPV & test to 1000 psi from below. . Rig down and release the rig. V-107 Drilling Permit Page 9 COMPANY DETAILS BP Amcco REFERENt -YATION Co-adinate (NÆ) Reference: W... Centre: V.I04, True North Vertical (TVD) Relèrenœ: Plan V-pad 82' 82.00 Section (VS) Referenœ: Slot - N-] (O.ooN,O.ooE) Measured Depth Reference: Plan V -pad 82' 82.00 Calculation Method: Minimum Curvature SURVEY PROGRAM Depth Fm Depth Tn SurveylPlan 82,00 1000.00 Planned: V.I04 wpOl VI 1000.00 7360.88 Planned: V-I04 wpOl VI C..kuJ~I;''', Mrlt,.J M;r.imw" O"'''''~Jt,Jre Em~ s\ ;k>¡¡1 IS\.~" o)A Swn M~tt..:"J ff'JO C..1I11J.,,'I' N...'Inb Em.'1 '!oUiia~.: tlllp¿I" (.üq Warning Method: Rules Based -1000- T~ CB-GYRO-SS MWD Plan: V-l04wpOl (V-I04lPlan V.I04) Created By: Ken Allen Checked: Date: 9/12/2001 Date:- Date:- Reviewed: Approved: Date:- WELL DETAILS Name +N/-S +EI-W Ncrthing V-I04 120.14 -2S7.74 S970081.50 Easting Latitude Longitude Slot S90SII.50 70"19'40.799N 149'IS'S739SW N.] Name .....:..... PV5 0 ¡ A- i -I2Br- 1000 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 82.00 0.00 0.00 82.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 700.00 4.00 165.00 699.68 -13.48 3.61 1.00 165.00 -11.36 4 II 00.00 0.00 0.00 1099.35 -26.96 7.22 1.00 180.00 -22.72 5 1752.06 6.52 310.00 1750.00 -3.14 -21.17 1.00 310.00 14.34 6 1953.36 6.52 310.00 1950.00 11.56 -38.68 0.00 0.00 37.20 7 2381.08 19.35 310.00 2366.00 72.98 -1\ 1.88 3.00 0.00 132.75 8 6552.04 19.35 310.00 6301.29 961.42 -1170.65 0.00 0.00 1514.84 9 6987.26 15.00 310.00 6717.00 1044.02 -1269.08 1.00 180.00 1643.33 PV5 10 7210.88 15.00 310.00 6933.00 1081.22 -1313.41 0.00 0.00 1701.21 1\ 7360.88 15.00 310.00 7077.89 1106.18 -1343.15 0-00 0.00 1740.03 CASING DETAILS No. TVD MD Name Size 2682.00 2716.01 75/8" 7.625 7077.88 7360.87 5 1/2" x 3 1/2" 5.500 ¡Start Dir 1°/100': 300' MD, 3oo'TVD 2000 ¡End Dir : 1752.06' MD, 1750' TVD u, ::7"u. .. r . ! ' ~ Start Dir 3°/100' : 1953.36' MD, 1950'TVD i '¡ l()~ 1 ! 2000\ ; 'r\'\~o.. - .... TARGET DETAILS TVD +N/-S +E/-W Northing 6717.00 1044.02 .1269.08 5971110.04 Easting Shape 589230.04 Point FORMATION TOP DETAILS No. TVDPath MDPath Fonnation :s 3000 it: 0 0 =- All TVD depths are ssTVD plus 82' for RKBE. SVI OA THRZ BHRZ/TKLB Kl TKucrrKUP/BKLB LcurrKUB BKuprrML v ..:: 'E. Ö '" t) 'f > 2 4000 ... 5000 6000 1°/100' : 6552.04' MD, 6301.29'TVD ----~------ MD.ó717'TVD 7000 B.<:'UPffML v Total Depth: 7360.88' MD, 7077.89' TVD 8000 0 1000 2000 Vertical Section at 309.47° [looOft/in] I 3000 I 2 3 4 5 6 7 8 2653.00 4453.00 6413.00 6585.00 6641.00 6682.00 6756.00 6933.00 2685.27 4593.06 6670.02 6850.15 6908.43 6950.99 7027.63 7210.88 ~ I //,i/+/ .....;...... I.///~ . """"...,...',' '/ ' I, ,# ;-::. ""/~ ~ ~ /Qþ 4- ~ '¡:¡' ~ 8 ~ 600 +' .:;: 1š ~ .:;: :; 0 (/) COMI'ANY DETAII$ REFERENCE INFORMA nON SURVEY PROGRAM Depth Fm Depth To SwveyIPlan BP Amoco Co-ordinale (NIE) Refereoce: Wen Ceotre: V-!04, True North Vertical (fYD) Reference: Plan V-pad 82' 82.00 Section (VS) Reference: Slot. N-} (O,OON,O.OOE) Meas~~~io':=~ ~~~.:~- 82,00 82.00 !OOO.OO Planned: V.I04 wpOl VI 1000.00 7360,88 Planned: V.I04 wpO! VI Calculation Method: Minimum CUrvaIUro = ~=~ ~';:¿'~inder North Wa~ï: ~~i:,d: ~~t~~~lng CASING DETAILS No. TVD Name Size MD 1 2682.00 2716.01 75/8" 2 7077.88 7360.87 5 1/2" x 3 112" 7.625 5.500 1 2 3 4 5 6 7 8 82.00 300.00 700.00 1100.00 1752.06 1953.36 2381.08 6552.04 See 1200 Jk'~ i" x 3,1/2" ............, otal uepm 1.)0' .1111' VlU, IUII.II';/' 1 VU 3nd 'ir: >987.: :6'M b, 6717' TVD ............ '''"+ ¿ ~/ y.-:ll anul rll uu U.J.U.. .. ¡;~/\I , , '-., ""..... ~ 6001 ~ ~ All TVD dept 55' )~'" .. ..... ssTVD plus 8~ ,... ," '.. ~ ¡ 51 )00'" "~" llnim~..~~.. : " , ¡ 500 '" . ~ ~ 400( ", ",.",. '" '" 351 ~ , '" , ¡ ,~" 7 ~ '8" ¡ ¡ ~vv ~ Pn'! T);r 'n!! /\!!' AT) . ":;~,, /! 10..'1 'I.;:;' '''~! nuu 1 ':>¿.UO' MJ 2( 'O?..n ~~ St! rlDiJ 1°/100': . 0 , ! I I I I 900 300 0 -1500 -1200 -900 -600 -300 West(-)/East(+) [300ft/in] Tool Plan: V.104wpOl (V-I04/Plan V-104) Created By: Ken Allen Date: 9/12/2001 CB-GYRQ,.SS MWD Checked: Date: Reviewed: Date: WELL DETAILS Name +N/-S Northing Longitude Slot Basting latitude +EI.W V.I04 120.14 -257.74 5970081.50 590511.50 70019'40.799N 149°15'57.395W N.} Name TARGET DETAILS TVD +Ni-S +EI.W Northing 6717.00 1044.02 -1269.08 5971110J)4 Easting Shape 589230.04 Point PV5 MD SECTION DETAILS Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 0.00 0.00 82.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 4.00 165.00 699.68 -13.48 3.61 1.00 165.00 -11.36 0.00 0.00 1099.35 -26.96 7.22 1.00 180.00 -22.72 6.52 310.00 1750.00 -3.14 -21.17 1.00 310.00 14.34 6.52 310.00 1950.00 11.56 -38.68 0.00 0.00 37.20 19.35 310.00 2366.00 72.98 .111.88 3.00 0.00 132.75 L~ 19.35 310.00 6301.29 961.42 -1170.65 0.00 0.00 1514.84 15.00 310.00 6717.00 1044.02 -1269.08 1.00 180.00 1643.33 PV5 15.00 310.00 6933.00 1081.22 -1313.41 0.00 0.00 1701.21 15.00 310.00 7077.89 1106.18 -1343.15 0.00 0.00 1740.03 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 2653.00 2685.27 SVl 2 4453.00 4593.06 OA 3 6413.00 6670.02 THRZ 4 6585.00 6850.15 BHRZITKLB 5 6641.00 6908.43 K1 6 6682.00 6950.99 TKUCrrKUP/BKLB 7 6756.00 7027.63 LCUrrKUB 8 6933.00 7210.88 BKUPffML V RKBE. ,~¡ , 1j1'f'r~,'.T:: i ~\l))~:J('l:: I ~., l:" . ~ /:I~::¡:::: I . ,¡IPS' ;;;; ,~ 0' MD, 300'TVD I 300 ~ BP Amoco Planning Report- Geographic --J Company: BP Amoco Field: Prudhoe Bay Site: PB V Pad Well:, V-104 Well path: Plan V-104 Date: 9/12/2001 Time: 16:43:55 Co-ordinate(NE) Reference: Well: V-104. True North Vertical (TVD) Reference: Plan V-pad 82' 82.0 Section (VS) Reference: Well (0.00N.0.00E.309.47Azi) Plan: V-104 wp01 Page: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB V Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5969964.50 ft 590770.65 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 39.618 N 149 15 49.871 W True 0.69 deg Well: V-104 Slot Name: N-J Surface Position: +N/-S 120.14 ft Northing: 5970081.50 ft Latitude: 70 19 40.799 N +E/- W -257.74 ft Easting : 590511.50 ft Longitude: 149 15 57.395 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 120.14 ft Northing: 5970081.50 ft Latitude: 70 19 40.799 N +E/-W -257.74 ft Easting : 590511.50 ft Longitude: 149 15 57.395 W Measured Depth: 82.00 ft Inclination: 0.00 deg Vertical Depth: 82.00 ft Azimuth: 0.00 deg Wellpath: Plan V-104 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: Plan V-pad 82' Height 82.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/12/2001 Declination: 26.27 deg Field Strength: 57467 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 309.47 Plan: V-104 wp01 Date Composed: 9/12/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/1000 deg 82.00 0.00 0.00 82.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 4.00 165.00 699.68 -13.48 3.61 1.00 1.00 0.00 165.00 1100.00 0.00 0.00 1099.35 -26.96 7.22 1.00 -1.00 -41.25 180.00 1752.06 6.52 310.00 1750.00 -3.14 -21.17 1.00 1.00 0.00 310.00 1953.36 6.52 310.00 1950.00 11.56 -38.68 0.00 0.00/ 0.00 0.00 2381.08 19.35 310.00 2366.00 72.98 -111.88 3.00 3.00 0.00 0.00 6552.04 19.35 310.00 6301.29 961.42 -1170.65 0.00 0.00 0.00 0.00 6987.26 15.00 310.00 6717.00 1044.02 -1269.08 1.00 -1.00 0.00 180.00 PV5 7210.88 15.00 310.00 6933.00 1081.22 -1313.41 0.00 0.00 0.00 0.00 7360.88 15.00 310.00 7077 .89 1106.18 -1343.15 0.00 0.00 0.00 0.00 Section 1: Start MD Incl Azim TVD +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1000 deg/1000 deg/1000 deg 82.00 0.00 0.00 82.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~, BP Amoco -J Planning Report - Geographic Compan}': BP Amoco Date: 9/12/2001 Time: 16:43:55 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: V-104, True North Site: PB V Pad Vertical (TVD) Reference: Plan V-pad 82' 82.0 Well: V-104 Section (VS) Reference: Well (0.00N,O.00E,309.47Azi) Wellpath: Plan V-104 Plan: V-104 wp01 Section 2: Start MD Incl Azim TVD +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 ,'deg 400.00 1.00 165.00 399.99 -0.84 0.23 -0.71 1.00 1.00 0.00 0.00 500.00 2.00 165.00 499.96 -3.37 0.90 -2.84 1.00 1.00 0.00 0.00 600.00 3.00 165.00 599.86 -7.58 2.03 -6.39 1.00 1.00 0.00 0.00 700.00 4.00 165.00 699.68 -13.48 3.61 -11.36 1.00 1.00 0.00 0.00 Section 3: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 800.00 3.00 165.00 799.49 -19.38 5.19 -16.32 1.00 -1.00 0.00 180.00 900.00 2.00 165.00 899.40 -23.59 6.32 -19.87 1.00 -1.00 0.00 180.00 1000.00 1.00 165.00 999.36 -26.12 7.00 -22.00 1.00 -1.00 0.00 180.00 1100.00 0.00 0.00 1099.35 -26.96 7.22 -22.71 1.00 -1.00 0.00 -180.00 Section 4: Start 1\ID Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 1200.00 1.00 310.00 1199.34 -26.40 6.55 -21.84 1.00 1.00 0.00 0.00 1300.00 2.00 310.00 1299.31 -24.72 4.55 -19.22 1.00 1.00 0.00 0.00 1400.00 3.00 310.00 1399.21 -21.91 1.20 -14.86 1.00 1.00 0.00 0.00 1500.00 4.00 310.00 1499.03 -17.99 -3.47 -8.76 1.00 1.00 0.00 0.00 1600.00 5.00 310.00 1598.72 -12.95 -9.48 -0.91 1.00 1.00 0.00 0.00 1700.00 6.00 310.00 1698.25 -6.78 -16.82 8.67 1.00 1.00 0.00 0.00 1752.06 6.52 310.00 1750.00 -3.14 -21.17 14.35 1.00 1.00 0.00 0.00 Section 5: Start MD Incl Azim TVD +N/-S +E/- W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 1800.00 6.52 310.00 1797.63 0.36 -25.34 19.79 0.00 0.00 0.00 0.00 1900.00 6.52 310.00 1896.98 7.66 -34.04 31.14 0.00 0.00 0.00 0.00 1953.36 6.52 310.00 1950.00 11.56 -38.68 37.21 0.00 0.00 0.00 0.00 Section 6: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1000 deg/1000 deg/1000 deg 2000.00 7.92 310.00 1996.27 15.33 -43.17 43.07 3.00 3.00 0.00 0.00 2100.00 10.92 310.00 2094.91 25.85 -55.71 59.43 3.00 3.00 0.00 0.00 2200.00 13.92 310.00 2192.56 39.67 -72.18 80.93 3.00 3.00 0.00 0.00 2300.00 16.92 310.00 2288.95 56.76 -92.54 107.52 3.00 3.00 0.00 0.00 2381.08 19.35 310.00 2366.00 72.98 -111.88 132.76 3.00 3.00 0.00 0.00 Section 7: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1000 deg/1000 deg/1000 deg 2400.00 19.35 310.00 2383.85 77.01 -116.68 139.03 0.00 0.00 0.00 0.00 2500.00 19.35 310.00 2478.20 98.31 -142.06 172.16 0.00 0.00 0.00 0.00 2600.00 19.35 310.00 2572.55 119.61 -167.45 205.29 0.00 0.00 0.00 0.00 2700.00 19.35 310.00 2666.90 140.90 -192.83 238.42 0.00 0.00 0.00 0.00 2800.00 19.35 310.00 2761.26 162.20 -218.21 271.56 0.00 0.00 0.00 0.00 2900.00 19.35 310.00 2855.61 183.50 -243.59 304.69 0.00 0.00 0.00 0.00 3000.00 19.35 310.00 2949.96 204.80 -268.97 337.82 0.00 0.00 0.00 0.00 3100.00 19.35 310.00 3044.31 226.10 -294.36 370.95 0.00 0.00 0.00 0.00 3200.00 19.35 310.00 3138.66 247.39 -319.74 404.09 0.00 0.00 0.00 0.00 3300.00 19.35 310.00 3233.01 268.69 -345.12 437.22 0.00 0.00 0.00 0.00 3400.00 19.35 310.00 3327.36 289.99 -370.50 470.35 0.00 0.00 0.00 0.00 3500.00 19.35 310.00 3421.71 311.29 -395.88 503.48 0.00 0.00 0.00 0.00 3600.00 19.35 310.00 3516.07 332.59 -421.27 536.61 0.00 0.00 0.00 0.00 3700.00 19.35 310.00 3610.42 353.88 -446.65 569.75 0.00 0.00 0.00 0.00 3800.00 19.35 310.00 3704.77 375.18 -472.03 602.88 0.00 0.00 0.00 0.00 3900.00 19.35 310.00 3799.12 396.48 -497.41 636.01 0.00 0.00 0.00 0.00 -1 BP Amoco -J Planning Report- Geographic Company: BP Amoco Date: 9/12/2001 Time: 16:43:55 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: V-104, True North Site: PB V Pad Vertical (TVD) Reference: Plan V-pad 82' 82.0 Well: V-104 Seetion(VS) Reference: Well (0.00N,O.00E,309.47Azi) Wellpath: Plan V-104 Plan: V-104 wp01 Section 7: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO 'ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 4000.00 19.35 310.00 3893.47 417.78 -522.79 669.14 0.00 0.00 0.00 0.00 4100.00 19.35 310.00 3987.82 439.08 -548.18 702.28 0.00 0.00 0.00 0.00 4200.00 19.35 310.00 4082.17 460.37 -573.56 735.41 0.00 0.00 0.00 0.00 4300.00 19.35 310.00 4176.52 481.67 -598.94 768.54 0.00 0.00 0.00 0.00 4400.00 19.35 310.00 4270.88 502.97 -624.32 801.67 0.00 0.00 0.00 0.00 4500.00 19.35 310.00 4365.23 524.27 -649.70 834.81 0.00 0.00 0.00 0.00 4600.00 19.35 310.00 4459.58 545.57 -675.09 867.94 0.00 0.00 0.00 0.00 4700.00 19.35 310.00 4553.93 566.86 -700.47 901.07 0.00 0.00 0.00 0.00 4800.00 19.35 310.00 4648.28 588.16 -725.85 934.20 0.00 0.00 0.00 0.00 4900.00 19.35 310.00 4742.63 609.46 -751.23 967.34 0.00 0.00 0.00 0.00 5000.00 19.35 310.00 4836.98 630.76 -776.61 1000.47 0.00 0.00 0.00 0.00 5100.00 19.35 310.00 4931.33 652.06 -802.00 1033.60 0.00 0.00 0.00 0.00 5200.00 19.35 310.00 5025.69 673.35 -827.38 1066.73 0.00 0.00 0.00 0.00 5300.00 19.35 310.00 5120.04 694.65 -852.76 1099.87 0.00 0.00 0.00 0.00 5400.00 19.35 310.00 5214.39 715.95 -878.14 1133.00 0.00 0.00 0.00 0.00 5500.00 19.35 310.00 5308.74 737.25 -903.52 1166.13 0.00 0.00 0.00 0.00 5600.00 19.35 310.00 5403.09 758.55 -928.90 1199.26 0.00 0.00 0.00 0.00 5700.00 19.35 310.00 5497.44 779.84 -954.29 1232.39 0.00 0.00 0.00 0.00 5800.00 19.35 310.00 5591.79 801.14 -979.67 1265.53 0.00 0.00 0.00 0.00 5900.00 19.35 310.00 5686.14 822.44 -1005.05 1298.66 0.00 0.00 0.00 0.00 6000.00 19.35 310.00 5780.50 843.74 -1030.43 1331.79 0.00 0.00 - 0.00 0.00 6100.00 19.35 310.00 5874.85 865.04 -1055.81 1364.92 0.00 0.00 0.00 0.00 6200.00 19.35 310.00 5969.20 886.33 -1081.20 1398.06 0.00 0.00 0.00 0.00 6300.00 19.35 310.00 6063.55 907.63 -1106.58 1431.19 0.00 0.00 0.00 0.00 6400.00 19.35 310.00 6157.90 928.93 -1131.96 1464.32 0.00 0.00 0.00 0.00 6500.00 19.35 310.00 6252.25 950.23 -1157.34 1497.45 0.00 0.00 0.00 0.00 6552.04 19.35 310.00 6301.29 961.42 -1170.65 1514.84 0.00 0.00 0.00 0.00 Section 8: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 6600.00 18.87 310.00 6346.61 971.51 -1182.68 1530.54 1.00 -1.00 0.00 180.00 6700.00 17.87 310.00 6441.51 991.77 -1206.82 1562.06 1.00 -1.00 0.00 180.00 6800.00 16.87 310.00 6536.95 1010.96 -1229.69 1591.91 1.00 -1.00 0.00 180.00 6900.00 15.87 310.00 6632.89 1029.08 -1251.28 1620.09 1.00 -1.00 0.00 180.00 6987.26 15.00 310.00 6717.00 1044.02 -1269.08 1643.33 1.00 -1.00 0.00 180.00 Section 9: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 7000.00 15.00 310.00 6729.31 1046.14 -1271.61 1646.63 0.00 0.00 0.00 0.00 7100.00 15.00 310.00 6825.90 1062.78 -1291.43 1672.51 0.00 0.00 0.00 0.00 7200.00 15.00 310.00 6922.49 1079.41 -1311.26 1698.39 0.00 0.00 0.00 0.00 7210.88 15.00 310.00 6933.00 1081.22 -1313.41 1701.20 0.00 0.00 0.00 0.00 Section 10: Start l\ID Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1000 deg/1000 deg/1000 deg 7300.00 15.00 310.00 7019.08 1096.05 -1331.08 1724.27 0.00 0.00 0.00 0.00 7360.88 15.00 310.00 7077.89 1106.18 -1343.15 1740.02 0.00 0.00 0.00 0.00 Survey Map Map <- Latitude -> <- Longitude --> MD Incl Azim TVD +N/-S +EI- W Northing Easting Deg Min Sec Deg Min See ft deg deg ft ft ft ft ft 82.00 0.00 0.00 82.00 0.00 0.00 5970081.50 590511.50 70 19 40.799 N 149 15 57.395 W 100.00 0.00 0.00 100.00 0.00 0.00 5970081.50 590511.50 70 19 40.799 N 149 15 57.395 W 200.00 0.00 0.00 200.00 0.00 0.00 5970081.50 590511.50 70 19 40.799 N 149 15 57.395 W 300.00 0.00 0.00 300.00 0.00 0.00 5970081.50 590511.50 70 19 40.799 N 149 15 57.395 W 400.00 1.00 165.00 399.99 -0.84 0.23 5970080.66 590511.73 70 19 40.791 N 149 15 57.389 W ~ BP Amoco -J Planning Report - Geographic Company: BP Amoco, Date: 9/12/2001 Time: 16:43:55 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: V-104, True North Site: PB V Pad Vertical (TVD) Reference: Plan V-pad 82' 82.0 Well: V-104 Section (VS) Reference: Well (0.00N,0.00E.309.47 Azi) Wellpath: Plan V-104 Plan: V-104 wp01 Survey Map Map <- Latitude --> <- Longitude --> 1\1D Incl Azim TVD +N/-S +EI-W Northing Easting Deg Min See Deg Min Sec ft deg deg ft ft ft ft ft 500.00 2.00 165.00 499.96 -3.37 0.90 5970078.14 590512.44 70 19 40.766 N 149 15 57.369 W 600.00 3.00 165.00 599.86 -7.58 2.03 5970073.94 590513.62 70 19 40.725 N 149 15 57.336 W 700.00 4.00 165.00 699.68 -13.48 3.61 5970068.07 590515.27 70 19 40.667 N 149 15 57.290 W 800.00 3.00 165.00 799.49 -19.38 5.19 5970062.19 590516.92 70 19 40.609 N 149 15 57.244 W 900.00 2.00 165.00 899.40 -23.59 6.32 5970057.99 590518.10 70 19 40.567 N 149 15 57.211 W 1000.00 1.00 165.00 999.36 -26.12 7.00 5970055.47 590518.81 70 19 40.543 N 149 15 57.191 W 1100.00 0.00 0.00 1099.35 -26.96 7.22 5970054.63 590519.04 70 19 40.534 N 149 15 57.185 W 1200.00 1.00 310.00 1199.34 -26.40 6.55 5970055.19 590518.37 70 19 40.540 N 149 15 57.204 W 1300.00 2.00 310.00 1299.31 -24.72 4.55 5970056.84 590516.34 70 19 40.556 N 149 15 57.263 W 1400.00 3.00 310.00 1399.21 -21.91 1.20 5970059.61 590512.97 70 19 40.584 N 149 15 57.360 W 1500.00 4.00 310.00 1499.03 -17.99 -3.47 5970063.4 7 590508.24 70 19 40.623 N 149 15 57.497 W 1600.00 5.00 310.00 1598.72 -12.95 -9.48 5970068.44 590502.17 70 19 40.672 N 149 15 57.672 W 1700.00 6.00 310.00 1698.25 -6.78 -16.82 5970074.52 590494.76 70 19 40.733 N 149 15 57.887 W 1752.06 6.52 310.00 1750.00 -3.14 -21.17 5970078.11 590490.37 70 19 40.769 N 149 15 58.013 W 1800.00 6.52 310.00 1797.63 0.36 -25.34 5970081.56 590486.16 70 19 40.803 N 149 15 58.135 W 1900.00 6.52 310.00 1896.98 7.66 -34.04 5970088.75 590477.37 70 19 40.875 N 149 15 58.389 W 1953.36 6.52 310.00 1950.00 11.56 -38.68 5970092.59 590472.69 70 19 40.913 N 149 15 58.525 W 2000.00 7.92 310.00 1996.27 15.33 -43.17 5970096.31 590468.15 70 19 40.950 N 149 15 58.656 W 2100.00 10.92 310.00 2094.91 25.85 -55.71 5970106.67 590455.49 70 19 41.054 N 149 15 59.022 W 2200.00 13.92 310.00 2192.56 39.67 -72.18 5970120.29 590438.85 70 19 41.190 N 149 15 59.503 W 2300.00 16.92 310.00 2288.95 56.76 -92.54 5970137.13 590418.29 70 19 41.358 N 149 16 0.097 W 2381.08 19.35 310.00 2366.00 72.98 -111.88 5970153.12 590398.76 70 19 41.517 N 149 16 0.662 W 2400.00 19.35 310.00 2383.85 77.01 -116.68 5970157.09 590393.91 70 19 41.557 N 149 16 0.802 W 2500.00 19.35 310.00 2478.20 98.31 -142.06 5970178.08 590368.27 70 19 41.766 N 149 16 1.543 W 2600.00 19.35 310.00 2572.55 119.61 -167.45 5970199.07 590342.64 70 19 41.976 N 149 16 2.284 W 2700.00 19.35 310.00 2666.90 140.90 -192.83 5970220.06 590317.00 70 19 42.185 N 149 16 3.025 W 2800.00 19.35 310.00 2761.26 162.20 -218.21 5970241.05 590291.37 70 19 42.395 N 149 16 3.766 W 2900.00 19.35 310.00 2855.61 183.50 -243.59 5970262.03 590265.73 70 19 42.604 N 149 16 4.507 W 3000.00 19.35 310.00 2949.96 204.80 -268.97 5970283.02 590240.10 70 19 42.814 N 149 16 5.248 W 3100.00 19.35 310.00 3044.31 226.10 -294.36 5970304.01 590214.46 70 19 43.023 N 149 16 5.989 W 3200.00 19.35 310.00 3138.66 247.39 -319.74 5970325.00 590188.83 70 19 43.232 N 149 16 6.730 W 3300.00 19.35 310.00 3233.01 268.69 -345.12 5970345.99 590163.19 70 19 43.442 N 149 16 7.471 W 3400.00 19.35 310.00 3327.36 289.99 -370.50 5970366.98 590137.56 70 19 43.651 N 149 16 8.212 W 3500.00 19.35 310.00 3421.71 311 .29 -395.88 5970387.96 590111.92 70 19 43.861 N 149 16 8.953 W 3600.00 19.35 310.00 3516.07 332.59 -421.27 5970408.95 590086.29 70 19 44.070 N 149 16 9.694 W 3700.00 19.35 310.00 3610.42 353.88 -446.65 5970429.94 590060.66 70 19 44.280 N 149 16 10.435 W 3800.00 19.35 310.00 3704.77 375.18 -472.03 5970450.93 590035.02 70 19 44.489 N 149 16 11.176 W 3900.00 19.35 310.00 3799.12 396.48 -497.41 5970471.92 590009.39 70 19 44.699 N 149 16 11.917 W 4000.00 19.35 310.00 3893.47 417.78 -522.79 5970492.91 589983.75 70 19 44.908 N 149 16 12.658 W 4100.00 19.35 310.00 3987.82 439.08 -548.18 5970513.89 589958.12 70 19 45.118 N 149 16 13.399 W 4200.00 19.35 310.00 4082.17 460.37 -573.56 5970534.88 589932.48 70 19 45.327 N 149 16 14.140 W 4300.00 19.35 310.00 4176.52 481.67 -598.94 5970555.87 589906.85 70 19 45.536 N 149 16 14.881 W 4400.00 19.35 310.00 4270.88 502.97 -624.32 5970576.86 589881.21 70 19 45.746 N 149 16 15.622 W 4500.00 19.35 310.00 4365.23 524.27 -649.70 5970597.85 589855.58 70 19 45.955 N 149 16 16.363 W 4600.00 19.35 310.00 4459.58 545.57 -675.09 5970618.84 589829.94 70 19 46.165 N 149 16 17.105 W 4700.00 19.35 310.00 4553.93 566.86 -700.47 5970639.82 589804.31 70 19 46.374 N 149 16 17.846 W 4800.00 19.35 310.00 4648.28 588.16 -725.85 5970660.81 589778.67 70 19 46.584 N 149 16 18.587 W 4900.00 19.35 310.00 4742.63 609.46 -751.23 5970681.80 589753.04 70 19 46.793 N 149 16 19.328 W 5000.00 19.35 310.00 4836.98 630.76 -776.61 5970702.79 589727.40 70 19 47.002 N 149 16 20.069 W 5100.00 19.35 310.00 4931.33 652.06 -802.00 5970723.78 589701.77 70 19 47.212 N 149 16 20.810 W 5200.00 19.35 310.00 5025.69 673.35 -827.38 5970744.77 589676.13 70 19 47.421 N 149 16 21.551 W 5300.00 19.35 310.00 5120.04 694.65 -852.76 5970765.75 589650.50 70 19 47.631 N 149 16 22.292 W -' ) ~ - BP Amoco Planning Report - Geographic Company: BP Amoco Date: 9/12/2001 Time: 16:43:55 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: V-104, True North Site: PB V Pad Vertical (TV D) Reference: Plan V-pad 82' 82_0 Well: V-104 Section (VS) Reference: Well (0.00N,O.00E,309.47Azi) Wellpath: Plan V-104 Plan: V-104 wp01 Survey Map Map <- Latitude --> <-- Longitude -> 'MD Incl Azim TVD +N/-S +EI-W Northing Easting Deg Min See Deg Min Sec ft deg deg ft ft ft ft ft 5400.00 19.35 310.00 5214.39 715.95 -878.14 5970786.74 589624.87 70 19 47.840 N 149 16 23.033 W 5500.00 19.35 310.00 5308.74 737.25 -903.52 5970807.73 589599.23 70 19 48.050 N 149 16 23.774 W 5600.00 19.35 310.00 5403.09 758.55 -928.90 5970828.72 589573.60 70 19 48.259 N 149 16 24.516 W 5700.00 19.35 310.00 5497.44 779.84 -954.29 5970849.71 589547.96 70 19 48.469 N 149 16 25.257 W 5800.00 19.35 310.00 5591.79 801.14 -979.67 5970870.69 589522.33 70 19 48.678 N 149 16 25.998 W 5900.00 19.35 310.00 5686.14 822.44 -1005.05 5970891.68 589496.69 70 19 48.887 N 149 16 26.739 W 6000.00 19.35 310.00 5780.50 843.74 -1030.43 5970912.67 589471.06 70 19 49.097 N 149 16 27.480 W 6100.00 19.35 310.00 5874.85 865.04 -1055.81 5970933.66 589445.42 70 19 49.306 N 149 16 28.221 W 6200.00 19.35 310.00 5969.20 886.33 -1081.20 5970954.65 589419.79 70 19 49.516 N 149 16 28.962 W 6300.00 19.35 310.00 6063.55 907.63 -1106.58 5970975.64 589394.15 70 19 49.725 N 149 16 29.704 W 6400.00 19.35 310.00 6157.90 928.93 -1131.96 5970996.62 589368.52 70 19 49.935 N 149 16 30.445 W 6500.00 19.35 310.00 6252.25 950.23 -1157.34 5971017.61 589342.88 70 19 50.144 N 149 16 31.186 W 6552.04 19.35 310.00 6301.29 961.42 -1170.65 5971028.64 589329.44 70 19 50.254 N 149 16 31.574 W 6600.00 18.87 310.00 6346.61 971.51 -1182.68 5971038.59 589317.30 70 19 50.353 N 149 16 31.926 W 6700.00 17.87 310.00 6441.51 991.77 -1206.82 5971058.55 589292.91 70 19 50.552 N 149 16 32.631 W 6800.00 16.87 310.00 6536.95 1010.96 -1229.69 5971077.46 589269.81 70 19 50.741 N 149 16 33.298 W 6900.00 15.87 310.00 6632.89 1029.08 -1251.28 5971095.32 589248.01 70 19 50.919 N 149 16 33.929 W 6987.26 15.00 310.00 6717.00 1044.02 -1269.08 5971110.04 589230.03 70 19 51.066 N 149 16 34.449 W 7000.00 15.00 310.00 6729.31 1046.14 -1271.61 5971112.13 589227.48 70 19 51.087 N 149 16 34.522 W 7100.00 15.00 310.00 6825.90 1062.78 -1291.43 5971128.53 589207.46 70 19 51.251 N 149 16 35.101 W 7200.00 15.00 310.00 6922.49 1079.41 -1311.26 5971144.92 589187.43 70 19 51.414 N 149 16 35.680 W 7210.88 15.00 310.00 6933.00 1081.22 -1313.41 5971146.70 589185.26 70 19 51.432 N 149 16 35.743 W 7300.00 15.00 310.00 7019.08 1096.05 -1331.08 5971161.31 589167.42 70 19 51.578 N 149 16 36.259 W 7360.88 15.00 310.00 7077.89 1106.18 -1343.15 5971171.30 589155.22 70 19 51.677 N 149 16 36.612 W TREE = 3-1/8" SM CIVV WELLHEAD = 11" FMC ,. ,--~,----~,,_.'~---,---'w_-----, ACTUA TOR = NA KB~--ELE\r;-"'W-"_W^__N^,'_'^-^ã2~6í' BF~wa:I~vN;,^,_.w"^,-'--W_W-"5i5Õi' "KÕ"p-;--'---'~-"-"--"""3õõí' Max Angle = 19° @ XXXX' oaiüm"MD ,;,~w~w"vn^,w_"__'N'_' Datum lVÕ = -,-~~^--"w_- -' 17-S/8"CSG,29.7#, L-80,ID=6.87S" l-i 2716' ~ 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" l-i I S-1/2" CSG, 1S.5#, L-80, BTC, ID = 4.9S0" l-i xxxx' xxxx' 14-3/4" X 3-112" CSG XO, ID = 3.000" l-i 6751' PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE None PBTD 1-1 7281' 13-1/2" CSG, 9.2#, L-80, .0087 bpf, 10 = 2.992" 1-1 7361' V-107 J ~ I I L ~ j'mv NOTES: 986' 1-i7-S/8" TAM Collar, ID = 6.87S" I 2200' l-i 3-1/2" HES 'X' NIP, 10 = 2.813" I ~ ST MD 3 2 1 GAS LIFT MANDR8.S lVD DEV TYPE VLV LATCH PORT 3S00 KBG2-9 DV BTM 3.5x1 4S00 KBG2-9 DV BTM 3.Sx1 tbd KBG2-9 DCK-3 BTM 3.Sx1 DATE I I I xxxx' 1-i3-1/2"BKRCMDSLlDINGSLV, 10=2.813" 1 ~ '. I I I': i 1 xxxx' 6734' 6751' xxxx' xxxx' xxxx' l-i BKR LOC SEAL ASSY, 10 = 2.990" 1 l-i TOP OF BKR PBR, ID = 4.00" I I-IBTM OF 3-1/2" BKRSEALASSY, ID=2.990" I 1-i3-1/2" HES X NIP, 10 = 2.813" I 1-i3-1/2" HES X NIP, ID = 2.813" I 1-i1S'PUPJTW/RA TAG I . I xxxx' 1-116' PUPJTW I RA TAG 1 ~ DATE REV BY 07/2S/02 jdf COMMENTS A"oposed Corrpletion DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: V -107 ÆRMIT No: API No: SEe 11, T11 N, R11 E, 483S' NSL & 1789' WEL BP Exploration (Alaska) ~ -J V-107 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates may be encountered near the base of the Permafrost at 1782'MD 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 is maintained to avoid stuck pipe situations. Production Hole Section: . A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The production section will be drilled with a recommended mud weight of 10.0 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.3 pore pressure. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . V-1 07 will cross a fault at -3830' TVD (+/-200'). The estimated throw of the fault is approximately 160'. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies H 207002 DATE 7/12/02 INV# CX071002C INVOICE / CREDIT MEMO PERMIT TO DRIL~ FEE THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P,O, BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TO THE ORDER OF DESCRIPTION v~ f 07 TOTAL ~ GROSS DATE 7/12/02 CHECK NO. H207002 VENDOR DISCOUNT NET RECEIVED JUL 2 6 2002 Alaska Oil & Gas Cons. CommissIOn Anchorage No,. H 207002 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND. OHIO 8' P r;~."."',-l-.-."",:.t ,.. (í.I.',IIt.I"IU~ ,,""'< .,.,',:J. (II: iii.. :',::. - - ...; 0' fl' u,' .'il-' ,11 /. ," ..' ... " UI~lttP "......n..,..... STE 100 99501 ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVE ANCHORAGE, AK. 56-389 "'"412 JULY DATE , 2002 II' 20 ? 0 0 2 II' I: 0 1. , 20 :I a 11 5.: 00 a ... I. , q II' CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ****$100.00**** ~~.~t.~:~~!t!~e.~~~~~?-~Y~:~.~:::~.~:::~~S:::f:~:::~1 .:.,:..........:,..,.,:~:.. "..',...,." "".. "',',','.', " . . . ,"', ".',,' .."\:-"'.'..'~.'.~.,.,.,.'..,.......,,',.,::,.., ..'......,",.'::'''''::.':.,''',.-.'.'.,'.-:'.'.' .."":.\ -~:. -., - - ." "::. ~. ."....~/~~...:.~. ;~.\:t-_.. - .-;¡-.~/.. , :"fi;"", \., ;.1\ -~~d ~~~..~;.;(.:: ~{~..;;.\...:..:{.~: \~~t\~ ;~~~i:~~ ;;;~~{?~:~~; ~~;~~ ~'::f:;C H L. L/ ~) ~) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fJßU t/.... jO'7 PTD# 2o:¿-/S(" CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore. segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ßfJ ;X WELL NAME (/-1 c> /' PROGRAM: Exp - Dev.2S. Redrll - Re-Enter - Serv - Wellbore seg - FIELD & POOL h c.¡O)3d INIT CLASS/)~;/./ r-4; I GEOL AREA ??~ UNIT# /1 bf..)(") ON/OFF SHORE Q4) 'ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . (0 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number.,. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pooL. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located. proper distance from other wells.. . . . . . . . . ! Y IN,. r.:l I 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N :3 ¡;'/.-Æ~/ , ~I), '--'" 7./ - ¿ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N f/'¥<- ~c:>'- 9'. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y I N 12. Permit can be issued without administrative approval.. . . . . ..::v N (Service Well Only) 13. Welt located wlin area & strata authorized by injection order#- Y ß /V~4. (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . ., /" N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 34'1 ~ 'loll @ i l (/ 16. Surface casing protects all known USDWs. . . . . . . . . . ,N A j . t- 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ' ',. ~ ~1 ~v,L.{ ~CPt;. c~ . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N ~~: ~~:~Ja1:~~~~~;~~~~:~~~~ ~¡t:.' ~ ~ :~r~~fr.o~t.. : : : : : : ~ ~ ~6~s q £ ~ 22. If a re-drill, has a 10-403 for abandonment been approved. . . Y N N./11r 23. Adequate wellbore separation proposed.. . . . . . . . . . . . &. N 24. If diverter required, does it meet regulations. . . . . . . . . . éìl... N 25. Drilling fluid program schematic & equip list adequate. . . . . iN 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N þ:.- t APPR DATE 27. BOPE press rating appropriate; test to iþ; 00 psig. N Nt Ç. r 2.5 -81 pc..;.. ~ C$Cj ~' '-1500 'Pi / . .IYA.- I ,I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 82 N ~ 7 ~"~7t ot. 29. Work will occur without operation shutdown. . . . . . . . . . . & N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y Œl 31. Mechanical condition of wells within AOR verified. . . . . . . .¥-N Ai/It- ~ Y,,1/;71- ~~ . ,APPR DATE (Service Well Only} ,GEOLOGY APPR DATE A/JI"; ìh1Þ/, , (~xploratory Only) 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . . 1.,1() .)'~..;;~~ .:2, I ;ff¿ ) GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RP~ TEM JDH JBR COT, DTS OìjJI i ~< SFD- WGA Wt,A---' MJW Rev: 07/12/02 G:\geology\perm its\checklist.doc