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202-111
David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 CenterPoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 9/25/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL D-17B (PTD 202-111)) RPM_PNC3D_RAW_04JAN20_BHI RPM_PNC3D_ANALYSIS_18JAN20_BHI Please include current contact information if different from above. Received by the AOGCC 09/25/2020 PTD: 2021110 E-Set: 33989 Abby Bell 09/25/2020 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 j , mAR 1 6' .C� a,O L I I I E JD . Alaska Oil and Gas Conservation Commission ,�� 333 West 7 Avenue Anchorage, Alaska 99501 Masks Oil �� �zxi1 �1J3810n rp- 17B REn Mr. Tom Maunder Subject: Corrosion Inhibitor Treatments of GPB D Pad Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03 /04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 0-17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 / D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 STATE OF ALASKA ~p ALA OIL AND GAS CONSERVATION COMMISSION REPORT OF UNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well Plug Perforations ~ Stimulate ~ Other J SEAL TITE - Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well [] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory .,.N 202-1110- 3. Address: P.O. Box 196612 Stratigraphic Service ~~ 6. API Number: Anchorage, AK 99519-6612 50-029-20692-02-00 - 7. KB Elevation (ft): 9. Well Name and Number: 70.6 KB PBU D-176 ' 8. Property Designation: 10. Field/Pool(s): ADLO-028285 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10320.5 ' feet Plugs (measured) None true vertical 9135.38 ~ feet Junk (measured) None Effective Depth measured 10231 - feet true vertical 9069.67 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 2704 13-3/8" 72# L-80 28 - 2696 28 - 2696 5380 2670 Intermediate 8483 9-5/8" 47# L-80 27 - 8483 27 - 7642 6870 4760 Production 1160 7" 26# L-80 9310 - 9456 7501 - 8474 7240 5410 Liner 1054 4-1/2" 12.6# 13CR80 9266 - 10320 8310 - 9135 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 25 - 9270 0 0 - Packers and SSSV (type and measured depth) 9-5/8" DV Packer 2603 7"x4-1/2" bkr S-3 PKR 9213 0 0 0 0 12. Stimulation or cement squeeze summary: ) /~ ~y~y~j$~~ pti ~^ ~ q/,q! [p~.~ , Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 375 17803 706 1343 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work' copies of Logs and surveys Run Exploratory ~ Development ~ - Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ~ Gas WAG (~ GINJ WINJ ~' WDSPL 3 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: 308-010 Contact Gary Preble Printed Name Gary Pre .~~ c °A Title Data Management Engineer Signature ~ _ Phone 564-4944 Date 9/26/2008 «. 1 ~, t Form 10-404 Revised 04/2006 ~) ~ R .~ue ~ , v ~-=` ss! ~. r ~,' ~~ ~ ~~Q~ Submit Original Onl ~~ ~% 1 D-17B 202-1110 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D-17B 7/12/02 PER 10,072. 10,087. 8,953.61 8,964.46 D-17B I 4/14/03 APF 10,067. 10,072. 8,950. 8,953.61 D-176 2/25/04 APF 10,058. 10,074. 8,943.51 8,955.06 D-176 5/27/06 APF 10,030. 10,040. 8,923.36 8,930.55 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR _ SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF _ SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC _ STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • D-17B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/12/2008T/I/0=150/120/160 temp=S1 Circ-out (Seal-Tite casing repair) Pumped 578 bbls ', ', '9.8# brine down TBG taking returns up IA to well #18's flow line. FWHP's=140/120/240 ', AT DEPARTURE VALVES in following positions -and operator notified of ', positions and result of job. Wing closed, Swab closed, SSV closed, Master open, IA open, OA open -Well SI ', 9/13/2008 T/I/0= 0/0/200.Obj: Seal-Tite casing repair. Pumped 20 bbls of diesel down TBG. Bled back `4 bbls. Pumped 130 bbls of diesel down IA to spot Sealtite. Annulus ', casing valves tagged and left open on departure. Swab, Wing,SSV closed. Master,lA and OA open. Final WHP = 240/560/200 operator notified of well status ', __ 9/15/2008 "*W ELL S/I ON ARRIVAL*** SET 4.5" WHIDDON @ 9.247 SLM. ILl__T__H_EPROCESS OF RUNNING IN TO PULL STA. #2 *'`*CONT. WSR ON 09/16/08*"" ... _.. 9/16/2008 T/I/O =SSV/330/180. Temp = SI. Displace Seal-tite Pill (assist Seal-tite). AL spool piece removed. IA has integral installed. IA FL @ surface. Bled OAP from 180 psi 100 psi (gas) in 35 min into BT. Pumped 1.3 bbl diesel down IA from 320 psi to 1000 psi. Monitored pressures for 60 min. IAP decreased to 950 psi. Pumped 0.67 bbl diesel down IA from 950 psi to 1500 psi. Monitored pressures ' for 60 min. IAP decreased to 1410 psi. Pumped 1.95 bbl diesel down IA from 1410 psi to 2000 psi. Monitored pressures for 60 min. IAP decreased to 1830 psi. Pumped 0.98 bbl diesel down IA from 1830 psi to 2500 psi. Monitored pressures for 60 min. IAP decreased to 2370 psi. Final WHPs = SSYl~376l~0:- MV open. IA & OA valves OTGs. WV, SV &SSV closed. 9/16/2008' ~**CONT. WSR FROM 09/15/08"** PULLED STA. #2 FROM 7,956' SLM, 1.5" CIRCULATING VALVE (RKP LATCH) 'SET STA. #2 @ 7,956' SLM, 1.5" DGLV (RK LATCH) PULLED 4.5" WHIDDON FROM 9,247 SLM. (EMPTY) **"WELL LEFT S/I, PAD OP NOTIFIED OF STATUS**'` r 9/17/2008T/I/O = SSV/1410/110. Temp = SI. Displace Seal-tite Pill (asssist Seal-tite). AL 'spool piece removed. IA has integral installed. IA FL @ surface. IAP decreased :960 psi, OAP increased 10 psi overnight. Pumped 2.14 bbl diesel down IA from si to si. onitore ressures or 0 min. IAP decreased to 2310 psi. '.Pumped 1.25 bbl down IA from 2310 psi to 3000 psi. Monitored pressures for '!min, IA lost 10 psi the 1st 15 min & 10 psi the 2nd 15 min. Continued monitor for X90 more minutes, IAP decreased another 20 psi. Bled IAP from 2960 psi to 2150 -psi (0.60 bbl) into BT. Final WHPs = SSV/2150/110. `€MV open. IA & OA valves OTGs. WV, SV &SSV closed. .,,, 9/17/2008 T/I/0= 1900/1440/80. Temp=S1. Freeze Protect Flowline (Post Sealtite). P~ 7 bbls. meth and 77 bbls. crude to freeze protect the Flowline. Pressure up 11 ....I:..-.. a.. il~nn.-_: ...-~.- J_.~~..a. ..... Notified DSO upon departure of Valve positions. Valve positions as follows; Swab- closed,Wing-closed, SSV-closed, Master-open, IA-open, OA-open. CH2MH has control of well upon departure. FWHP's= 1900/1440/80 9/18/2008'T/I/O = SSV/2170/110. Temp = SI. WHPs (post Seal-tite). AL spool piece 'removed. IA has integral installed. IAP increased 10 psi, OAP unchanged overnight. 9/20/2008 T/I/O =SSV/2020/90. Temp = SI. Monitor WHP (sealtite). AL disconnected L casing valve. Integral installed on IA. IAP decreased 150 psi, OAP decreased 20 psi overnight. SV, WV, SSV shut. MV open. IA & OA otg. NOVP. 9/21/2008 T/I/O=SSV/1990/90. Temp=S1. Monitor WHP (sealtite). AL disconnected. IAP decreased 30 psi, OAP unchanged overnight. SV, WV, SSV=Closed. MV=Open. IA&OA=OTG. NOVP. FLUIDS PUMPED BBLS 150 diesel 578 9.8# BRINE 7 METH 77 CRUDE 812 Total • 'i ~ r` ~ ~ I scc I t ~t ~ ,, ! ~,,,~,,,,~ ~ ~ t~ ~ ~"° ~ ~'~ ~"~ ~~ SARAH PAUN, GOVERNOR ~-7~ OIL AMID (iAS 333 W. 7th AVENUE, SUITE 100 ~ COI~TSER'QATIOI~T CO1~iISSIOI~T ANCHORAGE, ALASKA 99501-3539 f PHONE (907) 279-1433 FAX (907) 276-7542 Chidiebere Igbokwe Petroleum Engineer .~ ~ 200 BP Exploration Alaska, In •)A~ PO Box 196612 Anchorage, AK 99519-6612 ~© ~~- Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-17B Sundry Number: 308-010 Dear Mr. Igbokwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ,[day of January, 2008 Encl. Sincerely- ~~~I\/~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN ~ 0 200$ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~I~SkO Dil & GAS Con~4 ~OmITiISSIOfi 1. Type of Request: Abandon Suspend Operational shutdown Perforate Wa p~ ®~~~ Othe Alter casing^ Repair well ^~ Plug Perforations^ Stimulate ^ Time Extension ^ SEAL TITE Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ 202-1110 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-20692-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU D-176 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028285 70.6 KB PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10320.5 9135.38 10231 9069.67 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 29 109 29 109 1490 470 Surface 2704' 13-3/8" 72# L-80 28 2696 28 2696 5380 2670 Intermediate 8483' 9-5/8" 47# L-80 27 8483 27 7642 6870 4760 Production 1160' 7" 26# L-80 8310 9456 7501 8474 7240 5410 Liner 1054' 4-1/2" 12.6# 13CR80 9266 10320 8310 9135 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10030 - 10040 8923 - 8931 4-1/2" 12.6# 13Cr80 25 - 9270 10058-10067 8944-8950 - 10067 - 10072 8950 - 8954 - 10072 - 10087 8954 - 8965 - 10074-10087 8955-8965 - Packers and SSSV Type: 9-5/8" DV Packer Packers and SSSV MD (ff): 2608 7"x4-1/2" bkr s-3 pkr 9213 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations; 1/24/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chidiebere Igbokwe Printed Name Chidie °f<~we Title Petroleum Engineer Signature Phone 564-4795 Date 1/10/2008 COMMISSION USE ONLY diti f tif d N b ~~~ C l N C i i t t ti it th S on ons o o y ry um er: approva : omm on so a a represen ve may w ness un ss a ~ l Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~~~ Other: Subsequent Form Required: ~~ APPROVED BY Approved by: % MMIS ZONE THE COMMISSION Date: ~' ~" Form 10-403 Revised 06/2006 /`/ "C/ ~~~t ~ } L3 ~ G Submit in Duplicate by To: Jerry Bixby /Clark Olsen -Well Operation Team Leaders Jennifer Julian - Senior Well-work Engineer From: Chidiebere Igbokwe - D-Pad Engineer Neil Cary -Seal-Tite Operations Director Subject: D-17B Seal-Tite Leak Repair PBFPDLI7-S Please perform the attached leak detect log procedure: C, January 7, 2008 Est. Cost: $100M IOR: 250 BOPD 1 S Set Plug in XN-Nipple @ 9,258' MD. Pull GLV 2 0 Seal-Tite repair work to fix PC leak @ DV packer 3 S Pull plug (post Seal-Tite Job) Current Status: Last Production Test: Maximum Deviation: Minimum ID: Last TD Tag: Last Downhole Operation: Latest H2S value: P, SI, Not Operable 12/23/2007: 539 bopd, 920 bwpd, 24.7 MMscf, GOR 45,850 44 deg @ 9.953' MD 3.725" @ 9258' (4 t/z" HES XN Nipple). 08/19/2007: Tag TD @ 10,148' MD. 08/20/2007: HCL Acid Stimulation. 11 /08/2007 D-17B was completed as a zone 2B Rig sidetrack in June, 2002. The initial production from 15' of perforation post rig sidetrack was 800 bopd, 70% WC, 25,000 GOR. An adperf (5 ft) was shot in 2003 but was short-lived. Post 2003 adperf an acid stimulation was done that did not yield any benefit. Another set of adperfs were shot in 2004. Post 2004 adperf, an acid stimulation job was done on D-176 on 08/20/2007 to increase productivity. D-176 failed numerous CMIT-TxIA in 2004 and 2005. A Sensa temperature leak detect log was run on 9/i0/2005 that revealed a leak @ the 9-5/8" DV packer @ 2,608'. D-17B passes an MIT-T and MIT-OA. An MIT-IA prior to the Sensa log job failed with a LLR of 2.8 gpm (5/16/2005).D-17B was wavered for PC leak 11/1/2005. D-17B remained a producer until it was shut-in on the 31St December, 2007 per the new well integrity policy. A recent review of the well events indicates there is a strong possibility of fixing the leak using seal-tite and preliminary assessment by the seal-tite representatives also confirms this. Please contact Jennifer Julian @ 564-5663 (w), 240-8037 (c) or Chidi Igbokwe @ 564-4795 (w), 222-2854 (h) or (507)-993-1139 (c) w/any questions or comments. CC: Well File • • Program Objectives: The objective of this well work is to fix PC leak Q DV packer and restore well integrity using Seal-Tite sealant and procedures. A sensa LDL confirmed leak Q the 9-5/8" DV packer C~ 2,608' on 9/10/2005. Mechanical Considerations Log data indicates communication from inner casing (9 5/8" 47#) to outer casing (13 3/8" 72#) at a DV packer at 2608'MD, 2537'THF. The leak rate is assumed to be 2.8 gallons per minute with diesel at 2800 psi. Tubing: 41/2" 12.6# 13 Cr-80 Cap: 0.6392 gal/ft 0.01522 bbl/fit Production Annuli: KB-THF = 71' 9 5/8" 47# x 41/2" to 8225' THE Cap: 2.2485 gal/ft 0.0535 bbl/ft 7" 26# x 41h" f/ 8225' to 9142'THF Cap: 0.7808 gal/ft 0.0186 bbl/ft Gas lift Mandrel with dummy at 9124'MD, 9053'THF 3.813" ID X nipple at 9192'MD, 9121'THF Production packer at 9213'MD, 9142'THF 3.725" ID XN nipple at 9258'MD, 9258'THF 0-Seal-Tite Procedure: 1. Meet with field personnel; review field history and verify condition of well as matching information provided. 2. Perform Job Safety Analysis with all concerned personnel. 3. Record all tubing and casing pressures. 4. Rig up and test slickline. Set XN plug in nipple at 9258'MD. 5. Pull dummy from mandrel at 9124'MD. (No problem pulling or setting on 9/21/06) 6, Rig up on tubing, test pump and lines to 250 low and 4000 psi high holding each test for 5 minutes. Circulate well with 10.5 Calcium Chloride. Circulate until clean 10.5 going in and coming out. Circulate at rate that does not cut out the profile of the gas lift mandrel. One circulation volume is 593 barrels. 7. Confirm DV leak rate at 1000, 2000, and 3000 psi by pumping down tubing. Monitor the 13 3/8" x 9 5/8" annulus for returns. For purposes of leak rate calculations the total system volume is 25,083 gallons. For each 100 psi drop in pressure, approximately 7.5 gallons of fluid will be lost. 8. Rig up on 9 5/8" x 4 1/2" annulus and test lines to 250 low and 4000 psi high holding each test for 5 minutes. Mix and pump 3 bbls of Flo-Seal I at 6:1 Ratio. Utilize 18 gallons Flo-Seal I plus 108 gallons of fresh water to yield 126 gallons, 3 bbls, of 8.7 ppg sealant. 126 gallons will provide 56' of coverage in the 9 5/8" x 41/2" annulus. Follow the Flo-Seal with 133 bbls of diesel while taking returns back thru 2 • ~ the tubing. This will put the base of the sealant at the leaking DV packer. Annulus pressure should be approximately 450 psi due to imbalance. 9. Shut in tubing. Open the 13 3/8" x 9 5/8" annulus valve and monitor for returns. Pressure up 9 5/8" x 4 ~/z" annulus from 450 to 1000 psi with diesel. Shut in well and allow an initial seal to form. At 1000 psi there will be approximately 2 barrels of sealant above and 1 barrel below the leak site. One barrel is 18.5 feet in the 9 5/8" x 4'/z". Measure returns from 13 3/8" x 9 5/8" if possible as this annulus may be cemented. Wait 1 hour for seal to cure. For every 100 psi pressure lost, approximately 9 gallons of sealant will be lost to the leak. 10. Pressure up first on the 9 5/8" x 4 1/2' with diesel and then on the tubing with brine in stages of approximately 500 psi each from final pressure after initial seal to 2000 psi attempting to keep the leak site within the coverage of the sealant. Note: For each 500 psi added to the annulus, the sealant interface will move down approximately 20'. For each 500 psi added to the tubing the sealant interface will move up approximately 20'. Allow sealant to cure for 2 hours at 2000 psi. Increase pressure on well in stages as above until a final pressure of 3000 psi is obtained. 11. Allow seal to cure for 72 hours under pressure. Monitor all pressures during the curing period. 12. Record M.I.T. data. 13. Bleed 2000 psi off the tubing and reset the dummy in tf~e'~gas lift mandrel at 9124'MD. Bleed the tubing and casing to zero. 14. Pull the plug from the XN nipple at 9258'MD. 15. Put well back on production and monitor casing for pressure build up until well flowing at normal rate and temperature. 16. Record pressure build up in casing due to thermal effects. 17. Rig down equipment and turn well over to Production. 3 D-17B (PTD #2021110) Internal 'aver Cancellation -Not Operable Well Page 1 of 1 • Regg, James B (DOA) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer [NSUADWWeIHntegrityEngineer@BP.com] ~~~ I +~~~ ~$ Sent: Monday, December 31, 2007 9:24 AM / To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, GC1 Wellpad Lead; GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, Wells Opt Eng; GPB, Prod Controllers; Engel, Harry R; GPB, Optimization Engr; Regg, James B (DOA); Maunder, Thomas E (DOA} Cc: Igbokwe, Chidiebere; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E; Culpepper, Jerry K. (Orbis); Boyles, Gerald J Subject: D-17B (PTD #2021110) Internal Waiver Cancellation -Not Operable Well All, :/ An internal waiver was issued for a PC Leak on natural producing well D-17B (PTD #2021110) on 11/01/05. The dispensation from the Well Integrity System Policy for this well has expired. If not already done, please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~ ~ H~ ~. ~ ~~~ U G1 1 /17/2008 _..-..- . STATE OF ALASKA ffc; ~Lj/oh ALA OIL AND GAS CONSERVATION COM_SION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED SEP 1 3 2006 1. Operations Performed: Anchorage o Abandon o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing o Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown ~ Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 202-111 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20692-02-00 7. KB Elevation (ft): 70.60 9. Well Name and Number: PBU D-17B 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10320 feet true vertical 9135 feet Plugs (measured) None Effective depth: measured 10231 feet Junk (measured) None true vertical 9070 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' 1490 470 Surface 2704' 13-3/8" 2704' 2704' 4930 2670 Intermediate 8483' 9-5/8" 8483' 7642' 6870 4760 Production 1160' 7" 8296' - 9456' 7489' - 8474' 7240 5410 Liner 1054' 4-1/2" 9266' - 10320' 8310' - 9135' 8430 7500 ¡"~ANNE~-) ~EP "' "20"i-' \). ." ... y {'.l ,~i .1.)" Perforation Depth MD (ft): 10030' - 10087' Perforation Depth TVD (ft): 8923' - 8964' 4-1/2", 12.6# 13Cr80 9270' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2" Landing Nipple, 9-5/8" DV Packer 2158',2608' 7-5/8" X 4-1/2" BKR S-3 Packer 9213' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: 0 0 0 150 200 Subsequent to operation: 0 0 0 250 200 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or NJA if C.O. Exempt: Contact Gary Preble, 564-4944 Printed Name G~ Preble ......,. A Title Data Mgmt Engr ......t'~, , //~ ¡¿repared By Name/Number: Signature ----. Phone 564-4944 Date fØ'/ø -- Form 10-404 ReVisa1frG t N A L f Submit Original Only RBDMS BFt SEP ] 4 lOOö 1133/8" CSG, 72#, L-80, ID= 12,347" I TREE = WELLHEAD = ACTUATOR = KB. ELBI '" BF. ELEV - KOP= Max Angle = Datum MD - Datum ND = 4-1/2" CrN McEVOY OTIS 70.6' 42.98' 8483' 44 @ 9953' 9957' 8800' SS . D-17B SAFETYN .4-1/2"CHROMETBGANDLNR**PC LEAK. OPERATING LIMITS: MAX lAP = 500 PSI; MAX OAP = 1000 PSI (11/1/05 WAlVERED) 2158' 4-1/2" X LANDING NIP, ID = 3.813" 9 5/8" DV PKR I 2608' ST MD ND DEV TYÆ VLV LA TCH PORT DATE 6 2935 2935 5 CA DMY RK 0 04/30/05 5 3719 3697 22 CA DMY RK 0 04/30/05 4 5890 5460 38 MMGM DMY RK 0 06/24/02 3 6507 5954 36 MMGM DMY RK 0 06/24/02 2 7964 7193 27 MMGM DMY RK 0 06/24/02 1 9124 8188 30 KBG-2 DMY BK 0 06/24/02 Minimum ID = 3.725" @ 9258' 4-1/2" HES XN NIPPLE I TOP 7" LNR , 8296' ÆRFORA TION SUMMARY REF LOG: MWD ON 06/22/02 ANGLEATTOPÆRF: 44@ 10031' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 2 10031 - 10034 0 OS/27/06 2-7/8" 6 10034 - 10040 0 OS/27/06 3-3/8" 6 10058 - 10074 0 02/25/04 3-3/8" 6 10067 - 10072 0 04/14/03 3-3/8" 6 10072 - 10087 0 07/12/02 9-5/8" MILLOUT WINDOW 8483 - 8499 TOP OF WHIPSTOCK I 4-1/2"HESXNIP,ID=3.813" I I 9-5/8" CIBP I 8507' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" I -i 4-1/2" HES XN NIP, ID = 3.725" I 5" X 7" BKR TIEBACK SL V, ID = 5.246" 1-14-1/2" WLEG, ID = 3.958" I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I DATE 04/01/82 06/17/96 06/24/02 02/24-25/04 05/03/05 OS/29/05 10483' REV BY COMMENTS ORIGINAL COMPLETION CTD SIDETRACK (0.17 A) DAC/KK RIG SIDETRACK (D-17B) JJ/MAITP TAG FILL, ADPERF RWLlPJC GLV C/O (4/30/05) ROY /PJC ÆRF/TTP CORRECTION REV BY COMMENTS / TLH CORRECTIONS EZUPJC WM/ER SAFETY NOTE DAV/PAG TTPPULLED RRD/PJC ÆRFORA TIONS PRUDHOE BA Y UNIT WELL: 0-17B ÆRMIT No: "2021110 API No: 50-029-20692-02 SEC 22, T11N, R13E, 2100' SNL & 1692' WEL DATE 06/07/05 11/01/05 12/02/05 OS/27/06 . . ....,.... , ,,, D-17B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 40. needs Integral installed. unit to #6. Wait on N2 truck currently servicing CTU #9. RIH lifting at 500 scflm N2 rate. Ran down to 2000' and begin lifting with no returns to flowline, pooh to 1000' and still no flow. Out of hole and pump 60 bbls of meth down flowline. Rih while pumping 1000 scflm N2 rate stop at 7500' tvd while pumping 600 scflm N2 rate. Rih and Stop at 8000' and see if well will flow on its own. Well flowing on its own Pooh, Stand by to make sure well still flowing. Final FWHP = 220 psig. Final FWHT = 76 deg F. RD CTU #6. *** Job Complete *** FLUIDS PUMPED BBLS 1 I :::A:l 1 e e WELL LOG TRANSMITTAL ;to;2 - III To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 13ltji~ RE: MWD Formation Evaluation Logs D-17B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 D-17B: LAS Data & Digital Log hnages: 50-029-20692-02 1 CD Rom ~ t ~ ~/ é)r;jOh e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc RECEIVED . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION cOMrvlWlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 70.6 KB 8. Property Designation: ADL-028285 11. Present Well Condition Summary: Total Depth measured 10320.5 true vertical 9135.38 Effective Depth measured 10231 true vertical 9069.67 Casing Conductor Surface Production Liner Liner Length 80 2668 8456 1146 1054 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# 13Cr80 Perforation depth: Measured depth: 10058 - 10074 True Vertical depth: 8943.51 - 8955.06 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signat~ Form 10-404 Revised 04/2004 ,1/1\11 1 2006 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development ;?J Stratigraphic D Stimulate 0 8 Ö1~jrn Gas ÇlJn~ ('9mm:,:.. WaiverO Time Extension OAf I ¡~.,,'" 1 Re-enter Suspended Well 0 IC Wrage 5. Permit to Drill Number: 202-1110 D 6. API Number: 50-029-20692-02-00 Exploratory Service 9. Well Name and Number: D-17B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) feet feet MD 29 - 109 28 - 2696 27 - 8483 8310 - 9456 9266 - 10320 TVD 29 - 109 28 - 2695.83 27 - 7642.32 7500.74 - 8474.01 8310.31 - 9135.01 10067 - 10087 Çt·l·k~\",í~:;:11 ' \.~\,¡){I"tw{,:t;."" ...i 8950 - 8964.46 4-1/2" 12.6# 13Cr80 9-5/8" DV Packer 9-5/8" Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" TIW Top Packer None None Burst 1490 5380 6870 7240 8430 Collapse 470 2670 4760 5410 7500 -j (); .......' f...-' 25 - 9270 2600 8304 9213 9273 RBDMS 8Ft ,IAN ] 1 1006 Title Data Mgmt Engr Phone 564-4424 Tubing pressure Service GINJ D WDSPL D Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory D Development ;?J 16. Well Status after proposed work: Oil r;¡: Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ Sundry Number or N/A if C.O. Exempt: N/A Date 1/9/2006 Submit Original Only .' e e D-178 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE Ididi~~UMIIIY ,V? "rl 12/1/2005 ***WELL SHUT IN ON ARRIVAL*** (pull ttp) PULLED 4.5 PX PLUG @ 9165' SLM *** LEFT WELL SHUT IN *** FLUIDS PUMPED I BBLS I : TOTAL ) ¡ ~V---i N~ '1 DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021110 Well Name/No. PRUDHOE 8AY UNIT D-178 Operator 8P EXPLORATION (ALASKA) INC 5¡? C; ¿ i ì J -I'(v... 4"\ 1- API No. 50-029-20692-02-00 MD 10320 lVD 9135 Completion Date 7/12/2002 Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt ;-er) --.C ~4 ~t i t;Ð_. [}-. : .er-~- 0 Electr Dataset Number Name l.11" 124 Gamma Ray Directional Survey Log Log Scale Media Run No 1 1 1 1 LIS Verification. cA1lféctional Survey t../11631 LIS Verification "'"ED C Asc (11771 LIS Verification ED C Pdf 11771 Rate of Penetration JED C Pdf /' 11771 Induction/Resistivity ED C Pdf 11771 Density ,ED C Pdf -41771 Neutron 25 25 25 25 Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORM~ON Well Cored? Y f.N.J Daily History Received? Chips Received? (Y / N Analysis Received? -- Comments: Formation Tops ~~ Current Status 1-01L UIC N Directional Survey @ (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 7196 10201 Case 10/1/2002 Includes Casing Collar Log ~ 8391 1 0320 Open 8/1/2002 7941 10275 Case 3/17/2003 8391 10320 Open 8/1/2002 7941 10275 ~. 3/17/2003 7938 1 0321 3/17/2003 8483 1 0320 ~ 3/17/2003 ROP, DGR, EWR 8483 10320 ca~ 3/17/2003 ROP, DGR, EWR 8483 10320 Ca~e 3/17/2003 DGR, SLD, CTN 8483 1 0320 Case 3/17/2003 DGR, SLD, CTN Sample Set Number Comments - &/N ''Q.N DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021110 Well Name/No. PRUDHOE BAY UNIT D-17B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20692-02-00 MD 10320 lVD 9135 Completion Date 7/12/2002 Completion Status 1-01L Current Status 1-01L UIC N Compliance Reviewed By: ~ Date: i b {~V; ~L( --/ .~ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION corvll".1SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 Repair Well 0 Pull Tubing 0 Operation ShutdownD Plug PerforationsD Perforate New Pool D 4. Current Well Class: 70.60 8. Property Designation: ADL-0028285 11. Present Well Condition Summary: Development I]] StratiQraphic 0 9. Well Name and Number: D-17B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Perforate ŒJ WaiverO Stimulate ŒJ Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1110 OtherD BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak.99519-6612 7. KB Elevation (ft): Exploratory 0 Service D 6. API Number 50-029-20692-02-00 Total Depth measured 10320 feet true vertical 9135.0 feet Plugs (measured) None Effective Depth measured 10231 feet Junk (measured) None true vertical 9069.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 109 29.0 109.0 1490 470 Liner 14 9-5/8" 47# L-80 8296 - 8310 7488.8 - 7500.7 6870 4760 Liner 1146 7" 26# L-80 8310 - 9456 7500.7 - 8474.0 7240 5410 Liner 25 7" 26# 13CR80 9266 - 9291 8310.3 - 8331.9 7240 5410 Liner 984 4-1/2" 12.6# 13Cr80 9291 - 10275 8331.9 - 9102.0 8430 7500 Liner 45 4-1/2" 12.6# L-80 10275 - 10320 9102.0 - 9135.0 8430 7500 Production 8456 9-5/8" 47# L-80 27 - 8483 27.0 - 7642.3 6870 4760 Surface 2668 13-3/8" 72# L-80 28 - 2696 28.0 - 2695.8 4930 2670 Perforation depth: Measured depth: 10058 -10067,10067 -10072, 10072 -10074,10074 -10087 True vertical depth: 8943.51 - 8950, 8950 - 8953.61, 8953.61 - 8955.06, 8955.06 - 8964.46 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 9270 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" TIW Liner Top Packer 9-5/8" DV Packer 9-5/8" Liner Top Packer @ 9213 @ 9273 @ 2600 @ 8304 ,3 1 21JC: 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10050' -11100' BWS BFl Treatment descriptions including volumes used and final pressure: 49 Bbls 12% DAD Acid @ 400 psig Representative Daily Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 10.9 1159 1200 APRO ltm!¡: 13 335 11.2 2218 800 Tubing Pressure 187 251 Prior to well operation: Subsequent to operation: Oil-Bbl 344 14. Attachments: 15. Well Class after proposed work: Exploratory D DevelopmentŒ] Service D Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasO WAG 0 GINJO WINJO WDSPLO Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature _11~ Ct(~"1V\. Form 1 0-404 Revise~ 12/2003 Title Production Technical Assistant URIGINÂT 564-4657 Date 3/30/04 ') ) D-178 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/18/04 *** WELL SHUT IN ON ARRIVAL *** ( DRIFT FOR CTU ACID JOB) DRIFT W/ 3.25 CENT /SB. TAG TO @ 101601 SLM. APPROX 501 BELOW BOTTOM PERF INTERVAL. SECURE WELL. NOTIFY PAD OPERATOR. RDMO. 01/25/04 HEAT UPRIGHT # 005 FROM 115* TO 160*, HEAT UPRIGHT # 072 FROM 115* TO 160* FOR CTU. RDMOL. 01/26/04 ACID TREAT, CTU #4; MIRU OS CTU #4. PREP FOR WEEKLY BOP TEST. CONT' ON WSR 1/27/04 ... 01/27/04 TI0=1240/1250/650 ASSIST COIL TUBING WITH ACID JOB, LOAD I.A. PUMPED 6 BBLS METH, 200 BBLS CRUDE. FINAL TI0=1600/1575/720 01/27/04 ACID TREAT, CTU #4; CONT' FROM WSR 1/26/04... STAB ONTO WELL. PREP FOR WEEKLY BOP TEST. COULD NOT PUMP DOWN COIL. POSSIBLE ICE PLUG IN COIL. RIH TO 3501, COIL THAWED. POOH. PERFORM WEEKLY BOP TEST - PASSED. LOAD IA WITH 200 BBLS DEAD CRUDE. FLUID PACK WELL WITH 230 BBLS FILTERED 2% KCL. RIH WITH 2.5" JSN. PERFORM INJECTIVITY TEST @ 1,2,3 BPM PRE/POST ACID. TAG TD @ 10117' CTMD. PUMPED 49 BBLS OF 12 % DAD. RECIPROCATED ACROSS PERFS THREE PASSES FROM 100501 - 111001. OVERFLUSH ACID WITH 100 BBLS OF FILTERED 2 % KCL . POOH. CHANGE PACK-OFFS. CONT' ON WSR 1/28/04 ... 01/28/04 ACID TREAT, CTU #4; CO NT' FROM WSR 1/27/04... CONTINUE RIGGING DOWN CTU #4. PERFORM CHAIN INSPECTION. NOTIFY PAD OPERATOR AND PCC. WELL IS READY TO POP. *** JOB COMPLETE *** 02/24/04 ***WELL FLOWING ON ARRIVAL *** ( PRE-ADPERF ) DRIFT W/ 33/8 DUMMY GUN, DRIFT TO 10,158 SLM. ADPERF TARGET DEPTH 10,058- 10,074. TURN WELL OVER TO PAD OPERATOR. 02/25/04 PERFORATED 100581 TO 100741 WITH 33/8" 3406 PJ, HMX, 6 SPF CORRELATED TO SWS PDC GR/CCL RUN 12-JUL-2002. FLUIDS PUMPED BBLS 161 996 400 49 1606 Methanal 2% KCL Crude 12% DAD Acid. Titration: 11.9%, Iron < 50 ppm TOTAL Page 1 TREE = 4-1 /2" CrN WELLHEAD = McEVOY ÃCÏÜÃrOR'-;;''''''''''''''''-''^"''OllS. "KEf-Ei.ËV';;^"'"'^~'-^^-'^-"7Õ~6' ,...........-v.-."''''''',,,,,,,,,,,,,,'''''''''''''''''''',,,,,,,,,,,,,,''''''''''''''''''''''''''''''''''"^''''''''''''''''''''''''''''''''''''''''''''' BF. 8..EV = 42.98' """"""",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,"<'"'''''''''''-'''''''''''''''''''''''~''''''''''''''''''''''''''''''''''''''''''''''''' KOP= 8483' Max Angle = 44 @ 9953' oatumMi5'~" """"""9957i' 'ïsaiÙñï 'fVÖ;;;;"'" "äaöÖi'sS' 1133/8" CSG, 72#, L-80, D = 12.347' 1-1 2704' Minimum ID = 3.725" @ 9258' 4.1/2" HES XN NIPPLE I TOP 7" LNR 1-1 8296' PERFORATION SUMMARY REF LOG: MWD ON 06/22/02 ANGLEATTOPÆRF: 44 @ 10067' Note: Refer to Production DB for historcal perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 10058 - 10074 0 02/25/04 3-3/8" 6 10067 - 10087 0 04/14/03 3-3/8" 6 10072 - 10087 0 07/12/02 I TOP OF WHIPSTOCK 1-1 8483' I 9-5/8" CIBP 1-1 8507' ') ') SAFETY NOTES: 4-1/2" CHROME TBG AND LNR D-178 z 2158' 1-1 4-1/2" X LANDING NIP, ID = 3.813" I 2608' l-i 95/8" r:N A<R I ~ ~ ~ GAS LIFT MANDR8..S DEV TYPE VL V LA TCH 5 CA OOrvE RK 22 CA S/O RK 38 MMGM DMY RK 36 MMGM DMY RK 27 MMGM DMY RK 30 KBG-2 DMY BK PORT DATE 16 03/18/04 20 03/18/04 06/24/02 06/24/02 06/24/02 06/24/02 L ST MD TVD 6 2935 2935 5 3719 3697 4 5890 5460 3 6507 5954 2 7964 7193 1 9124 8188 .. I 9-5/8" MILLOur WINOOW 8483 - 8499 9192' 1-1 4-1/2" HES X NIP, ID = 3.813" I 9213' 1-1 7" X 4-1 /2" BKR 5-3 A<R, ID = 3.875" 1-1 4-1/2" I-ES XN NIP, ID = 3.725" I 9266' 1- 5" X 7' BKR llEBA CK SLV, D = 5.246" 9270' 1- 4-1/2" WLEG, ID = 3.958" I 9-5/8" CSG,47#, L-80,ID= 8.681" 1-1 9518' ~ ~ 17' LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 10483' I DATE 04101/82 06117/96 06124/02 07/12102 10/04102 11/12102 04114/03 07/09103 COMrvENTS ORIGINAL COM PLEIlON CTD SIDETRACK (D-17A) DACH<K RIG SIDETRACK (D-17B) CWSiKK IPERFS BM/lP W Arv ER SA FETY NOTE /TLH D8..ETE WA rvER SAFETY N01E PWE/KK A CPERFS Crv1O/lLP KB ELEV ATION CORRECfION REV BY \ 4-1/2" TBG, 12.6# -I 9270' I 13-CR-80, .0152 bpf '" ""- ID= 3.958" ~ IT' LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9456' 14-1/2" LNR, 12.6# 13-CR-80, .0152 bpf, ID = 3.958" ~ H 10320' 10231' 1-1 FBID I DA TE REV BY COMrvENTS 09/16/03 CrvrofTLP DATU'v1 M) & PERF ANGLE 09/29103 PWE/lLH 9-5/8" CSG A<R CORREeTON 02/24-25/04 J-.VMAlTP TAG RLL, A CPERF 03/18104 JLJIlLP GLV 00 FRU[]- OE BA Y UNIT W8..L: D-17B ÆRMrT No: 2021110 A PI No: 50-029-20692-02 SEe 22, T11 N, R13E, 2100' SNL & 1692' WEL BP Exploration (Alaska) ') ') WELL LOG TRANSMITTAL ~o 2- I To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 04, 2003 RE: MWDFonnation Evaluation Logs: D-l7B, AK-MW-22096 D-17B: Digital Log Images 50-029-20692-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:~---I ( / ð3 Signed: <::: c;; cX/f7) ) l ) aDd-III II ~,\,3¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation C011l1ll. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska March 11, 2003 RE: MWD Fonnation Evaluation Logs D-17B, AK-MW-22096 1 LDWG fOI11latted Disc with verification listing. API#: 50-029-20692-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: -- -~/J . Si~/)6ch (l QeQp.-n RECEIVED MAR 1 i 2003 Aiaska or: & Gas Cons. CommiS8ío AncfJnr.-r n vœg~e Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Job# Log Description Date MPS-11 ~Od.- ~ ~PS-13 ~O d-)J '-1 D-08A a nc=;>- J ~ ~ D-17B ~~- } I , D.S.14-33 I ~ ~-/ ~ S 22443 SCMT (PDC) 22444 SCMT (PDC) 22434 GR/CCL (PDC) 22433 GR/CCL (PDC) 22386 RST -SIGMA 07/01/02 07/02/02 07/15/02 07/12/02 07/21/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 -~ . Date Delivered: é ~ (Á 00:> ~ Blueline NO. 2449 Company: 09/30/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD ~. 1 1 1 1 1 -~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth RECEIVED Received by: OCT 0 1 2002 AJIIk8 Oil & Gal Cons. CommfIILJn Andmge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) 1. Status of Well 181 Oil 0 Gas, 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at sUrfacerë6~i;;-,1 ë:rION:;~',' ~,~- '~,'''I>''~';r", 21001 SNL, 1692'.W~L, SEC. 23, T11N, R13E, UM~ _'I '~Þ:;:E : ,~,(.)CA, . ~', At top of productive Interval } 7'/' 'Ó'2-~ ~" ; 35641 SNL, 4650' WEL, SEC. 23, T11 N, R13E, UM :, . '1fT r :-' , ~, "~'" ' ,~, " At total depth : t ~cD '\' r' ,- ", 3409' SNL, 4855' WEL, SEC. 23, T11 N, R13E, UM ~;,:::=:.,,-_..::::) t~;"-r'" ~_rer.ì.':~f 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE ;; 70.60' ADL 028285 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/17/2002 6/21/2002 7/12/2002 17. Total Depth (MD+lVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10320 9135 FT 10231 9070 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, PWD, DEN, NEU 23. CASING SIZE 20" X 30" 13-3/8" 9-518" Classification of Service Well 7. Permit Number 202-111 8. API Number 50- 029-20692-02 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D-17B 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 21581 MD 1900' (Approx.) WT. PER FT. Insulated 72# 47# 26# 12.6# GRADE Conductor L-80 L-80 L-80 13Cr80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 361' 8 cu yds Concrete Surface 2704' 17-1/2" 3588 cu ft Permafrost Surface 8483' 12-1/4" 303 cu ft Class 'G' 8296' 9456' 8-1/2" 219 cu ft Class 'G' 9266' 10320' 6-1/8" 168 cu ft Class 'GI AMOUNT PULLED 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 10072' - 10087" 8954' - 8965' 25. SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 9270' PACKER SET (MD) 9213' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected wI 150 Bbls of Diesel 27. Date First Production July 12, 2002 Date of Test Hours Tested 7/15/2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 826 CALCULATED 24-HoUR RATE OIL -BBL GAs-McF 9406 GAs-McF WATER-BBL 2874 WATER-BBL CHOKE SIZE 90.73° OIL GRAVITY-API (CORR) GAS-OIL RATIO 11,387 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips,' .1, 1 , , No core samples were taken. ,L\j~;i.¡,~ \(;1, & t;ë;.::: Ancr¡oraç¡c !~~ t1 t ~.) ¡,-} 1 ~;::t~.~ ':: ~.' Form 10-407 Rev. 07-01-80 ~ ,"" Or~r:"11 ~i~~ G\--' ~' i \ ,i lJ : i' ~ ~- R B 0 M 5 B F L AUG I 3 æQßmit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Sag River 9454' 8472' Shublik A 9496' 8508' Shublik B 9533' 8540' Shublik e 9562' 8565' Sadlerochit 9592' 8591' Zone 4A 9732' 8705 Zone 3 98431 8788' Zone 2C 9945' 8862' GOe 9990' 88951 owe 10086' 8964' HOT 10169' 9024' Zone 1 B 10267' 9096' 31. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb1e ~~ . ~ Title Technical Assislant D-178 202-111 Well Number Permit No. / Approval No. Date O?J'Û9.o~ Prepared By Name/Number: Terrie Hubble, 564-4628 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 othelWise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 .-.. r", r I \ :, I I ¡ '.', . Legal Name: 0-17 Common Name: 0-17 Test Date 6/16/2002 6/20/2002 FIT FIT Test Type Test Depth (TMD) 8,483.0 (ft) (ft) BPEXPLORATION Le,ak-()ffIést .Sl.ll11rnary TestDepth (TVD) 7,650.0 (ft) (ft) AMW 10.60 (ppg) (ppg) Silrfáce.PressÜre 357 (psi) (psi) 4~áf(Qff'.P.reS$(Jre(afiP) 4,569 (psi) (psi) 11.50 (ppg) 11.50 (ppg) --" ,,-," Printed: 6/28/2002 2:32:41 PM ") ') BPEXPLORATI'ON Operation!) Summary Report Page 1 of5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-17 0-17 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/13/2002 Rig Release: 6/25/2002 Rig Number: Spud Date: 3/9/1982 End: Dåte From - To Hours Task Code NPT Phase Description of Operations 6/13/2002 09:00 - 09:30 0.50 MOB P PRE PJSM for moving the rig. 09:30 - 10:30 1.00 MOB P PRE Move shop, camp and pits from D-22B to D-17B. 10:30 - 12:00 1.50 MOB P PRE Move Rig to D-17B. 12:00 - 14:00 2.00 MOB P PRE Spot camp, pits, shop and rig. 14:00 - 15:00 1.00 RIGU P PRE RU lines and stairs. Berm around cellar and cuttings tank. 15:00 - 16:00 1.00 RIGU P PRE Inspect rig. ACCEPT RIG AT 15:00 HRS, 6-13-2002. Install secondary annular valve. 16:00 - 16:30 0.50 RIGU P PRE Pre-spud safety meeting with all personnel. 16:30 - 17:30 1.00 RIGU P PRE Pull BPV w/ lubricator. (100 psi on the 5-1/2" tbg x 9-5/8" csg annulus). 17:30 - 21 :00 3.50 WHSUR P SURF RU flowlines to tree and circulate out diesel freeze protect, at 3 BPM. 21 :00 - 22:00 1.00 WHSUR P SURF Open well and monitor. No pressure. Blow down and RD lines. 22:00 - 22:30 0.50 WHSUR P SURF Install TWC, test from below to 1,000 psi - okay. 22:30 - 00:00 1.50 WHSUR P SURF ND tree. 6/14/2002 00:00 - 03:00 3.00 WHSUR P SURF Finish ND/NU. 03:00 - 06:30 3.50 WHSUR P SURF SET TEST PLUG. TEST UPPER PIPE RAMS, AND HYD CHOKE TO 250 PSI LOW AND 3,500 PSI HIGH, FOR 5/5 MIN. TEST ANNULAR AND MANUAL KILL AND CHOKE TO 250 PSI LOW AND 3500 PSI HIGH, FOR 5/5 MIN. TEST TO, (2) TIW VALVES, DART VALVE TO 250/3,500 PSI FOR 5/5 MIN. TEST BLIND RAMS, HYD KILL AND CHOKE VALVES TO 250/3,500 PSI FOR 5/5 MIN. WITNESSING OF TEST WAIVED BY CHUCK SCHEVE OF THE AOGCC. 06:30 - 07:30 1.00 WHSUR P SURF Pull TWC with lubricator. 07:30 - 08:30 1.00 PULL P DECOMP RU casing handling equipment. Make up landing joint. 08:30 - 09:30 1.00 PULL P DECOMP Pull tubing hanger to floor with 200K (15K over). Cap off control lines and rig up spooling unit. 09:30 - 10:00 0.50 PULL P DECOMP Lay down landing joint and hanger. 10:00 - 19:30 9.50 PULL P DECOMP Pull and lay down 5-1/2" pup, 201 jts of 5-1/2",17 Ib/ft, L-80, BTC tubing, plus a 13.95' cutoff, 11 GLM, and SSSV. Recovered 23 clamps and 3 SSCL bands. 19:30 - 21 :00 1.50 PULL P DECOMP Clear rig floor. 21 :00 - 23:30 2.50 WHSUR P DECOMP PU window milling BHA. 23:30 - 00:00 0.50 WHSUR P DECOMP PU and set RTTS 2' below tubing spool. 6/15/2002 00:00 - 05:00 5.00 WHSUR P DECOMP MU pack-off running tool and screw into pack-off. Finish bleed down annulus pressure, and change out pack-offs. Plastic pack with 4 sticks and test to 5,000 psi for 10 min. - okay. 05:00 - 07:00 2.00 BOPSUR P DECOMP MU test assembly, set and test lower Rams to 250 / 3,500 psi for 5/5 min. Pull test plug, install WB, laydown test joint. 07:00 - 08:00 1.00 BOPSUR P DECOMP MU running tool and retrieve RTTS packer. Monitor well - okay. 08:00 - 13:00 5.00 STWHIP P WEXIT RIH with mills making a guage run and picking up 4" DP singles needed to drill to TO. 13:00 - 14:30 1.50 STWHIP P WEXIT Cut and slip 100' of drill line. Service Top Drive. 14:30 - 15:00 0.50 STWHIP P WEXIT Continue to RIH and tag up on 5-1/2" tbg stub at 8,639' drillpipe depth. 15:00 - 16:30 1.50 STWHIP P WEXIT Sweep the hole at 11 BPM. UWT= 205K, DWT=165K, ROT = 185K, TQ = 5,000 ft-Ib. Flow check, pump slug. 16:30 - 20:00 3.50 STWHIP P WEXIT POOH to BHA, SLM - no correction. 20:00 - 21 :00 1.00 STWHIP P WEXIT Stand back BHA. 21 :00 - 21 :30 0.50 STWHIP P WEXIT RU wireline loggers and EZSV setting tool. 21 :30 - 23:00 1.50 STWHIP P WEXIT RIH, tag tbg stump at 8,641' WL depth. Log collars, set EZSV Printed: 6/28/2002 2:32:59 PM ) ') BP EXPLORATION Ope rati 0 os ..Summa ry. Re port page 2 oI5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-17 0-17 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/13/2002 Rig Release: 6/25/2002 Rig Number: Spud Date: 3/9/1982 End: Date From- To HoUrs Task Code NPT Phase Description of'Operations 6/15/2002 21 :30 - 23:00 1.50 STWHIP P WEXIT 2' above collar. Top of EZSV at 8,507'. Check string weight, POOH. 23:00 - 23:30 0.50 STWHIP P WEXIT RD wireline loggers. 23:30 - 00:00 0.50 STWHIP P WEXIT Pressure test 9-5/8" casing to 3,000 psi for 30 min - okay. 6/16/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT Finish casing test. Clear rig floor. 01 :00 - 03:00 2.00 STWHIP P WEXIT Make up whipstock + milling BHA. Orient MWD. 03:00 - 04:30 1.50 STWHIP P WEXIT RIH to 962'. Shallow test MWD. 04:30 - 07:30 3.00 STWHIP P WEXIT Continue to RIH to 8,428'. Test MWD. 07:30 - 08:30 1.00 STWHIP P WEXIT Orient whipstock to 84 deg RHS. Tag up on EZSV and set whipstock at 8,507'. 08:30 - 10:30 2.00 STWHIP P WEXIT Displace hole to 10.6 ppg LSND milling fluid. 10:30 - 17:30 7.00 STWHIP P WEXIT Mill window from 8,483' - 8,499' at 2-3 ft/hr. UWT=190K, DWT= 160K, ROT=180K, Torque = 7/9K ft-Ib off/on. Continue drilling formation to 8,515'. (Recovered 120 Ib of metal cuttings, and a questionable trace of cement in returns). 17:30 - 19:00 1.50 STWHIP P WEXIT Sweep hole at 10.5 BPM and 2,320 psi. Work thru the window with pumps off/on - no problems. Monitor well. 19:00 - 19:30 0.50 STWHIP P WEXIT Pull into casing above whipstock, to 8,468'. Perform FIT to 11.5 EMW with 357 psi surface pressure. 19:30 - 22:30 3.00 STWHIP P WEXIT Pump slug and POOH to BHA. 22:30 - 00:00 1.50 STWHIP P WEXIT Stand back HWDP and LD DC. 6/17/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT LD milling BHA. (All mills were in guage). 01 :00 - 01 :30 0.50 STWHIP P WEXIT Clear rig floor. 01 :30 - 02:30 1.00 DRILL P INT1 Flush BOP stack, service WB, function BOPE. 02:30 - 03:30 1.00 DRILL P INT1 MU drilling BHA, adjust motor bend to 1.5 deg. 03:30 - 04:30 1.00 DRILL N SFAL INT1 Computer failure in MWD unit, change out same. 04:30 - 05:30 1.00 DRILL P INT1 Test and orient MWD. 05:30 - 08:30 3.00 DRILL P INT1 Shallow pulse test MWD, RIH to 8,351'. 08:30 - 09:30 1.00 DRILL N DPRB INT1 Pipe plugged. Circulate plug free and continue circulating one pipe volume. 09:30 - 10:30 1.00 DRILL P INT1 Orient toolface to 85 deg RHS, pass thru window. 10:30 - 11 :00 0.50 DRILL P INT1 Ream undergauge hole from 8,506' - 8,515'. UWT=185K, DWT=155K. 11:00 -12:00 1.00 DRILL P INT1 Drill to 8,526'. AST=.75 hr, ART=.25 hr. 12:00 -12:30 0.50 DRILL N RREP INT1 Engine downtime due to over heaing. (Variable speed controler for radiator fan was malfunctioning). 12:30 - 00:00 11.50 DRILL P INT1 Drill ahead with 1.5 deg motor. AST= 4.5 hr, ART = 4 hr. 6/18/2002 00:00 - 03:00 3.00 DRILL P INT1 Drill ahead with 1.5 deg motor to 9,033'. 03:00 - 04:00 1.00 DRILL N SFAL INT1 Failure of Sperry-Sun computer in MWD unit. Change out computers (second changout for this well). MAD pass from 9,003'-9,033' at 100' per hour. 04:00 - 15:30 11.50 DRILL P INT1 Drill 8-1/2" hole to 9,456. ART= 7.25 hr, AST= 4.15 hr. 15:30 - 16:30 1.00 DRILL P INT1 Circulate HI-VIS weighted sweep at 12 BPM and 3,250 psi. Monitor well. 16:30 - 17:30 1.00 DRILL P INT1 POOH to inside 9-5/8" casing at 8,445'. (No overpull while POOH). 17:30 - 19:00 1.50 DRILL P INT1 Cut and slip 75' of drilling line, service top drive. 19:00 - 19:30 0.50 DRILL P INT1 RIH to 9,456'. No fill on bottom. (passed thru window w/o problems). 19:30 - 21 :00 1.50 DRILL P INT1 Circulate sweep around, circulate hole clean at 12 BPM and 3,250 psi. 21 :00 - 00:00 3.00 DRILL P INT1 POOH to 2,002'. 6/19/2002 00:00 - 01 :00 1.00 DRILL P INT1 POOH to BHA. Printed: 6/28/2002 2:32:59 PM Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION' OperationsSumnlaryR~port 0-17 0-17 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/13/2002 Rig Release: 6/25/2002 Rig Number: ') Page30f5 Spud Date: 3/9/1982 End: Date From - To Hours Task Code NPT Phase Description of Operations 6/19/2002 01 :00 - 03:30 2.50 DRILL P INT1 LD Drilling BHA. Download MWD data. 03:30 - 04:00 0.50 CASE P INT1 Clear rig floor. 04:00 - 06:30 2.50 CASE P INT1 Change out upper pipe RAMs to 7". Test to 250 / 3,500 psi for 5/5 min. 06:30 - 07:00 0.50 CASE P INT1 PJSM for running liner. 07:00 - 09:30 2.50 CASE P INT1 Run 28 Jts of 26 Ib/ft, L-80, BTC-M liner, plus HMC hanger and ZXP liner top packer. Thread lock shoe joints. Make up joints to 7,500 ft-Ib. Ran straight blade centralizers on first 10 joints. Locked centralizers in the center of the liner joints. 09:30 - 10:30 1.00 CASE P INT1 Circulate one liner volume. RD casing equipment. (Liner weight + the blocks = 55K). 10:30 - 14:30 4.00 CASE P INT1 RIH with 7" liner on 4" drillpipe. 14:30 - 15:00 0.50 CASE P INT1 Circulate one pipe volume at 6 BPM and 773 psi. UWT= 175K, DWT= 140K. 15:00 - 16:00 1.00 CASE P INT1 Pass thru window okay and continue to RIH without problems. 16:00 - 16:30 0.50 CEMT P INT1 PU/MU cement rotating head. RIH and tag bottom at 9,456'. 16:30 - 17:30 1.00 CEMT P INT1 Circulate and reciprocate casing (UWT=190K, DWT= 145K), while staging up pump flowrate to 8 BPM, at 1,900 psi. 17:30 - 18:30 1.00 CEMT P INT1 Test cementing lines to 4,000 psi, pump 10 bbl of water, 44 bbls of 11.6 ppg, Alpha Spacer, 41 bbls(198 sx) of 15.8 ppg Class "G", plus additives, at 4 BPM. Drop plug and displace. Bump plug - CIP at 18:25 hrs. 18:30 - 19:00 0.50 CASE P INT1 Pressure up to 3,500 psi, set hanger check floats - okay. Release from hanger, PU (lost 50K of string weight). Weight set packer with 50K, rotate while slacking off with 75K with good surface indications. 19:00 - 20:00 1.00 CASE P INT1 PU 12', circulate btms up at 11 BPM and 2,980 psi. Trace of cement in returns. 20:00 - 00:00 4.00 CASE P INT1 POOH and LD running tool. (tool okay). 6/20/2002 00:00 - 01 :00 1.00 BOPSURP PROD1 Change out top RAMs from 7" to Variable RAMs. 01 :00 - 01 :30 0.50 BOPSUR P PROD1 Pull WB, set test plug. 01 :30 - 04:30 3.00 BOPSURP PROD1 Continue testing BOPE. Test upper pipe RAMS, and hyd choke to 250 / 3,500 psi for 5/5 minutes. Test Annular and manual Kill and Choke valves to 250 / 3,500 psi, for 5/5 minutes. Test TO, (2) TIW valves, and dart valve to 250 / 3,500 psi for 5/5 minutes. Test Blind RAMS, HYD Kill and Choke valves to 250 / 3,500 psi for 5/5 minutes. Test witnessing waived by Lou Grimaldi of the AOGCC. 04:30 - 05:30 1.00 CASE P PROD1 Test 7" liner and 9-5/8" casing to 3,000 psi for 30 minutes. 05:30 - 09:00 3.50 DRILL P PROD1 Make up BHA #4 with tricone bit on 1.5 deg bent motor. Orient MWD, upload data, load logging RA sources, test MWD. 09:00 - 13:00 4.00 DRILL P PROD1 RIH to 9,372', filling pipe at 3,950' and 7,216' and testing MWD. Tag up on landing collar at 9,372' 13:00 - 15:30 2.50 DRILL P PROD1 Drill float equipment and shoe track cement to 9,450' UWT= 195K, Dwt= 140K, ROT= 160K, TO= 7K Off / 8K On. 15:30 - 19:00 3.50 DRILL P PROD1 Displace well to 8.4 ppg, Ouick-Dril mud at 5 BPM and 1,320 psi. 19:00 - 20:00 1.00 DRILL P PROD1 Drill out the remaining cement and float shoe plus 20' of new formation to 9,576', 20:00 - 20:30 0.50 DRILL P PROD1 Perform FIT to 10.0 ppg EMW with 705 psi surface pressure. 20:30 - 00:00 3.50 DRILL P PROD1 Drill 6-1/8" hole with 1.5 degree motor to 9,538', ART= 2.6 hrs, AST= 0.7 hrs. 6/21/2002 00:00 - 20:30 20.50 DRILL P PROD1 Drill 6-1/8" hole with 1.5 deg bent motor, final UWT=235K, Printed: 6/28/2002 2:32:59 PM ) ) BP EXPLORATION Operations S.ummary Report Page 4 Of5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-17 D-17 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/13/2002 Rig Release: 6/25/2002 Rig Number: Spud Date: 3/9/1982 End: Date From - To Hours Task Code NPT Phase Descriþtion of Operations 6/21/2002 00:00 - 20:30 20.50 DRILL P PROD1 DWT= 140K, ROT= 172K. ART= 11.5 hrs, AST= 5.0 hrs. 20:30 - 22:30 2.00 DRILL P PROD1 Circulate HI-VIS sweep, monitor well. 22:30 - 23:30 1.00 DRILL P PROD1 Short trip to inside 7" casing at 9,450'. No overpull. UWT=245K. RIH to bottom, DWT= 137K, no problems, no fill. 23:30 - 00:00 0.50 DRILL P PROD1 Circulate hole clean. 6/22/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Circulate and condition mud at 10,320'. Spot liner running pill. 01 :00 - 01 :30 0.50 DRILL P PROD1 Monitor well - static. Drop ESS survey tool. 01 :30 - 06:30 5.00 DRILL X PROD1 MAD pass from 10,320' to 9,640' at 150 ft/hr, 9,640' to 9,495' at 300 ft/hr. Make check shot surveys at 10,165' and 9,979'. 06:30 - 07:00 0.50 DRILL P PROD1 Flow check. Pump slug. 07:00 - 07:30 0.50 DRILL P PROD1 POOH to 8,518'. 07:30 - 09:30 2.00 DRILL X PROD1 MAD pass from 8,518' to 7,988' at 300 ft/hr. 09:30 - 11 :30 2.00 DRILL P PROD1 POOH to BHA. 11 :30 - 14:00 2.50 DRILL P PROD1 LD BHA. Rmove RA logging sources, download MWD and zero motor. 14:00 - 14:30 0.50 DRILL P PROD1 Clear rig floor. 14:30 - 16:30 2.00 CASE P PROD1 RU casing equipment. PJSM. 16:30 - 18:30 2.00 CASE P PROD1 Run 24 jts of 4-1/2", 12.6 Ib/ft, 13CR80, Vam-Ace liner. Thread locked all shoe jts, float equipment. Ran 23 free floating centralizers. Average MU torque of 3,600 ft-Ib 18:30 - 19:00 0.50 CASE P PROD1 Circulate one liner volume. 19:00 - 23:00 4.00 CASE P PROD1 RIH with 4-1/2" liner on 4" drillpipe to 9,451'. UWT= 190K, DWT= 135K. 23:00 - 00:00 1.00 CASE P PROD1 Circulate one pipe volume. MU cement head, LD one jt of drillpipe. 6/23/2002 00:00 - 00:30 0.50 CASE P PROD1 Run liner in 6-1/8" open hole, no problems. 00:30 - 01 :00 0.50 CASE P PROD1 RU cement head, manifold and circulating lines. 01 :00 - 03:30 2.50 CASE P PROD1 Stage up circulating rate to 6-1/2 BPM at 1,000 psi. Reciprocate pipe. UWT= 200K, DWT= 145K. Hold PJSM. Batch mix cement. 03:30 - 04:30 1.00 CEMT P PROD1 Test all lines to the cement head, to 4,000 psi. Pump 25 bbls of 9.4 ppg Alpha spacer, followed by 30 bbl of 15.6 ppg, latex "G" cement, plus additives. Drop dart and displace with 40 bbls of perf pill, followed by 67.2 bbl of freshwater. Bump plug, pressure up to 3,500 psi and set hanger. Release pressure and check the floats - okay. CIP @ 0430 hrs - 6/23/2002. 04:30 - 05:90 0.50 CASE P PROD1 Slack off and set down with 25K, and had indications of liner top packer setting. PU and set down with 45K, repeat set down with 45K, while rotating. 05:00 - 05:30 0.50 CASE P PROD1 Un-sting and displace well to 8.5 ppg seawater at 11 BPM and 1,900 psi. Recovered 2 bbl of cement while circulating. 05:30 - 07:00 1.50 CASE P PROD1 RD cement head and lines. 07:00 - 08:00 1.00 CASE P PROD1 POOH to 7,400' 08:00 - 09:30 1.50 CASE P PROD1 Cut and slip drill line. Service Top Drive. 09:30 - 10:30 1.00 CASE P PROD1 POOH laying down drill pipe. 10:30 - 12:00 1.50 CASE N RREP PROD1 Rig repair of chain drive on pipe skate. 12:00 - 16:00 4.00 CASE P PROD1 POOH laying down 4" drllpipe (194 jts). 16:00 - 16:30 0.50 CASE P PROD1 Service and LD liner running tool. 16:30 - 17:30 1.00 CASE P PROD1 RIH with 11 stands of drill pipe that was racked in the derrick. POOH laying down 4" DP (33 jts). 17:30 - 18:00 0.50 RUNCOrvP COMP PullWB. 18:00 - 19:00 1.00 RUNCOrvP COMP Test 4-1/2" x 7" x 9-5/8" casing to 3,000 psi for 30 minutes. 19:00 - 20:00 1.00 RUNCOrvP COMP RU tubing handling equipment, hold PJSM with all personnel. Printed: 6/28/2002 2:32:59 PM ) ) BPEXPLORA TION Operation$ .SummaryReport PageS of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-17 D-17 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/13/2002 Rig Release: 6/25/2002 Rig Number: Spud Date: 3/9/1982 End: 'Date From-To Hours Task Code NPT Phase Description of Operations 6/23/2002 20:00 - 00:00 4.00 RUNCOrvP COMP Run 4,062' (92 jts) of 4-1/2",12.6 #/ft, 13CR80, Vam-Ace tubing. Thread-lock all connections below the packer. Make up all tubing jts with Best-O-Life PTC compound and apply an average MU torque of 3,600 ft-Ib. 6/24/2002 00:00 - 05:30 5.50 RUNCOrvP COMP Continue running 4-1/2",12.6 #/ft, 13CR80, Vam-Ace tubing, to 8,250'. Make up all tubing jts with Best-O-Life PTC compound and apply an average MU torque of 3,600 ft-Ib. 05:30 - 06:00 0.50 RUNCOrvP COMP Service Top Drive. 06:00 - 07:00 1.00 RUNCOrvP COMP Continue running tubing to 9,175' 07:00 - 07:30 0.50 RUNCOIVN SFAL COMP Repair Nabors casing tongs. 07:30 - 08:00 0.50 RUNCOrvP COMP Continue running 4 1/2" tubing, tagged at 9272' 08:00 - 10:00 2.00 RUNCOrvP COMP Space out with 19.91' + 2.40' pups. UWT= 145K, DWT= 110K. Land hanger and RILDS. 10:00 - 14:00 4.00 RUNCOrvP COMP RU circulating lines, reverse circulate corrosion inhibitor at 3 BPM and 120 psi. 14:00 - 20:00 6.00 RUNCOrvP COMP PU landing Jt and drop 1-7/8" (dia) ball and rod. Pressure tubing to 3,500 psi for 30 min. (Indications of packer setting at 1,800 psi). Test annulus and pemanent pkr to 3,000 psi - leaked. Re-torqued hanger and pressured tubing to 4,000 psi for 30 minutes - ok. Tested annulus to 3,000 psi for 30 minutes. Sheared RP valve at 2,100 psi. 20:00 - 20:30 0.50 WHSUR P COMP Install TWC and test to 2,000 psi from below. 20:30 - 21 :30 1.00 WHSUR P COMP Blow down lines and NO BOPE. 21 :30 - 22:30 1.00 WHSUR P COMP NU adaptor flange and tree. Test to 5,000 psi. 22:30 - 23:30 1.00 WHSUR P COMP RU lubricator and pul TWC. 23:30 - 00:00 0.50 WHSUR P COMP RU flowlines to freeze protect well. 6/25/2002 00:00 - 03:00 3.00 WHSUR P COMP Pump 150 bbl of diesel and u-tube. 03:00 - 04:00 1.00 WHSUR P COMP Install BPV, test to 2000 psi, RD secondary casing valve, Secure well, Release Rig at 04:00 hrs, 6/25/2002. Printed: 6/28/2002 2:32:59 PM ) ) Well: Field: API: Permit: D-17B Prudhoe Bay Unit 50-029-20692-02 202-111 Rig Accept: 06/13/02 Rig Spud: 06/17/02 Rig Release: 06/25/02 Drilling Ri~r Nabors 2ES POST RIG WORK 07/05/02 PULL B&R. SET GENERIC GASLlFT DESIGN. PULL RHC-M PLUG BODY. RAN 3-3/8" DG. SAT DOWN @ 9724' SLM. RAN 2.50" DRIVE DOWN BAILER. SAT DOWN @ 9752'. WORKED TO 10010' SLM. RAN 3" & 3.50" BROACH TO 10015' SLM. START IN WELL WI 3.50" BAILER. 07/06/02 RAN 3.50" DRIVE DOWN BAILER. WORKED TO 10016'. BAILER STUCK. DROP KINLEY CUTTER. FISH KINLEY CUTTER. RIH LATCH FISH, UNABLE TO FREE TOOL STRING. RUN BAITED BOWEN OVERSHOT. SET @ 9978' SLM. 3-1/2" INTERNAL FISH NECK LOOKING UP. (TAKES 3-1/2" GS TO PULL). OVERSHOT LENGTH-55". WILL SWALLOW 30-1/2". FISH IS 28' LONG + LENGTH OF OVERSHOT (MINUS THE 30-1/2" IT SWALLOWED). RD. NOTIFIED DSO OF WELL STATUS. 07/08/02 FISH SIL TS, FCO CEMENT-RIH W/3 1/2" HYD GS, LATCH FISH AT 10000' CTD, JAR 10 LICKS UP, 1 DOWN, PULL FREE, POOH. LAY DOWN FISH, BAILER RECOVERED, RESIDUAL CEMENT INSIDE. M/U 3.70" CEMENT MILL & RIH. 07/09/02 RIH TO 10,059', NO DRY TAG. PIU TO 9990' & MILUWASH TO 10,225', (PBTD). OPEN CIRC SUB & SWEEP WI BIOlAN, FIP TO 2500', CLOSE SWAB & UD MOTOR & MILL. RDMO. 07/11/02 D&T W/3 3/8" D/GUN AND SIBAILER (13'-5" OAL) TO 10183' SLM. NOTIFY PAD OPERTOR AND LEFT WELL SHUT IN. 07/12/02 RIG UP RUN 15 FT 3318 POWERJET GUN @ 6 SPF-PERF INTERVAL 10072 TO 10087--TOTAL SHOTS 91--- CORRELATED TO SWS BHC RAN 28 MAR 1982 & SWS DUAL INDUCTION RAN 28 MAR 1982 PEN 38.6 ENT. 45 TURNED WELL BACK TO PAD OP. WELL LEFT SHUT IN. ) ) ao~-, III 31-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well D-178 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,391.70' MD Window / Kickoff Survey 8,483.00' MD (if applicable) Projected Survey: 10,320.50' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 1 2002 Alaska Oil & Gas Cons. Commissio Anchorage n North Slope Alaska BPXA PBU_WOA D Pad, Slot D-17 D-178 Job No. AKMW22096, Surveyed: 21 June, 2002 SURVEY REPORT 23 July, 2002 D~~ ~/J)vs ~ Your Ref: API 500292069202 Surface Coordinates: 5958888.00 N, 653471.00 E (70017' 40.6591- N, 148045' 26.3142- W) Kelly Bushing: 70.60ft above Mean Sea Level &pe'-''''Y-SUf1 D~ILL.NG SERVIc:es A Halliburton Company "--.v Survey Ref: svy11252 Sperry-Sun Drilling Services D . Survey Report for 0-178 ~ Your Ref: API 500292069202 'E ~ . Job No. AKMW22096, Surveyed: 21 June, 2002 'N ''''1 \IE BPXA North Slope Alaska PBU WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8391.70 34.950 236.190 7498.43 7569.03 1682.01 S 2217.75 W 5957161.06 N 651288.05 E 1267.65 Tie On Point MWD Magnetic ~ 8483.00 38.240 237.040 7571.72 7642.32 1711.94 S 2263.20 W 5957130.20 N 651243.23 E 3.646 1295.60 Window Point 8530.93 35.530 241.140 7610.06 7680.66 1726.74 S 2287.85 W 5957114.91 N 651218.88 E 7.635 1311.38 8563.4 7 34.470 244.110 7636.71 7707.31 1735.33 S 2304.42 W 5957105.99 N 651202.49 E 6.165 1322.58 8593.14 33.970 246.950 7661.25 7731.85 1742.24 S 2319.60 W 5957098.76 N 651187.46 E 5.640 1333.25 8624.47 33.010 250.080 7687.38 7757.98 1748.57 S 2335.68 W 5957092.10 N 651171.51 E 6.306 1344.99 8655.42 32.790 253.320 7713.37 7783.97 1753.85 S 2351.63 W 5957086.50 N 651155.67 E 5.730 1357.07 8688.15 32.260 256.880 7740.97 7811.57 1758.38 S 2368.63 W 5957081.63 N 651138.76 E 6.067 1370.42 8720.45 32.310 259.350 7768.27 7838.87 1761.93 S 2385.51 W 5957077.73 N 651121.96 E 4.087 1384.08 8749.93 31.820 263.200 7793.26 7863.86 1764.31 S 2400.97 W 5957075.04 N 651106.55 E 7.129 1396.98 8784.92 32.070 265.770 7822.95 7893.55 1766.08 S 2419.40 W 5957072.89 N 651088.17 E 3.951 1412.80 8816.41 31.590 268.760 7849.71 7920.31 1766.88 S 2435.98 W 5957071.75 N 651071.60 E 5.234 1427.40 8837.31 31.340 270.230 7867.54 7938.14 1766.98 S 2446.89 W 5957071.43 N 651060.70 E 3.861 1437.18 8877.12 30.790 273.250 7901.64 7972.24 1766.36 S 2467.42 W 5957071.63 N 651040.16 E 4.151 1455.94 8908.55 30.150 275.370 7928. 73 7999.33 1765.16 S 2483.31 W 5957072.50 N 651024.25 E 3.980 1470.78 8934.94 29.220 278.840 7951.66 8022.26 1763.55 S 2496.27 W 5957073.85 N 651011.26 E 7.403 1483.15 8968.78 28.950 279.880 7981.23 8051.83 1760.88 S 2512.50 W 5957076.19 N 650994.97 E 1.694 1498.94 8995.89 28.710 283.100 8004.98 8075.58 1758.28 S 2525.31 W 5957078.53 N 650982.12 E 5.795 1511.60 9029.08 28.710 285.600 8034.09 8104.69 1754.32 S 2540.75 W 5957082.16 N 650966.60 E 3.618 1527.23 -' 9059.21 28.730 289.960 8060.52 8131.12 1749.91 S 2554.53 W 5957086.30 N 650952.73 E 6.953 1541 .56 9089.58 29.070 294.120 8087.11 8157.71 1744.40 S 2568.13 W 5957091.53 N 650939.03 Ë 6.713 1556.20 9123.18 29.600 298.730 8116.40 8187.00 1737.07 S 2582.86 W 5957098.55 N 650924.15 E 6.903 1572.65 9157.07 30.290 301.250 8145.77 8216.37 1728.62 S 2597.50 W 5957106.71 N 650909.33 E 4.233 1589.51 9188.27 30.360 306.020 8172.70 8243.30 1719.90 S 2610.61 W 5957115.16 N 650896.05 E 7.721 1605.11 9216.39 30.500 306.950 8196.95 8267.55 1711.43 S 2622.06 W 5957123.39 N 650884.43 E 1.747 1619.10 9250.47 30.440 307.440 8226.32 8296.92 1700.98 S 2635.83 W 5957133.56 N 650870.45 E 0.750 1636.03 9309.43 30.310 308.010 8277.19 8347.79 1682.74 S 2659.41 W 5957151.31 N 650846.51 E 0.536 1665.20 9388.83 30.550 308.560 8345.65 8416.25 1657.82 S 2690.97 W 5957175.58 N 650814.44 E 0.463 1704.45 9455.28 30.850 308.560 8402.79 8473.39 1636.68 S 2717.50 W 5957196.18 N 650787.48 E 0.451 1737.53 9486.90 31.600 305.980 8429.83 8500.43 1626.75 S 2730.54 W 5957205.83 N 650774.24 E 4.849 1753.59 ----------- -- ---.- -~ -------- 23 July, 2002 - 14:45 Page 20'4 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services D.. . Survey Report for D-17B fFIN/~'~ Your Ref: API 500292069202 Job No. AKMW22096~ Surveyed: 21 June~ 2002 '. IIYE BPXA North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9512.26 31.390 303.690 8451.46 8522.06 1619.198 2741.42 W 5957213.18 N 650763.22 E 4.789 1766.67 9544.50 30.540 303.490 8479.10 8549.70 1610.01 8 2755.23 W 5957222.07 N 650749.21 E 2.656 1783.10 9579.72 30.030 301.780 8509.52 8580.12 1600.438 2770.19 W 5957231.34 N 650734.07 E 2.844 1800.73 _/ 9608.62 31.720 301.920 8534.32 8604.92 1592.60 8 2782.79 W 5957238.91 N 650721.31 E 5.853 1815.47 9642.15 33.650 302.880 8562.54 8633.14 1582.908 2798.07 W 5957248.30 N 650705.83 E 5.960 1833.46 9674.16 36.740 305.660 8588.70 8659.30 1572.50 8 2813.30 W 5957258.39 N 650690.39 E 10.872 1851.69 9705.59 38.780 308.080 8613.54 8684.14 1560.95 8 2828.69 W 5957269.62 N 650674.77 E 8.021 1870.57 9736.67 40.040 308.110 8637.56 8708.16 1548.77 S 2844.22 W 5957281.48 N 650659.00 E 4.055 1889.84 9766.68 40.460 307.600 8660.46 8731.06 1536.87 8 2859.53 W 5957293.06 N 650643.45 E 1.779 1908.80 9797.68 42.460 306.430 8683.69 8754.29 1524.52 8 2875.92 W 5957305.08 N 650626.81 E 6.918 1928.93 9860.17 42.290 307.120 8729.86 8800.46 1499.31 8 2909.65 W 5957329.59 N 650592.57 E 0.792 1970.26 9953.41 44.200 305.720 8797.77 8868.37 1461.408 2961.06 W 5957366.45 N 650540.40 E 2.292 2033.03 10046.38 43.990 306.310 8864.54 8935.14 1423.36 8 3013.39 W 5957403.41 N 650487.30 E 0.496 2096.69 10141.17 43.110 307.390 8933.25 9003.85 1384.20 8 3065.65 W 5957441.50 N 650434.25 E 1.216 2160.77 10234.84 42.630 307.580 9001.90 9072.50 1345.42 8 3116.22 W 5957479.24 N 650382.90 E 0.531 2223.16 10255.37 42.790 308.650 9016.98 9087.58 1336.828 3127.17 W 5957487.61 N 650371.77 E 3.620 2236.76 10320.50 42.790 308.650 9064.78 9135.38 1309.198 3161.73 W 5957514.53 N 650336.66 E 0.000 2279.88 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ~.' Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 295.730° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10320.50ft., The Bottom Hole Displacement is 3422.06ft., in the Direction of 247.507° (True). ---..- -- - -. -.- 23 July, 2002 - 14:45 Page 3 0'4 DrillQuest 2.00.08.005 North Slope Alaska Sperry-Sun Drilling Services Survey Report for D-178 Your Ref: API 500292069202 Job No. AKMW22096, Surveyed: 21 June, 2002 ~~~I BPXA "¡Iy/",,, PBU_WOA 0 Pad II/~ . . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment -/ 8391.70 8483.00 10320.50 7569.03 7642.32 9135.38 1682.01 S 1711.94 S 1309.19 S 2217.75 W 2263.20 W 3161.73 W Tie On Point Window Point Projected Survey Survey tool program for D-17B From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 8391.70 0.00 8391.70 7569.03 10320.50 7569.03 AK-1 BP _HG - BP High Accuracy Gyro (D-17) 9135.38 MWO Magnetic (O-17B) ~~ - ------~--- ------- 23 July, 2002 - 14:45 Page 40'4 DrillQuest 2.00.08.005 @~fK\'IT): riÜ d Lru J ib ') (j rr ¡l I~ ! u !I 1....-....' I,";. ) fK\ ~ fK\ @~ 1£ lJ=lj u lJ=lj ~ ll\\ ¡Jì~ / / .r / TONY KNOWLES, GOVERNOR AI¡A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. -¡TH AVENUE, SUITE 100 ANCHORAGE, .ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit D-17B BP Exploration (Alaska), Inc. Pennit No: 202-111 Sur Loc: 2100' SNL, 1692' WEL, Sec. 23, TIIN, RI3E, UM Btmhole Loc. 3418' SNL, 4881' WEL, Sec. 23, TIIN, RI3E, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 Qrder, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Û~ rQu~' t..[,.-/ Cammy ðechsli Tayk;;S' Chair BY ORDER O~ THE COMMISSION DATED this~ day of June, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ) ) 0" bp :, i,", ",,:,:;. , \", ',.-,'\', To: Winton Aubert - AOGCC Date: June 3,2002 From: Phil Smith- BPXA GPB Rotary Drilling Subject: Reference: D-17B Request for dispensation re: 7" liner RAMS API # 50-029-20692-02 Mr. Aubert: Approval is requested for dispensation from the requirement to install 7" rams during the installation of the 7" liner in the 0-178 sidetrack. This well has a planned whipstock exit at 8,500' MD from the existing 9 5/8" casing. An 8 %" intermediate hole will be drilled to the top of the Sag River formation, with a proposed casing point of 9,460' MD. There will be approximately 1 000 feet of 8 %" open hole. The entire open-hole section will be within the Kingak, reaching TO in the top Sag River. Generally, the Sag River is a finely grained sandstone of moderate porosity and low permeability. A well site geologist will be present and acquiring samples to determine top Sag River. The mud weight will be maintained at 10.6ppg throughout the running and cementing of the liner. With the liner lap, there will be approximately 1100 feet of 7" liner total length. This will be run in the hole on 4" HT drill pipe. Request for dispensation is based upon the relatively short length of 7" liner prior to having 4" drill pipe through the stack. Nabors 2ES currently has 3 %" X 6" V8R and 2 7/8" X 5" V8R installed. In the very unlikely event of a kick, the annular preventer would be closed on the liner. This would leave just one set of rams for stripping in the 4" drillpipe. Maintaining two sets of rams capable of closing on the 4" drillpipe is the safest alternative. Regards, Phil Smith Operations Drilling Engineer 564-4897 D-17B Application for 7" liner RAMS dispensation ALAS~ STATE OF ALASKA )OIL AND GAS CONSERVATION CO~ ')ISSION PERMIT TO DRILL 20 AAC 25.005 vJll'A- 1 b. Type of well 0 Exploratory, 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan RKB = 72$ Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028285 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / D-17B 9. Approximate spud date 06/15/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 1033T MD 19141' TVD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 45 Maximum surface 3100 psig, At total depth (TVD) 8800' I 3430 psig Setting Depth TQo Bo~om Lenath MD TVD MD TVD 1118' 8350' 7535' 9468' 8484' 1019' 9318' 8353' 1033T 9141' vJGA- S It t 10 L ~4~~ 1 a. Type of work 0 Drill a Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2100' SNL, 1692' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 3611' SNL, 4594' WEL, SEC. 23, T11 N, R13E, UM At total depth 3418' SNL, 4881' WEL, SEC. 23, T11N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028284,399' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8500' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casing Weiaht Grade Couolina 7" 26# L-80 BTC-M 4-1/2" 12.6# 13Cr80 Vam-Ace 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Hole 8-1/2" 6-1/8" Quantitv of Cement (include staae data) 236 cu ft Class 'G' 163 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11333 feet 9015 feet 1 0785 feet 8971 feet Length Plugs (measured) Tagged TOC at 10785' (09/2000) Junk (measured) Size Cemented MD TVD 110' 20" x 30" 2704' 13-3/8" 9518' 9-5/8" 661' 7" 2303' 2-7/8" 8 cu yds Concrete 3588 cu ft Permafrost 303 cu ft Class 'G' 403 cu ft Class 'G' 101 cu ft Class 'G' 110' 2704' 9518' 9011' - 9672' 9030' - 11333' ~. \.,,~,\, ,',1,)1 ;,1,:,':~ ,\,,,, 110' 2704' 8488' 8062' - 8624' 8078' - 9015 Perforation depth: measured 10465' - 10485', 10485' - 10535', 11030' - 11160' .-, ", ~ -.... : "' true vertical 8955' - 8960', 8960' - 8969', 8970' - 8969' ,,!it'inskJ ~¿.. 20. Attachments a Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch a Drilling Program a Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the forego.np !S _~¡.ê¡d correct to the best of my ~nowl~~ge . Signed Brian Robertson ~ [;h'U" / "Title Senior Dnlllng Engineer ~Col11misSion Use Only Permit Number API Number ~pJr~ll Rate See cover letter 202 -#/ 50- 029-20692-02 l, S U 1\ for other requirements Conditions of Approval: Samples Required 0 Yes .8 No Mud Log I~equired 0 Yes .No Hydrogen Sulfide Measures BI Yes 0 No Directional Survey Required )2ð Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU ~mélg¡~tãdßf' PE ~ ~5~o pSt ~ ~, J tJ~A- ), Cammy ~s~$;~1l1 Cot l-Rd U I\l-ÿ vet ,,",~ ~?Jt(,l'~ ,by order o.f . ( , /.. '7 Approved By Commissioner the commission Date 0 v / V) C\ Form 10-401 Rev. 12-01-85 0 RIG I N A L Suomi In Triplicate Date ~-z,,-t}¿ ) ) IWell Name: ID-178 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Conventional Sidetrack Producer I AFE Number: 4P1880 I Estimated Start Date: I 06/15/02 I I MD: 110,337' I I TVD: 19,141' I Surface Location: Estimated Target Location: Sadlerochit Zone 28 Bottom Hole Location: x = 653,471.00 2100' FNL , 1692' FEL X = 650,602.54 3611' FNL , 686' FWL X = 650,311.06 34181 FNL , 399' FWL Y = 5,958,888.00 Sec. 23, T11 N, R13E Umiat Y = 5,957,319.38 TVDss 8720 Sec. 23, T11 N, R13E Umiat Y = 5,957,506.45 TVDss 9066 Sec. 23, T11 N, R13E Umiat I RiQ: I Nabors 2ES ,// I OperatinQ days to complete: 114.0 I BF/MS: 142.98' I I RKB: 172.5' I Well DesiQn (conventional, slim hole, etc.): I Conventional Sidetrack I Objective: I Zone 28, Sadlerochit Casingrrubing Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDrrVD MDrrVD 81/2" 7" 26.0# L-80 8TCM -1118' 8350' /7535' 9468' /8484' ./ 61/8" 4 Y2" 12.6# 13Cr-80 Vam-Ace -1019' 9318' / 8353' 10337'/9141' Tubing 4 Y2" 12.6# 13Cr-80 Vam-Ace -9318' GL 9318'/8353' Directional KOP: 18,500' MD Maximum Hole Angle: Close Approach Well: Survey Program: D-178 Sidetrack -38.5° in original well bore at the kick-off / exit point of 8500' MD. -45.0° through reservoir section of planned sidetrack from 9847' MD to TD at 10337' MD. . There are no close approach issues of concern: The closest well to the D- // 178 is D-10 with a center-center distance of 796' and allowable deviation of 441' at the planned depth of 8589' MD. This well passes major risk criteria and will not be shut in while drilling. Standard MWD Surveys from kick-off to TD. Page 1 ') Mud Program Window Milling Mud Properties: LSND Density (ppg) Viscosity PV 10.4-10.5 50-60 10-13 Drilling Mud Properties: LSND Density (ppg) Viscosity 10.4 -10.5 j 45 - 55 PV 11 -15 Production Mud Properties: Quickdril-N Density (ppgy Viscosity PV 8.4 - 8.6 45 - 55 6 - 8 ) I Whip stock Window 9 5/8" I YP tauO HTHP pH API FI 25 - 35 6-8 <10 9.0 <6 I 8 Y2" Hole Section I YP tauO HTHP pH API FI 20 - 30 4-7 <10 8.5 - 9.0 <6 I 6 1/8" hole section I YP tauO MBT pH API FI 22 - 27 4-7 <3 8.5 - 9.0 N/C Logging Program 8 V2" Intermediate: Sample Catchers - None Drilling: MWD Dir/GR/Res- Real time GR/RES throughout entire interval. PWD Open Hole: None Cased Hole: Sample Catchers - Two, at Company man call out MWD Dir/GR/Res/Den/Neu - Real time GR/RES throughout entire interval; Recorded DEN/NEU only. None None 6 1/8" Production: Drilling: Open Hole: Cased Hole: Cement Procram ~ Casing Size 7" Intermediate Liner Basis: Lead: None Tail: Based on 85' of 7" shoe track, 968' of 8 Y2" open hole with 40% excess, and 150' of 9 5/8" x 7" liner lap (no 9 5/8/:,x 4" DP annulus volume). Tail TOC: -8350' I' MD (7535'TVDbkb).- Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 11 .5 ppg None / ~/ 42 bbl 1236 fe I 198 sks of Halliburton 'G' at 15.6 ppg and 1.19 dIsk, BHST 2000 @ 8300' TVDss TT = Batch Mix 4 to 4.5 hrs Casing Size I 4 V2" Production Liner Basis: Lead: None Tail: Based on 85' of 4 Y2" shoe track, 869' of 6 1/8" open hole with 400/0 excess, 150' of 4 Y2" x 7" liner lap, and 200' of 9 5/8" x 4" DP annulus volume. Tail TOC: -9318' /' MD (8354' TVDbkb).- Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail D-17B Sidetrack 30 bbls Alpha spar at 9.5 ppg None ./ 29 bbl I 163 ft3 I 137 sks of Halliburton 'G' at 15.6 ppg and 1.19 dIsk, BHST 2150 @ 8800' TVDss TT = Batch Mix 4 to 4.5 hrs Page 2 ) ") Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. /' BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3430 psi "/8800' TVOss - Ivishak . Maximum surface pressure: 3100 psi @ surface (based upon BHP and a full column of gas from TO @ 0.10 psi/ft) No annular injection in this well. / Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . Planned BOP test pressure: . Planned completion fluid: . . . Formation Markers Formation Tops (Wp#3) LCU KINGAK KINGAK F KINGAK D TOP KINGAK A SAG RIVER SS TSHU/SHUBLlK EILEEN TSADITZ4B TZ3 TZ2C TZ2B WD-22TS WD-21 TS THOT TZ1B TZ1A BSAD TD Criteria: Target polygon 0-17B Sidetrack MD 8,240 8,240 8,452 8,960 9,364 9,462 9,502 9,592 9,849 9,942 10,051 10,106 10,179 1 0,186 10,300 N/A N/A 3500 psi 8.6 ppg seawater /7.2 ppg Diesel TVDss -7362 -7362 -7540 -7968 -8320 -8405 -8440 Comments 10.4 ppg minimum mud density for stability -8518 -8721 -8787 -8864 " -8903 3430 psi /7.4 ppg emw / -8955 -8960 -9040 -9095 -9150 Page 3 ) ) Sidetrack and Complete Procedure Summary Ria Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 5 }'2" tubing from cut. 5. Change out 9 5/8" casing packoff if necessary. 6. MU window milling BHA drift down to the KOP. Change well over to milling fluid. Test casing to 3000 ",/ psi. 7. Set bridge plug on wireline at ::1:8520' such that the window will not be cut through a casing collar. 8. RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on bridge plug. Mill window in casing at::l: 8500' MD. Perform FIT to 11.5 ppg. POOH( 9. Kick-off and drill the 8 }'2" section as per the directiona~lan to top of Sag River formation. 10. Run and cement a 7" drilling liner, displace with mud. 11. Test casing to 3000 psi. Drill out shoe and 20' of new formation, displace well to 8.5 ppg QuickDRILn mud. 12. Drill 6 1/8" production hole as per directional plan to TO well at::l:1 0,337' MD. 13. Short trip, CBU, spot liner running ~, POH. 14. Run and cement a 4 ¥2", 12.6#, 13-Cr solid production liner to TO. Displace with perf pill and seawater. Set liner top packer. Circulate the well to clean seawater at the liner top, POOH. 15. Test the well (all casing strings) from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 16. Run 4 }'2", 12.6# 13-Cr completion tying into the 4 }'2" liner top. ( 17. Set packer and test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well. 20. Rig down and move off. Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 4. Perforate. D-17B Sidetrack Page 4 ) ) ~,:~,~,W,~»~~~1'm~~~~,~,~ff:1I#,,,*,.~,~~~:I!=~ .~~%~'m~,)¡~,.fu~.~."..",I":,~",.",,,; Job 1: MIRU Hazards and Contingencies » No wells will require shut-in for the rig move to 0-17. The two closest wells are 0-16 and 01-18, each on 110' centers. » O-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Closest BHL Wells D-16 10ppm H2S (2/22/2002) D-01 10ppm H2S (8/05/2000) D-18 No recorded H2S D-10 10ppm H2S (4/21/2002) // The maximum level recorded of H2S on the pad was 20 ppm. D-17A measured 10 ppm in November, 2000. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud ~"""'~M"'''' ":<I«_:~~"""W.'U.'''"''_.''_,',,,,~~~,,,,,,, """""""""'~~""""""""""'''''''''"""^,N"^"""",,^^'''Y'''''''''''''''__''',',¡,,.,-,,U.'W.W.,._. -............... Job 2: De-complete Well Hazards and Contingencies » The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. » NORM test all retrieved well head and completion equipment. » A Kinley caliper from November 2000 revealed some extensive corrosion plus possible holes in six joints of tubing. The corrosion appears on one side of the pipe; pull up to 80% of the pipe body yield strength will be acceptable. ~~~~:-':'X~~~:o:-o~m~~':,~~::::j~~~:-:.'I~,~,~:(,) ,:<,~~:(,~:~~~':: ¡»'m~~'m¡~~~:I::~**~~:::~~~~m«~ ~~:::::<:='<~ «::::*t::~~:<:::I'~<~~ffl' ¡ ~~~'~<<::~~»:O:~~-:ffl'i'I~~~~«:X::::-:~':::~ffl¡~:<:I'I¡:H~~~;ffl~¡~~~~ ~'~<~~~~~::::::::~~~~¡'¡~,,~ Job 3: Run Whipstock Hazards and Contingencies » Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. «<<<>:<<..NU,U<<"."N"._"UMMN."".""<~-<<:-:_-"'¡<<<<<<:+<<<-I~~---_<<O:<<<<<<...:..<<oMo(.-(_o:.!'«<(>«:+'«o.«oI_...A«<_--«<- _:«-:U"'-""-'~"""^""'~,<~'- Job 4: Drill 8 Y2" Intermediate Hole Hazards and Contingencies ~ The well will be kicked off in the Kingak shale so well bore stability is a major concern. Ensure the mud weight does not drop below the minimum stated requirement. Use PWD to ensure good drilling and connection practices. ~ KICK TOLERANCE: In the worst-case scenario of 9.6ppg pore pressure at the Sag River depth, a fracture gradient of 11.0ppg at the 9 5/8" casing window, and 10.6ppg mud in the hole, the kick tolerance is infinite. Job 6: Install 7" Intermediate DrillinQ Liner Hazards and Contingencies ~ Minimize surge while RIH with the drilling liner. The pad data sheet list several wells where lost circulation occurred during the cement job. D-17B Sidetrack Page 5 ) ) ~~lj~~~m~m::::::~~~,~:-I:I:I~ ~~ffl~<~~~,~,-:,:-:-~~~,~,*,~,.,.,Im::..,ffl,~,~~~ ;!,~~ffl:ln~ Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ There are no anticipated fault crossings while drilling D-178. ~ This well bore will land in the Kavik shale with relatively low mud weight. Operations should be planned to minimize the open hole time after well TD to avoid de-stabilizing the shale. ~~m~,~,~~~~,~:::'~:~'¡:""""¡»'~1~~W~,:,:_;,~,~,~,:w.c,~,~,I~: ~~~,~,~~~,*,~,,,,,-~~,~,",~~~~~,~~~~,:~,~~~,'::,~',~~1':':.:,,:-:-,;.'~W:t:l~ Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg Quickdril will be -400 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. D-178 Sidetrack Page 6 ') ') Job 12: Run Completion Hazards and Contingencies )0> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release RiQ Hazards and Contingencies )0> Though there are no close proximity surface issues, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. 0-178 Sidetrack Page 7 TREË = 6" CrN WELLHEAD= MCEVOY . ÀCTUATOR;" ,"" "'" oilS 'KEr'EC8J';'; ," """"""""78:93' BF.äE\i;'4i9á 'ï<oP';;"""" ',,",",,", '''''''''''2'90'0; 'MïiïxArÏQie ';;; "97.Sö@1Ó97S; 'ÖãtumMD ;;;"""""'16616' .".. .. ,. "'......".."" .... "..... .'... ..... Datum lVDss= 8800' ') D-17A Pre RiJ 8 I z- ~ 1998' 1-151/2" HES DMY SSSV, 10=3.10" 2608" 1-19 5/8" DV Packer Z 113-3/8" 72#, L80, BTRS Casing 1-1 2704' 1- ~ L ST MD 12 3001 11 5082 10 6273 9 6427 8 6991 7 7146 6 7541 5 7697 4 8021 3 8168 2 8598 1 8748 GAS LIFT MANDRELS lVD DEV TYPE SIZE L TCH 2921 7° OTIS 5 1/2 RA 4745 37° OTIS 51/2 RA 5687 36° OTIS 51/2 RA 5812 36° OTIS 5 1/2 RA 6273 33 ° OTIS 5 1/2 RA 6403 32° OTIS 51/2 RA 6742 30° OTIS 51/2 RA 6878 28° OTIS 51/2 RA 7166 2]0 OTIS 51/2 RA 7298 27° OTIS 5 1/2 RA 7654 40° OTIS 5 1/2 RA 7772 38° OTIS 51/2 RA COMMENTS 151/2" 17.0# L-80 IPCTubing ~ y I Pre-rig tubing cut 1-1 8600' I Tubing Seal Assembly I 95/8" Baker Packer; 4.75" 1.0. 151/2" "XA" Sliding Slv; 1.0.=4.562" 1-1 8860' 1-1 8906' 1-1 8926' I I I ~ I Z I 11 1 Pre-rig CTU Cement P&A; TOe 1-1 8940' I TOP OF 7" Liner 1-1 9011' I ITOPOF 2-7/8" Linerl-l 9029' I 19-5/8" 47#, L80, BTRS Csg 1-1 9518' 1-" :~:~:~:;, 9006' 1-14-1/2" OTIS 'X' NIP, 10=3.813 I 9030' 1-1 PBR & GS Fishing neck 9045' 1-14-1/2" 12.6#, L-80 TBG TAIL ~ .. I Millout Window 1-1 9672' ... \'IIIAII~ , I I 11333' 1-127/8" FL4S Liner, 6.16#, L-80, .0058 bpf ~ r 7" 26#, L80, BRTS Liner 1-1 10483' 1- DA TE REV BY COMMENTS 01/17/02 D8N Proposed Pre Rig CTU Cement P&A; Tubing cut. PRUDHOE BA Y UNIT WELL: D-17A PERMfT No: 196-046 API No: 50-029-20692-01 Sec. 22,T11N,R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 WELLHEAD= MCEVOY ...... ......".......,..".......,,, ". . ..."."......... ..." "'" A CTUA TOR= OTIS KS:êLEV ;" .,',' w,,,.. " "72:98~" , Bi=:ËLB,i;;;' 42.98 ....... .".. .." .,,, "." KOP = 8500' ~~'~':~~~i~'~','~i'5'~'@984 7' Datum MD = """""""'10Ú37; Dî3iumWDss; .. "gÒ35í D-1 i .8 Proposed Co.hpletion J ~ 113-3/8" 72#, L80, BTRS Casing 1-1 2704' 1- ~ 141/2" 12.6# 13 Cr-80 Tubing Top of 7" 26#, L-80, BTC-M Liner 1-1 8350' 1 Top of Whip Stock 1-1 8500' I Bridge Plug l-i 1-1 8518' 8600' I Pre-rig tubing cut I I z- ~ 2200' 1-141/2" 'X' Landing Nipple, ID=3.813" 2608" 1-19 5/8" DV Packer GAS LIFT I'v1ANDRELS lVD DEV TYPE SIZE 3000 7.2° OTIS 4 1/2 X 1 1/2 3750 22.0° OTIS 4 1/2 X 1 1/2 5500 37.r OTIS 4 1/2 X 1 1/2 6000 35.7° OTIS 4 1/2 X 1 1/2 7250 26.0° OTIS 4 1/2 X 1 1/2 8250 29.8° OTIS 4 1/2 X 1 L TCH COMMENTS RA RA RA RA RA RA L ST MD 6 3000 5 3776 4 5938 3 6562 2 8026 1 9200 :> I I 9228' 1-14-1/2" 'X' NIP, ID=3.813" I ~I 9253' 1-17" X 4 1/2" Baker S-3 Packer I -I 9278' 1-i4-1/2" 'X' NIP, ID=3.813" -I 9303' 1-14-1/2" 'XN' NIP, ID=3.725" 9318' - Baker 5"X7" Tieback Sleeve; 'ZXP Liner top packer; 'HMC' Liner hanger ~ ¡/ I 7" 26#, L-80, BTC-M Liner 1-1 9468' 151/2" "XA" Sliding Slv; I.D.=4.562" 1-1 8860' I I I Tubing Seal Assembly 1-1 8906' I I I 95/8" Baker Packer; 4.75" I.D. 1-1 8926' ~ Z I I Pre-rig CTU Cement P&A; TOC 1-1 8940' 9006' 1-14-1/2" OTIS 'X' NIP, ID=3.813 I I TOP OF 7" Liner 1-1 9011' I ITOPOF 2-7/8" Linerl-1 9029' I 9045' 1-14-1/2" 12.6#, L-80 TBG TAIL I I 9-5/8" 47#, L80, BTRS Csg 1-1 9518' I-~ I Millout Window 1-1 9672' I 7" 26#, LBO, BRTS Liner 1-1 10483' I I ~I1H) II~ 141/2" 12.6#, 13 Cr-80, Liner 1-1 10337' I 11 .. -~ ~ I 11333' 1-127/8" FL4S Liner, 6.16#, L-80, .0058 bpf COMMENTS DA TE REV BY 01/17/02 DEW Proposed completion for D-17B. 01/22/02 DEW Update proposed completion for o.17B with new GLM design. PRUDHOE BAY UNrT WELL: o.17A PERMrT No: API No: 50-029-20692-02 Sec. 22,T11N,R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 ò 7500- 7800 8100 c 2: 0 Ë 'E. 8400 Ö ~ > '"' ¡:: 8700 9000 9300 COMPANY DETAII$ REFERENCE INFORMATION IWAffit'ICO Co.onJîn.11~ (N,E) Referen....~: \Vell Cenlre: D-17, Trœ North Vcrtio:aJ (n'D) Re¡¡'rence: 7450' 7450 s.."tion (VS) Reforence: Use, DofiIL'd (.171622N.-2269.95E) Moa,u,,:'¡ 0..;></1 Roferenœ: 7450' 7450 CakuJalion Metbed: Minimum Curvature Cak-ublk1lt M\."thc...I: MinÎmlalI CUI\':]hllC Em" Sy"'--m: ISCWSA ~an Mctl)o.x.I: T r.i\' Cylin&:r North Em1r Surr;¡(:c: Elliphc:J1 . Casing W3mi~ ~1L-thnd: Ruk.-s IbSl.-d SURVEY PROGRAM Plan: D-17Bwp03 (D-17/D-I7B HighKO) Depth Fm Dopth To SlIIwy,Plan 8500.00 10337.21 Planœd: O-I7B wp03 VI Tool Cr031ed By: Ken Allen Dale: 12/1 81200 I M\\'D Checked: Date:- Rcviewed: Darc:- WELL DETAILS Name -'-NI-S Northin¡! Longitude Slot ~F-'-W Easting Latitude 0-17 3270.79 137250 5958887.99 653471.00 70'IT40.659N 148"4526314W 17 TARGET DETAILS Nam: 1VD 'Nf-S ~E'-W Northing 5957859.46 5957449.44 Easting Shap" 650510.19 Polygon 650400.26 Polygon 0-17B TI 899950 -967,94 -2981.41 0-17B Polygon 903450 -1375,66 -3099,70 SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TF ace VSee Target I 8500.00 38.55 237.10 7656.48 -1716.22 -2269.95 0.00 0.00 0.00 2 8520.00 38.82 240.92 7672.09 -1722.65 -2280.67 12.00 85.00 7.26 3 9106.24 29.85 303.92 8170.46 -1730.84 -2571.50 6.00 129.67 270.61 4 9594.63 29.85 303.92 8594.08 -1595.22 -2773.19 0.00 0.00 509.69 '- 5 9847.21 45.00 303.92 8794.08 -1509.82 -2900.19 6.00 0.01 660.23 6 10187.21 45.00 303.92 9034.50 -1375.66 -3099.70 0.00 0.00 896.71 D-17B Polygon 7 10337.21 45.00 303.92 9140.57 -1316.47 -3187.71 0.00 0.00 1001.04 CASING DETAILS : 9106.24' MD, 8170.46' TVD : 9594.63' MD. 8594.08'TVD ---~---~_._----~--_. 300 Vertical Section at 293.54° [300ft/in] All TVD depths are ssTVD plus 74.50' for RKBE. No. TVD MD Name Size I 2699.40 2699.57 133/8" 13.375 2 7656.48 8500.00 9 5/8" 9.625 3 8484.50 9468.30 7" 7.000 4 9140.56 10337.20 4 1/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8642.09 9650.97 1Z4 2 8794.50 9847.80 TCGurz3 3 8864.50 9946.79 BCGL 4 9034.50 10187.21 HOT Depth: 10337.21' MD. 9140.57' TVD ~ /lQ, I 1200 I 1500 '/~ ...J1'" ~ ~ /' " bp #~~ 'it~i c Õ ~ ~ ï: 0 z ~ -1600 Õ (/) COMPANY DETAII$ REFERENCE INFORMA nON IWAmlK:o Cl"HXdinate (N-E) Reft.~oc~: Well Centre: D-17. True North V~rtical (IVD) Re~reDCe: 7450' 7450 &~tion (V5) Reference: User Defirk."d (-171622N.-2269.95E) M""suTI:d D-.;>Ih Rofore...,,: 7450' 7450 Cakul.1tiol1 Mcthcd: Minímwn Cmvature Cakulalion M\.1htd: Minimum Cw\";m.rn: Em.,- Svst':OI: ISCWSA Scan ~(clhoJ: To", C)1ind.:r North Errl.,r SWb\7~: Elliptiç.J1 . Casing Wamin~ MI..1Ikk.l: Ruk.-s Ib~"" CASING DETAILS Æ~~ /~n..............:~ ; ( ./1 ì .iJi~>l ~i ",,'."'/lj,>,~ . .. I ~I /7) I: i // /1 ~~/~>: ; II/A. ' . . , 1// )"~ I~! '-, ,"l'~_"~h'-'-""/~'- /~ "'~~ ~~~~ -" No. TVD MD Name Size I 2699.40 2699.57 13 3/8" 13.375 2 7656.48 8500.00 9 5/8" 9.625 3 8484.50 9468.30 7" 7.000 4 9140.56 10337.20 4 1/2" 4.500 FORMATIONTOPDETA~S No. TVDPath MDPath Fonnation I 8642.09 9650.97 TZ4 2 8794.50 9847.80 TCGUTZ3 3 8864.50 9946.79 BCGL 4 9034.50 10187.21 HOT -1400 Total Depth: 10337.21' MD, 9140.57' TVD D-17B W." p03 T" ". ' 'h\C ,,,-. \ 4,', 1/2" ".'" ""',' ..... I I ~.,\.. QL 17B Poygon \'fCX. 'i9ô'oo ~ 70% eonf. ~. -" "- '''''''' ^"\."'"End Dir ::9847.21' MD, 8794.08' TVD ',,- '... '''--.. '-...., .'''---....,- Start Dir till 00' : 95~4.ti1' MD. 8594.08TVD '. ",.....,,~ 7" ' o..::::~. 8500""'_' ¡ h""'-'_'.,~,.,,_I '-l~~"'-....,. EndDir :9 06.24'MD.8170.46'TVD¡-------''''''''''h',,,, ' . ~_."'-~."'V.-~.....~.~... -1800 -2800 í -2600 West( - )/East( + ) [200ft/in] ----- SURVEY PROGRAM Plan: D-17B wp03 (D-171D-17B High KO) Depth Fm Deptl. To Surw)'" Plan 8500.00 10337.21 P1anœd: 0-179 ....pB VI T""I Created By: Ken Allen Checked: Date: 12118/200 I MWD Dale:- Reviewed: Dale:- WELL DETAILS NaIœ -'-N'-S -'-El-W Northing fasting Latitude longitude Slot D-11 3270.79 137250 5958881.99 653471.00 70"IT40.659N 148"45'263I4W 11 TARGET DETAILS Nan>: TVD -õ--Nf-S ~EI-W Northing 5957449.44 Easting Sbape 65Q.ID026 Polygon 0-178 Polygon 9034.50 -1375.66 -3099.70 SECTION DETAILS -See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSec Target I 8500.00 38.55 237.10 7656.48 -1716.22 -2269.95 0.00 0.00 0.00 2 8520.00 38.82 240.92 7672.09 -1722.65 -2280.67 12.00 85.00 7.26 - 3 9106.24 29.85 303.92 8170.46 -1730.84 -2571.50 6.00 129.67 270.61 4 9594.63 29.85 303.92 8594.08 -1595.22 -2773.19 0.00 0.00 509.69 5 9847.21 45.00 303.92 8794.08 -1509.82 -2900.19 6.00 0.01 660.23 6 10187.21 45.00 303.92 9034.50 -1375.66 -3099.70 0.00 0.00 896.71 0-178 Polygon 7 10337.21 45.00 303.92 9140.57 -1316.47 -3187.7] 0.00 0.00 ] 00 1.04 All TVD depths are ssTVD plus 74.50' for RKBE. 95/8" ~ 8000 ...p/\ Start ~ir 12/100': 8500' MD, 7656.48'TVD ---': : ,,'" DI' 6/100' : 8520' MD. 1672.09"rVD - 3400 -3000 -2400 I -2200 I -2000 Prudhoe 8ay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level P8 D Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Company: 8P Amoco Field: Prudhoe 8ay Site: P8 0 Pad Well: D~17 Wellpath: D-178 HighKO Field: Site: ) BP Amoco Planning Report - Geographic ) Date: 12/18/2001 Time: 18:39:47 Co-ordinate(NE) Reference: Well: D-17, True North Vertical (TVD) Reference: 74.50' 74.5 Sectiori (VS) Reference: User (-1716.22N,-2269.95E,293,54Azi) Plan: 0-178 wp03 Page: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre 8GGM2001 5955590.34 ft 652165.06 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 8.492 N 148 46 6.316 W True 1.16 deg D-17 D-17 Surface Position: +N/-S 3270.79 ft +E/-W 1372.50 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 3270.79 ft +E/-W 1372,50 ft Well: Wellpath: D-178 High KO Current Datum: Magnetic Data: Field Strength: Vertical Section: Plan: D-178 wp03 Principal: Yes Plan Section Information 8500.00 38.55 8520.00 38.82 9106.24 29.85 9594.63 29.85 9847.21 45.00 10187.21 45.00 10337.21 45.00 Section 1: Start MD Incl ft deg 8500.00 38.55 8520.00 38.82 Section 2: Start MD Incl ft deg 8550.00 37.69 8600.00 35.92 8650.00 34.29 8700.00 32.83 8750.00 31.56 8800.00 30.51 Slot Name: 17 Northing: 5958887.99 ft Latitude: 70 17 40.659 N Easting : 653471.00 ft Longitude: 148 45 26.314 W Northing: 5958887.99 ft Latitude: 70 17 40.659 N Easting : 653471.00 ft Longitude: 148 45 26.314 W Measured Depth: 34.00 ft Inclination: 0.00 deg Vertical Depth: 34.00 ft Azimuth: 0.00 deg 74.50' 11/12/2001 57493 nT Depth From (TVD) ft 7656.48 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft -2269.95 D-17 8500.00 ft Mean Sea Level 26.46 deg 80.78 deg Direction deg 293.54 12/18/2001 1 From: Definitive Path Height 74.50 ft +N/-S ft -1716.22 Date Composed: Version: Tied-to: Azim TVD +E/-W DLS Build Turn TFO dég ft ft dég/100ft deg/100ft. deg/100ft dég 237.10 7656.48 -1716.22 -2269.95 0.00 / 0,00 0.00 0.00 240.92 7672.09 -1722.65 -2280.67 12.00 1.36 19.08 85.00 303.92 8170.46 -1730.84 -2571.50 6.00 -1.53 10.75 129.67 303,92 8594.08 -1595.22 -2773.19 0.00 0.00 0.00 0.00 303.92 8794.08 -1509.82 -2900.19 6.00 6,00 0.00 0,01 303.92 9034.50 -1375.66 -3099,70 0,00 0.00 0.00 0.00 303.92 9140.57 -1316.47 -3187.71 0.00 0.00 0.00 0.00 Target D-178 Polygon Azim TVD +N/-S +E/-W VS DLS Build Turn TFO deg ft ft ft ft deg/100ft deg/10OO deg/10OO deg 237.10 7656.48 -1716.22 -2269.95 0.00 0.00 0.00 0.00 0.00 240.92 7672.09 -1722.65 -2280.67 7.26 12.01 1.35 19.10 85.04 Azim TVD +N/-S +E/-W VS DLS Build Turn TFO deg ft ft ft ft deg/100ft deg/10OO deg/100ft deg 243.19 7695.65 -1731.36 -2297.07 18.82 6.00 -3.76 7.55 129.67 247.22 7735.69 -1743.93 -2324.24 38.71 6.00 -3.55 8.08 127.89 251.61 7776.60 -1754.06 -2351.14 59.32 6.00 -3.26 8.77 124.66 256.35 7818.27 -1761.70 -2377.68 80.60 6.00 -2.92 9.49 121.07 261.46 7860.59 -1766.84 -2403.79 1 02.48 6.00 -2.53 10.21 117.12 266.91 7903.44 -1769.47 -2429.41 124.92 6.00 -2.10 10.91 112.79 ') BP Amoco ) Planning Report - Geographic Company: BP Amoco Date: 12/18/2001 Time: 18:39:47 Page: 2 Field: Prudhoe Bay Co;.ordinate(NE) Reference: Well: 0-17, True North Site: PB 0 Pad Vertical (TV D) Reference: 74.50' 74.5 Well: D-17 Section (VS) Reference: User (-1716.22N,-2269.95E,293.54Azi) Wellpath: D-17B High KO Plan: D-17B wp03 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1 OOftdeg/1 OOft deg/100ft deg 8850.00 29.70 272.67 7946.70 -1769.58 -2454.47 147.85 6.00 -1.62 11.52 108.12 8900.00 29.15 278.68 7990.26 -1767.17 -2478.89 171.20 6.00 -1.10 12.01 103.14 8950.00 28.88 284.84 8034.00 -1762.24 -2502.60 194.91 6.00 -0.55 12.32 97.90 9000.00 28.89 291.05 8077.78 -1754.80 -2525.55 218.92 6.00 0.02 12.43 92.51 9050.00 29.19 297.20 8121.51 -1744.89 -2547.67 243.16 6.00 0.59 12.31 87.07 9100.00 29.75 303.19 8165.05 -1732.52 -2568.90 267.56 6.00 1.14 11.98 81.69 9106.24 29.85 303.92 8170.46 -1730.84 -2571.50 270.62 5.99 1.53 11.66 75.54 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/100ft deg/100ft deg 9200.00 29.85 303.92 8251.78 -1704.80 -2610.23 316.52 0.00 0.00 0.00 0.00 9300.00 29.85 303.92 8338.51 -1677.02 -2651.53 365.48 0.00 0.00 0.00 0.00 9400.00 29.85 303.92 8425.25 -1649.25 -2692.83 414.44 0.00 0.00 0.00 0.00 9500.00 29.85 303.92 8511.98 -1621.47 -2734.13 463.40 0.00 0.00 0.00 0.00 9594.63 29.85 303.92 8594.08 -1595.22 -2773.19 509.69 0.00 0.00 0.00 0.00 Section 4: Start InCl DES Build Tl.lrn TFO deg deg/100ft deg/100ft degI100ft deg 9600.00 30.17 303.92 8598.73 -1593.72 -2775.42 512.33 6.00 6.00 0.00 0.01 9650.00 33.17 303.92 8641.28 -1579.07 -2797.20 538.15 6.00 6.00 0.00 0.01 9700.00 36.17 303.92 8682.39 -1563.20 -2820.80 566.12 6.00 6.00 0.00 0.01 9750.00 39.17 303.92 8721.97 -1546.15 -2846.15 596.18 6.00 6.00 0.00 0.01 9800.00 42.17 303.92 8759.88 -1527.97 -2873.19 628.23 6.00 6.00 0.00 0.01 9847.21 45.00 303.92 8794.08 -1509.82 -2900.19 660.23 5.99 5.99 -0.01 -0.05 Section 5: Start Incl deg 9900.00 45.00 303.92 8831.41 -1488.99 -2931.17 696.94 0.00 0.00 0.00 180.00 10000,00 45.00 303.92 8902.12 -1449.53 -2989.84 766.50 0.00 0.00 0.00 180.00 10100,00 45.00 303.92 8972.83 -1410.07 -3048.52 836.05 0.00 0.00 0.00 180.00 10187,21 45.00 303.92 9034.50 -1375.66 -3099.70 896.72 0.00 0.00 0.00 180.00 Section 6: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 10200.00 45.00 303.92 9043.54 -1370.61 -3107.20 905.61 0.00 0.00 0.00 180.00 10300.00 45.00 303.92 9114.25 -1331 .15 -3165.88 975.16 0.00 0.00 0.00 180.00 10337.21 45.00 303.92 9140.57 -1316.47 -3187.71 1001.04 0.00 0.00 0.00 180.00 Survey Map Map <-- Latitude ---> <--- Longitude --> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ft ft ft ft ft 8500.00 38.55 237.10 7656.48 -1716.22 -2269.95 5957125.91 651236.73 70 17 23.777 N 148 46 32.458 W 8520.00 38.82 240.92 7672.09 -1722.65 -2280.67 5957119.26 651226.14 70 17 23.713 N 148 46 32.770 W 8550.00 37.69 243.19 7695.65 -1731.36 -2297.07 5957110.22 651209.92 70 17 23.628 N 148 46 33.248 W 8600.00 35.92 247.22 7735.69 -1743.93 -2324.24 5957097.09 651183.01 70 17 23.504 N 148 46 34.039 W 8650.00 34.29 251.61 7776.60 -1754.06 -2351.14 5957086.42 651156.34 70 17 23.404 N 148 46 34.823 W 8700.00 32.83 256.35 7818.27 -1761.70 -2377.68 5957078.24 651129.96 70 17 23.329 N 148 46 35.596 W 8750.00 31.56 261.46 7860.59 -1766.84 -2403.79 5957072.56 651103.96 70 17 23.278 N 148 46 36.357 W 8800.00 30.51 266.91 7903.44 -1769.47 -2429.41 5957069.41 651078.40 70 17 23.252 N 148 46 37.104 W 8850.00 29.70 272.67 7946.70 -1769.58 -2454.47 5957068.79 651053.35 70 17 23.251 N 148 46 37.834 W 8900.00 29.15 278.68 7990.26 -1767.17 -2478.89 5957070.71 651028.89 70 17 23.275 N 148 46 38.545 W 8950.00 28.88 284.84 8034.00 -1762.24 -2502.60 5957075.15 651005.08 70 17 23.323 N 148 46 39.236 W ) BP Amoco Planning Report - Geographic CQmpany: BPAmoco Field: Prudhoe Bay Site: PB DPad Well: 0-17 Wellpath: 0-178 High KO Survey 9000.00 9050.00 9100.00 9106.24 9200.00 9300.00 9400.00 9500.00 9594.63 9600.00 9650.00 9700.00 9750.00 9800.00 28.89 29.19 29.75 29.85 29.85 29.85 29.85 29.85 29.85 30.17 33.17 36.17 39.17 42.17 9847.21 45.00 9900.00 45.00 10000.00 45.00 10100.00 45.00 10187.21 45.00 10200.00 45.00 10300.00 45.00 10337.21 45.00 ) i Date: 12/18/2001 Time: 18:39:47 Co;.ordinate(NE) Reference: Well: 0-17, True North Vertical (TVD) Reference: 74.50'74.5 Section (VS) Reference: User (-1716.22N,-2269.95E,293.54Azi) Plan: D.,17B wp03 Azim deg 291.05 297.20 303.19 303.92 TVD ft 8077.78 8121.51 8165.05 8170.46 Map Northing ft 5957082.12 5957091.58 5957103.51 5957105.14 Map Easting ft 650981.98 650959.67 650938.19 650935.56 +N/-S ft -1754.80 -1744.89 -1732.52 -1730.84 +E/-W ft -2525.55 -2547.67 -2568.90 -2571.50 303.92 8251.78 -1704.80 -2610.23 5957130.38 650896.31 303.92 8338.51 -1677.02 -2651.53 5957157.30 650854.46 303.92 8425.25 -1649.25 -2692.83 5957184.23 650812.60 303.92 8511.98 -1621.47 -2734.13 5957211.15 650770.74 303.92 8594.08 -1595.22 -2773.19 5957236.60 650731.16 303.92 8598.73 -1593.72 -2775.42 5957238.05 650728.90 303.92 8641.28 -1579.07 -2797.20 5957252.25 650706.82 303.92 8682.39 -1563.20 -2820.80 5957267.64 650682.91 303.92 8721.97 -1546.15 -2846.15 5957284.17 650657.21 303.92 8759.88 -1527.97 -2873.19 5957301.79 650629.81 303.92 8794.08 -1509.82 -2900.19 5957319.38 650602.45 303.92 8831.41 -1488.99 -2931.17 5957339.57 650571.06 303.92 8902.12 -1449.53 -2989.84 5957377.82 650511.59 303.92 8972.83 -1410.07 -3048.52 5957416.07 650452.13 303.92 9034.50 -1375.66 -3099.70 5957449.43 650400.26 303.92 9043.54 -1370.61 -3107.20 5957454.32 650392.65 303.92 9114.25 -1331.15 -3165.88 5957492.57 650333.19 303.92 9140.57 -1316.47 -3187.71 5957506.81 650311.06 Page: 3 <--- Latitude ---> <--- Longitude ---> Deg Min Sec Deg Min' Sec 70 17 23.396 N 148 46 39.905 W 70 17 23.494 N 148 46 40.550 W 70 17 23.615 N 148 46 41.169 W 70 17 23.632 N 148 46 41.244 W 70 17 23.888 N 148 46 42.373 W 70 17 24.161 N 148 46 43.577W 70 17 24.434 N 148 46 44.781 W 70 17 24.707 N 148 46 45.984 W 70 17 24.965 N 148 46 47.123 W 70 17 24.980 N 148 46 47.188 W 70 17 25.124 N 148 46 47.823 W 70 17 25.280 N 148 46 48.510 W 70 17 25.447 N 148 46 49.249 W 70 17 25.626 N 148 46 50.037 W 70 17 25.804 N 148 46 50.824 W 70 17 26.009 N 148 46 51.727 W 70 17 26.397 N 148 46 53.437 W 70 17 26.785 N 148 46 55.148 W 70 17 27.123 N 148 46 56.640 W 70 17 27.173 N 148 46 56.858 W 70 17 27.561 N 148 46 58.569 W 70 17 27.705 N 148 46 59.205 W H 206706 DATE INVOICE I CREDIT MEMO ". 0409û2 CK040902H PYMT COMMENTS: HANDL:NG INST: r? .:::< J\'cr;}{S l~;: r -- GROSS I iOO 00 PERr1IT TO DR ILL tEE - I S/H - TERRIE HUBBLE X4628 DESCRIPTION t ; 'I Ù' \ I ß '. . . .,. TOTAL ~ 100.001 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY FIRST NATIONAL BANK OF ASHLAND - AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 ---¡:j2 I :-. {¡ : ~A~E .. .-. --. -Jli L.I~ / 1 1 / ~.j¿ I OOC~~~~ ;~=L~, I VENDOR DISCOUNT ALA5KAOILA . NET iOO. 00 iO(J.OO No. H 206706 CONSOLIDATED COMMERCIAL ACCOUNT 00206706 ONE HUNDRED & OOil00************************************* US DOLLAR To The ORDER Of DATE 04/11/02 AMOUNT $100- 00 NOT VALID AFTER 120 DAYS ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE O~, () ß/V,~~j,.{ '\ .~~ -'~.' ..., '\:..:.- III 20 b 70 bill 1:0 L. ¡. 20 ~8 q 51: OOB L. L. ¡. qui AK 99501 « uu H -- -- CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL / EXPLORA TION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates , " ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME D- /7 B CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "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). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. 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. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY If' k WELL NAME -"~ .(J - /?~ FIELD & POOL 6o/C?I.~ INITCLASS /JPé/ /-¡?;/ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . ~R JtT~ 12. Permit ca~ be issued without administrativ~ approval.. . . . . - ~~tZ...-- 13. Can permit be approved before 15-day walt.. . . . . . . . . . ~ ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥---tN- 15. Surface casing protects all known USDWs. . . . . . . . . . . .'¥~ ./IA- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~ f'lf J 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -¥---N-. j 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 4M e¡ (.(..Av te ~ œc... s: Cvvt..,\ . ~~: ~~:~~a~:~~~~~:~~i~:~~~~ ~¡t:: ~ ~ :~r~~fr.o~t.. : : : : : : &J ~ Ai l E £ 21. If a re-drill, has a 10-403 for abandonment been approved. .. * b N 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . æ' N 23. If diverter required, does it meet regulations. . . . . . . . . . "-¥-ff"" /IL/I\- 24; Drilling fluid program schematic & equip list adequate. . . . . & N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~zy¿ N. JI APPR DAT~ 26. BOPE press rating appropriate; test to 3500 psig. N ¡II[ ~ p:: 3100 p.f ( .. \dC(Ä-S/1..lf{O l... 27. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . - N í 0 ff1 41t. 30. Permit can be issued wlo hydrogen sulfide measures. . . .. )r' n;) 31. Data presented on potential overpressure zones. . . . . . . y~.......... ¿ J LJ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /1/ iT7 . A~J3R D~T9 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ~ .þ~}1> - 34. Contact namelphone for weekly progress reports [exploratory on/~ Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan N / APPR DATE ~~~ ::: :~:~t:~~~:;: ~:sU~~:::r~o~e::~eZ~~~i~~ ~~s;e'. '.: ~ ~ !t.JA. -1'/. } to surface; I ~ Y.P.-Y6? ~ (C) will not impair mechanical integrity of the well used for disposal; V/ N (D) will not damage producing formation or impair recovery from a //Y N pool; and' (E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. / Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMiSsioN: RPP/¿ GEOLOGY JDH WGA ¡J6pY tJ~ PROGRAM: Exp - Dev - Redrll ~ Serv - Wellbore seg - Ann. disposal para req - f\ GEOL AREA ~'1('? UNIT# 11t;Ç Ò ON/OFF SHORE ~ J 'yjN Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N \y,N ( ( Comments/l nstructions: COT r / DTS O~0S'/02 ~ft\ G:\geology\permits\checklist.doc ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history file. To improve the readability of the Well History file and to simpHfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. '~ Sperry-Sun Drilling Services LIS Scan utility $Revi,sion: 3 $ LisLib $Revision: 4 $ Thu Mar 06 16:58:31 2003 Reel Header Service name.............LISTPE Date.....................03/03/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments..... ............STS LIS Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 031 031 06 Origin. . . . . . . . . . . . . . . . . . . S'l'S Tape Name................ UNKNOWN Continuation Nurober......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . s'rs LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS If WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: if JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22096 J. SACK J. RALL 1 D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) If WELL CASING RECORD ) W~iting Library. Scientific Technical Services Writing Library. Scientific Technical Services D-17B 500292,069202 BP Exploration Sperry Sun 06-MAR-03 (Alaska), Inc. MWD RUN 3 AK-MW-22096 R. MCNEILL R. BORDES 1 MAD RUN 3 AI\-MW-22 0 96 R. MCNEILL R. BORDES 1 23 UN 13E 2100 1692 .00 27.62 42.98 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8483.0 6.125 7.000 9454.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO KICK OFF FROM D-l7A a{JÇ)~ III 11(¿,~3/ ) ) wrfH TOP OF WHIPSTOCK SE'l' A'l' 8483' MD, 7642' TVD. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER. TUBE, DETECTORS, AND E,LE,CTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. MWD RUN 3 WAS DIREC'I'IONAL WI'I'H DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN),AND STABILIZED LITHO DENSITY (SLD) . 6. GAMMA RAY DA'l'A IN THE INTERVALS 7941' MD TO 8476' MD, 7629' TVD (IN THE CASING ABOVE THE KICKOFF POINT) AND 9450' MD, 8469' TVD TO 10281' MD, 9107' TVD WERE ACQUIRED ON A MEASUREMENT AE'T'ER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE FOLLOWING MWD RUN 3. MAD PASS DATA, WAS CORRECTED TO THE MWD GAMMA RAY DATA. 7. DIGITAL AND l'()G DATA ARE DEPTH SI-IIF'I'ED TO THE PDC GR LOG, (SCHLUMBERGER LOG RUN 07/12/02) PER 10/7/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 8. MWD RUNS 2-3 REPRESENT WELL D-17B WITH API # 50-029-20692-02. THIS WELL REACHED A TOTAL DEPTH ('I'D) OF 10320'MD / 9135' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) SEXP = SMOOTHED PHASE SHALLOW SPACING) SESP = SMOOTHED PHASE SPACING) SEMP = SMOOTHED PHASE SPACING) SEDP = SMOOTHED PHASE SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME TNPS = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DE'I'ECTOR' S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SHIFT DERIVED RESISTIVITY ( EXTRA SHIFT DERIVED RESI S'I'IVITY (SHALLOW SHI F'r DERIVED RESISTIVITY (MEDIUM S¡'UFT DERIVED RESISTIVITY (DEEP SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) CURVES WITH "M" SUFFIX DENOTE MAD PASS DATA PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 8.5" AND 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 850 TO 300 PPM CHLORIDES FORMATION WATER SALINITY: 10,990 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name........ .....STSLIB.001 Service Sub Level Name... ) ), Verston Number.......... .1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.OOO Cormnent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: if FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI PEE' RHOB DRHO $ 1 ) clipped curves; all bit runs merged. .5000 START DEPTH 7941. 5 8476.5 8476.5 8476.5 8476.5 8476.5 8515.5 9371. 0 9371.5 93"71.5 9386.5 9451. 5 9451.5 STOP DEPTH 10275.5 10280.0 10280.0 10280.0 10280.0 10280.0 10321.0 10236.0 10236.5 10236.0 10251. 5 10251. 5 10251. 5 if BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 7941.5 7959.0 7963.5 8014.5 8046.0 8066.0 8084.5 8097.0 8126.0 8139.5 8160.0 8190.0 8214.0 8223.5 8303.0 8437.0 8524.0 8551.0 8586.0 8651. 0 8846.0 8915.0 9011. 0 9041.5 9070.0 9103.0 9269.5 9375.0 9452.0 9464.5 9497.5 9505.0 9533.0 9541.0 9565.0 9579.5 9590.0 9595.0 9613 .5 9621. 5 9637.5 DEPTH GR 7938.0 7955.5 7959.5 8010.5 8042.0 8062.0 8081.5 8093.5 8121.5 8135.0 8156.0 8186.5 8209.5 8219.5 8300.5 8436.5 8524.5 8551.0 8586.0 8651.0 8845.0 8915.5 9009.5 9040.0 9069.0 9101.5 9267.0 9373.5 9451. 0 9463.5 9496.5 9505.5 9533.5 9541.0 9565.0 9578.5 9588.5 9593.5 9613.5 9621. 5 9637.0 ') ) 9654.0 9670.0 9685.5 9693.0 9822.0 9839.0 9851. 5 9863.5 9891.5 9942.5 9975.0 10005.0 10025.0 10047.5 10081. 0 10139.0 10197.5 $ 9652.0 9669.5 9683.0 9690.5 9820.5 9836.5 9849.5 9860.5 9890.5 9939.5 9971. 0 10002.5 10022.5 10045.0 10079.5 10136.0 10194.5 # MERGED PBU MWD MWD ,$ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 7938.0 3 9456.5 MERGE BASE 9456.0 10321.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rap Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD F'r/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 RHOB MWD G/CC 4 1 68 32 9 DRHO MWD G/CC 4 1 68 36 10 PEF MWD BIE 4 1 68 40 11 NPHI MWD PU 4 1 68 44 12 NCNT MWD CP30 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7941. 5 10321 9131.25 4760 7941. 5 10321 ROP MWD FT/H 0 499.19 58.5326 3612 8515.5 10321 GR MWD API 11. 01 551.03 87.8301 4669 7941.5 10275.5 RPX MWD OHMM 0.45 1298.98 13.2491 3608 8476.5 10280 RPS MWD OHMM 0.47 1373.55 16.4398 3608 8476.5 10280 RPM MWD OHMM 0.49 2000 39.6581 3608 8476.5 10280 RPD MWD OHMM 0.35 2000 37.755 3608 8476.5 10280 FET MWD HR 0.31 55.49 5.13629 3608 8476.5 10280 RHOB ¡vrwD G/CC 2.111 2.86 2.3296 1601 9451.5 10251.5 DRHO MWD G/CC -0.042 0.348 0.0563023 1601 9451.5 10251.5 PEF MWD B/E 1.5 14.44 2.96274 1731 9386.5 10251.5 NPHI MWD PU 2.95 61. 4 23.418 1730 9371. 5 10236 NCNT MWD CP30 14362 55627 29618.6 1731 9371 10236 FCNT MWD CP30 117 4528 778.091 1731 9371.5 10236.5 'í) ') First Reading For Entire File..........7941.5 Last Reading For Entire File. ...... ....10321 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/06 Maximum Physical Record..65535 FUe Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/06 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FCNT NCNT NPHI PEF DRHO RHOB FET RPD RPM RI?X RPS RA'r 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 7941. 5 7941. 5 7941. 5 7941. 5 7941.5 7941.5 7941.5 7948.0 7948.0 7948.0 7948.0 7948.0 7990.5 $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 7938.0 MERGE BASE 10321.0 # REMARKS: MERGED MAD PASS. $ STOP DEPTH 10281.5 10245.0 10244.5 10244.5 10260.5 10260.5 10260.5 10288.5 10288.5 10288.5 10288.5 102B8.5 10324.0 # Data Format Specification Record Data Record Type.. ................0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN May. frames per record............ .Undefined Absent value..................... .-999 Depth Unit,s....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT / H 4. 1 68 4. 2 GR MAD API 4 1 68 8 3 ) ) RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 ;:> RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 PET MAD HR 4 1 68 28 8 RHOB MAD G/CC 4 1 68 32 9 DRHO MAD Glee 4 1 68 36 10 PEF MAD B/E 4 1 68 40 11 NPHI MAD PU 4 1 68 44 12 NCNT MAD CP30 4 1 68 48 13 FCNT MAD CP30 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7941.5 10324 9132.75 4766 7941.5 10324 RAT MAD FT/H 7.91 3825.37 232.909 2718 7990.5 10324 GR MAD API 11.93 529.06 69.7254 2734 7941. 5 10281.5 RPX MAD OHMM 0.47 405.35 16.0215 2739 7948 10288.5 RPS MAD OHMM 0.5 485.95 19.6177 2739 7948 10288.5 RPM MAD OHMM 0.61 2000 570.814 2739 7948 10288.5 RPD MAD OHMM 0.03 2000 187.198 2739 7948 10288.5 FET MAD HR 21.18 121.47 62.2398 2739 7948 10288.5 RHOB MAD G/CC 1. 566 2.879 2.19657 2594 7941. 5 10260.5 DRHO MAD G/CC -0.796 0.776 0.143483 2594 7941..5 10260.5 PEF MAD B/E 1.5 14.79 3.78854 2679 7941.5 10260.5 NPHI MAD PU 4.29 89.17 38.2323 2655 7941.5 10244.5 NCNT MAD CP30 13224 53514 24028.8 2655 7941.5 10244.5 FCNT MAD CP30 78 3578 512.358 2657 7941. 5 10245 First Reading For Entire File..........7941.5 Last Reading For Entire File...........10324 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 File Type................ LO Next File Name..... ......STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Nurnber...........1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 Fì 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP 3 header data for each bit run in separate files. 2 .5000 START DEPTH 7938.0 8476.5 8476.5 8476.5 8476.5 8476.5 8515.5 STOP DEPTH 9407 .0 9417.0 9417.0 9417 . 0 9417 .0 9417.0 9456.0 ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-rrrME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOT1'OM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) Nr TEMPERATURE (DEGE') MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRA.TE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): If TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units....... ....Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ) 18-JUN-02 Insite 66.37 Memory 9456.0 8483.0 9456.0 28.7 38.2 TOOL NUMBER PB00225HWGR6 PB00225HWGR6 8.500 8483.0 LSND 10.60 55.0 9.5 1000 3.8 3.200 1.670 3.500 2.900 75.0 150.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 OHMM 4 1 68 28 8 First Last ) ) Name Service Unit Min Max Mean Nsam Reading Reading DEPT f'T 7938 9456 8697 3037 7938 9456 ROP MWD020 f'T/H 0 499.19 56.1249 1882 8515.5 9456 GR MWD020 API 33.14 206 110.034 2939 7938 9407 RPX l'1W0020 OHMM 0.99 1298.98 2.67715 1882 8476.5 9417 RPS MWD020 OHMM 0.95 1373.55 3.08811 1882 8476.5 9417 RPM MWD020 OHMM 0.94 2000 15.027 1882 8476.5 9417 RPD MWD020 OHMM 0.86 2000 5.88471 1882 8476.5 9417 FET MWD020 OHMM 0.31 3.02 1.16737 1882 8476.5 9417 First Reading For Entire f'ile..........7938 Last Reading For Entire File...........9456 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.. ...,. ......ST81IB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 F i 1 e '1' yp e. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FI1E NUMBER: RAIN' MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FI 1E SUMMARY VENDOR '1'001 CODE GR FCNT NCNT PEF NPHI FET RPD RPM RPS RPX ORHO RHOB ROP $ 4 3 .5000 START DEPTH 9407.5 9408.0 9408.0 9408.0 9408.0 9415.5 9415.5 9415.5 941,5.,5 9415.5 9452.0 9452.0 9456.5 # LOG HEADER DATA DATE 10GGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (fT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (fT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DE PTH 10272.5 10236.0 10235.5 10251.0 10235.5 10279.5 10279.5 10279.5 10279.5 10279.5 10251. 0 10251.0 10320.5 21-JUN-02 Insite 66.37 Memory 10320.0 9456.0 10320.0 30.0 44.2 # TOOL STRING (TOP TO VENDOR TOOL CODE CTN SLD DGR EWR4 $ BOTTOM) TOOL TYPE COMP THERMAL NEUTRON STABILIZED LITHO DEN DUAL GAMMA RAY ELEC'I'ROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): if BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHI,ORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (M'I'): MUD AT MAX CIRCULATING TERMPERATURE: MUD f'IL'TRATE AT WI': MUD CAKE AT 1'1T: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORREC'I'ION (IN): 'rOOL STANDOFF (IN): EÞ\TR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value..................... .-999 Depth Unì ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER PB00224HAGR4 PBOO224HAGR4 PB00224HAGR4 PB00224HAGR4 6.125 9454.0 QUICKDRILn 8.40 52.0 9.6 300 14.0 2.900 1. 230 3,200 3.300 71.0 176.0 71.0 71.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEP'r FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR 1'1WD030 API 4 1 68 8 3 RPX MWD030 OI-IMM 4 1. 68 12 4 RPS MWD030 OHMM 4 1 68 16 ,5 RP1'1 1'1WD030 01-11'11'1 4 1 68 20 6 RPD 1'1WD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 RHOB MWD030 GICC 4 1 68 32 9 DRI-IO MWD030 G/CC 4 1 68 36 10 PEF 1'1WD030 B/E 4 1 68 40 11 NPHI MWD030 PU 4 1. 68 44 12 NCNT MWD030 CP30 4 1 68 48 13 FCNT HWD030 CP30 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9407.5 10320.5 9864 1827 9407.5 10320.5 ROP MWD030 FT/H 0.7 201.73 61..0158 1729 9456.5 10320.5 GR MWD030 API 11. 01 551.03 49.9573 1731 9407.5 10272.5 RPX MWD030 OHMM 0.45 903.65 24.9797 1729 9415.5 10279.5 RPS ¡V!WDO 3 0 OHMM 0.47 678.06 31.3013 1729 9415.5 10279.5 RPM l'IWD030 OI-lHM 0.49 2000 70.4799 1729 9415.5 10279.5 ) RPD MWD030 OHMM 0.35 1808.8 75.6882 1729 9415.5 10279.[1 FET MWD030 HR 1.13 55.49 9.59096 1729 9415.5 10279.5 RHOS MWD030 Glee 2.111 2.86 2.32929 1599 9452 10251 DRHO MWD030 Glee -0.042 0.348 0.0561657 1599 9452 10251 PEF MWD030 B/E 1.5 14.44 2.71461 1687 9408 10251 NPHI MWD030 PU 2.95 61. 4 22.2371 1656 9408 10235.5 NCNT MWD030 CP30 14362 55627 30224.2 1656 9408 10235.5 FCNT MWD030 CP30 117 4528 805.79 1657 9408 10236 First Reading For Entire File..........9407.5 Last Reading For Entire File...........10320.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/06 Maximuffi Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOr Fi.le I-Ieader Service name............. .ST8LIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record ETLE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: II FILE SUMMARY VENDOR TOOL CODE GR RHOB DRHO FCNT NPHI NCNT PEF RPX RPS RPM RPD FET RAT $ 5 header data for each pass of each run in separate files. .5000 3 1 START DE PTH 7938.0 7938.0 7938.0 7938.0 7938.0 7938.0 7938.0 7944.5 7944.5 7944.5 7944.5 7944.5 7986.5 II LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10278.5 10257.5 10257.5 10242.0 10241.5 10241.5 10257.5 10285. .5 10285.5 10285.5 10285.5 10285.5 10321. 0 21-JUN-02 Insi,te 66.37 Memory 10320.0 7940.0 10320.0 30.0 44.2 TOOL STRING (TOP TO VENDOR TOOL CODE CTN SLD DGR EWR4 $ BOTTOM) TOOL TYPE COMP THERMAL NEUTRON STABILIZED LITHO DEN DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) l-\T TEMPERA1'URE (DEGE') MUD AT MEASURED 'rEMPERATURE (M'r): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MA'I'RIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): it REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing...... ...............60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Unl ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER PB00224HAGR4 PBOO224HAGR4 PB00224HAGR4 PB00224HAGR4 6.125 9454.0 QUICKDRILn 8.40 52.0 9.6 300 14.0 2.900 1. 230 3.200 3.300 71. 0 176.0 71.0 71.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD031 FT/H 4 1 68 4 2 GR MAD031 API 4 1 68 8 3 RPX MAD03.1 OHMM 4 .1 68 12 4 RPS MAD031 OHMM 4 1 68 16 5 RPM MAD031 OHMM 4 1 68 20 6 RPD MA0031 OHMM 4 .1 68 24 7 FET MA0031 HR 4 1 68 28 8 RHOB MA0031 G/ec 4 .1 68 32 9 DRHO MAD031 GICC 4 1 68 36 10 PEF MAD031 BIE 4 .1 68 40 11 NPHI MAD031 PU 4 1 68 44 12 NCNT MAD031 CP30 4 1 68 48 13 FCNT MAD031 CP30 4 1 68 52 14 First Last Name Service Unit Min Max Jvlean Nsam Reading Reading DEPT FT 7938 10321 9129.5 4767 7938 10321 RAT MAD031 FT/H 7.91 3825.37 233.475 2722 7986.5 10321 GR MAD031 API 11.93 529.06 69.6496 2737 7938 10278.5 RPX MAD031 OHMM 0.47 405.35 15.8502 2742 7944.5 10285.5 RPS MA0031 OHMM 0.5 485.95 19.4451 2742 7944.5 10285.5 RPM MA0031 OHMM 0.61 2000 575.304 2742 7944.5 10285.5 ) ) RPD MAD031 OHMM 0.03 2000 189.175 2742 7944.5 10285.5 FET MAD031 HR 21.18 121.47 62.4442 2742 7944.5 10285.5 RHOS MAD031 G/CC 1. 566 2.879 2.1961 2596 7938 10257.5 DRHO MAD031 G/CC -0.796 0.,776 0.142879 2596 7938 10257.5 PEF JvlA.D031 B/E 1.5 14..79 3.80339 2681 7938 10257.5 NPHI MAD031 PU 4.29 89.17 38.3213 2657 7938 10241.5 NCNT MAD031 CP30 13224 53514 23998.9 2657 7938 10241. 5 FCNT MAD031 CP30 78 3578 510.56 2659 7938 10242 First Reading For Entire Fi1e..........7938 Last Reading For Entire File...........10321 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/06 Maximum Physical Record..65535 File Type................ LO Next File Name. ..........STSLIB.OO6 Physical EOF Tape Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . .03/03/06 Origin. . . . .... . . . . . . . .. . . STS T ape Name................ UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wd ting l,ibrary. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/03/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ............UNKNOWN Continuation Number......01 Next Reel Name....... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS J..JIS Wri ting Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
