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Home My WebLink About202-045 I mya Project Well History File Cov -)Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;)():J. - 0 ~ Well History File Identifier -I ~escan Needed OVERSIZED (Scannable) Organizing (done) R':FAN 'vi ~ Color items: V Grayscale items: 0 Poor Quality Originals: 0 Two~Sìded DIGYL DATA ¡,ø'" Diskettes, No. 0 Maps: Other items scannable by large scanner 0 Other, NofType 0 0 Other: OVERSIZED (Non-Scannable) 0 Logs of various kinds NOTES: BY: BEVERLY ROBIN VINCENT SHER~INDY . 0, Other DATE:'! Jl ÓLf V/1!) J ' . J: lb': TOTAL PAGES % mO ~~ Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation I x 30 = ¡':S C) + BY: BEVERLY ROBIN VINCENT SHERYL E;YINDY DATE:if J.J olfSI . Production Scanning ß d Stage 1 PAGE COUNTFROM SCANNED FILE: If 7 CtrJ~ p~ a.£1~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: VYES NO BEVERL V ROBIN VINCENT sHERV@ WINDV DA TEÎŠ '¡ c¡ I D't-'S! VVlP Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (iI}(1i\'idu;.// pJg'"! [;¡p0r:i.l1 M10!HiO!1j .sc,}ìnillg ::ompll~'od) RESCANNED By< BEVERL'( ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (do)e) 12/10/02Rev3NOTScanned.wpd ,~ • • ~~Q~~ 0~ Q~Q~~{Q /,~,.~~.~~o~..~ John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. ,.~'`~::~.':_~~,~€,~ a,lk r, . `i'~ ~~ ~~~k.'.; P.O. Box 196612 ~ ~ ~~~ Anchorage, AK 99519-6612 4'1 (°~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-28A Sundry Number: 310-155 Dear Mr. Egbejimba: 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. 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 May, 2010. Encl. i~ STATE OF ALASKA ~`~' ~g~' S~L~~ ALASK~ AND GAS CONSERVATION COMMIS~I ~/~/D APPLICATION FOR SUNDRY APPROVAL MAY 1 $ 20~ 20 AAC 25.280 1. Type of Request: ,~~~ ^ Abandon ®Plug for Redrill , ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-045 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20867-01-00 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 C-28A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028305 & 028310 Prudhoe Bay Field / Prudhoe Bay 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): 11708' ~ 9032' - 11676' - 9031' - 9931' None Caain Len th Size MD TVD Burst Colla e Structural Conductor 1 1 ' Surface 2744' 1 / " 2744' 27 49 2 7 Intermediate 10232' -5/8" 1 2 2' 437' 870 47 0 Production Liner 728' 7" 9 91' - 1071 8243' - 2' 7240 541 Liner 1683' 3-1/2" x 3-3/16" x 2-7/8" 10 2 ' - 11708' 8271' - 0 2' 1 160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 11030' - 11676' 9029' - 9031' 4-1/2", 12.6# L-80 10719' Packers and SSSV Type: 9-5/8" x 4-1/2" BKR HB Packer Packers and SSSV 9965' / 8221' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 26, 2010 ~ ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG ®Suspended -, Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Charles Red Holds, 564-5480 Printed Name John Egbejimba Title Engineering Team Leader Prepared By Name/Number Signature ' ~ Phone 564-4191 Date ~ j ~ /" D Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: N fy Commission so that a representative may witness Sundry Number: ~~~" ~ ~~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance 35oa ,Os~ .Q~P E.sf' ~. ~ Other: ~ / / S .~- / _ _ ~ ~wr Subsequent Form Required: r 6- y0 APPROVED BY D ~ ~ '~ Approved By: OMMISSIONER THE COMMISSION Date Fom, 10-40~13~ is /2~Y 2 py ~ ~ B 1 vQR1GINA~. Submit In Duplicate i~ sz,-,~ • • .~~' ., ti~ 3~. .r?~ `J ~ .T ~ ~ ~sPaf~~1'~r~~~'1~t5 ~~r~ C-28A Well Type: Producer Current Status: The well is currently shut-in and secured with a TTP in the nipple reducer at 9931' MD MIT - T x IA Passed to 3000 psi 10/10/09 MIT - OA Passed to 2000 psi 10/10/09 Request: Approval is requested for the P&A of PBU well C-28A. C-28A is a horizontal Zone 2A coil - sidetrack drilled in March 2002. The well was drilled with approximately 780' in Z2A with 250' initially perforated. The well came on strong and produced at low GOR, but declining oil rates and increased gas rates prompted the 40' Z2A toe adperf in July 2003. The oil buzz was short-lived and the well began to cycle. A second Z2A adperf job (1 1 030-1 1 080' MD) was attempted in Aug 2004 without any benefit. The well continued to cycle with diminishing on-time until April 2006 when the well was shut-in for TxIA communication (failed a TIFL). A LDL run in May 2007 found a tubing leak at 6661' MD. A Baker one- run patch was set at 6650-6678' MD, and aMIT-IA passed to 3000 psi on 8/17/07 thereby returning this well to operable status. The well only flowed for 4 months before it was shut-in for TxIA communication again. The TecWel LDL run in June 2008 identified several tubing leaks. C-28A is currently shut-in and secured with a TTP in the nipple reducer at 9931' MD. During RST screening in Oct 2009, the well passed a CMIT-TxIA to 3000 psi and MIT-OA to 2000 psi; indicating the production casing and the production packer have integrity. The PPPOT-T & -IC also both passed. A caliper of the tubing was run in June 2006 and showed the 4-1/2" tubing was in average condition with a max wall penetration of 64% but no significant areas with cross-sectional wall loss or with ID restrictions. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram i drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing . wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: The sidetrack plan for the C-28B (an Ivishak Z2A producer) includes the following during pre-rig operations: pull 4-1/2" tubing patch, pull XX plug, pull nipple reducer, bullhead cement across the perforations and the 4-1/2" tubing will be cut 600' below planned whipstock exit point. The whipstock exit from the 9-5/8" casing is estimated at 8400' MD and will be milled using an 8-1 /2" milling assembly. The 8-1/2" hole will be drilled to the Top of the Sag River where a 7" drilling liner will be run to 150' inside the 9-5/8" casing. The 7" drilling liner will have 1,000' of cement at the shoe. The production hole will be drilled with a 6-1/8" BHA building to horizontal. The well will then run horizontally through the Ivishak formation. The production liner will be 4-1/2" L-80 and fully cemented. Tubing will be 4-1/2" 13Cr, tied into the top of the production liner. r,~ v-~ /. y ('~,°r LLB. }'rg~'r~f~~ ~P MASP: 2352 Estimated Pre-Rig Start Date: May 26, 2010 f:~ ~, `i~~J~+l ~~~~~ ~~ ~~ .-Y Jf Elf M~~~.J vn ~~ ~c~ ~,z e r (~iC~r-,~v,9 v ~? ct1y2/~ ,~,-~M j(,Y • Pre-Rip Operations: W 1 PPPOT-IC, PPPOT-T F 2 MIT-IA, MIT-OA S 3 Pull straddle atch, XX lu and ni le reducer. Drift tubin for 'et cut F 4 Confirm in'ectivit as re uired for P&A to follow. F 5 Bullhead Cement P&A S 6 Drift for 'et cut to TOC and to . F 7 Combo MIT-TxIA E 8 Jet cut tubin @ 9000' MD. F 9 Circ well to 1 % KCL and freeze rotect. CMIT- TxIA D 10 Bleed casin and annulus ressures to zero. V 11 Set BPV. Remove well house and flow line. Level ad as necessa Rig Operations: 1. MI / RU Doyon Rig 141 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Set and test TWC to 1,000 psi from above and below. 4. Nipple down tree & tubing adapter. Nipple up and test BOPE to 3,500psi high/ 250psi low. Pull TWC. --~ 5. R/U & pull 4-1/2" tubing from the cut depth at 9000' MD. ~! Tsf' LPR s 6~"Sf 7 SZ~,~~ 6. R/U & Run 9-5/8" cleanout BHA down past EZSV setting depth 7. RIH with HES EZSV bridge plug on E-line and set as required to avoid cutting a casing collar while milling the window. 8. Pressure-test the 9 5/8" casing to 3,500 psi for 30 minutes. Record test. 9. Change out 9-5/8" Pack offs 10. P/U and RIH with 9 5/a" Baker bottom-trip anchor whip stock assembly. Orient whipstock and set on EZSV bridge plug. Shear off of whip stock. ~' C. 8y00` N'o 11. Displace the well to LSND based milling fluid. Completely displace the well prior to beginning milling casma. oius aoorowmateiv ~u~ oevona m Pfd clean. 13. Pull up into 9-5/8" casing and perform LOT. POOH. y 14. M/U 8-~/z" MTR GR/RES/MWD assembly. RIH, kick off and drill the 8-'/2" intermediate section with LSND drilling fluid. ~r~ 15. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the well clean, short trip as needed. POOH. 16. Change out to 7" rams, and test to 250 psi / 3,500 psi 17. MU and run 7", 26#, L-80, VamTop HC liner to bottom on drill pipe. Circulate and condition the hole. 18. Pump 1000' of cement behind the 7" liner. Test the liner to 3,500 psi for 30 charted minutes. 19. Set the hanger and packer. 20. Circulate bottoms up, POOH, VD liner running tool (LRT). 21. Change out rams to variable and test to 250 psi / 3,500 psi 22. M/U the 6-%8" Dir/GR/DEN/NEU/Res assembly with an insert bit. Pick Up DP as necessary. 23. RIH, Drill out of cement and 7" liner float equipment. 24. Displace to 8.4 ppg Flo Pro Fluid. 25. Continue drilling out the 7" shoe plus ~20' new formation, pull up into the shoe and perform a FIT. 26. Drill the 6-%s" production interval as per directional plan to TD. 27. POOH. UD BHA. 28. MU and RIH to bottom with 4-'h", 12.6#, L-80 solid liner. This will include 150' liner lap inside the 7" drilling liner. 29. Cement the liner. 30. Set liner top packer and displace well to clean seawater above the liner top. a. A pert pill will be left in the 4-'/z" liner. 31. POOH, VD LRT. 32. Pressure test casing and liner to 3,500 psi for 30 minutes. 33. RU DPC pert guns, RIH and p• rate. Perf intervals to be supplied by ass• 34. R/U and run a 4-'/z", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-'/z" liner tie back sleeve. 35. Space out and make up tubing hanger per Cameron Rep. 36. Land the tubing hanger, and run in lock down screws. 37. Circulate Corrosion Inhibitor. 38. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 39. Shear Circulating Valve 40. Set a BPV. 41. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 42. Freeze protect the well to 2,200' TVD. Secure the well. 43. RD and Move Off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Replace the DCK shear valve with a dummy GLV. 3. Install well house and instrumentation. 4. Modify S- Riser As Needed. Drilling Engineer: Charles Reynolds (907) 564-5480 Production Engineer: Alice Kaminski (907) 564-5676 Geologist: Adam VanHolland (907) 564-4477 TREE= 4-1/16" FMC WELLHEA'D= McEVOY _ ACTUATOR = BAKER KB. ELEV = 72.59' BF_ ELEV = 37.29' KOP = 2150' Max Angle = 96 @ 11612' Datum MD = 10767' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2742' Minimum ID = 2.31" @ 9931' 4-1/2" X 2-7/8" NIPPLE REDUCER 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" SAFETY NOTES: WELL ANGLE > 70° @ 10970' C_28A &~@11103'. I~ 2006' -~4-1/2" OTIS SSSVN, ID = 3.813 " 2595' 9-5/8" DV COLLAR GAS LIFT MANDRELS ^ ST MD TVD DEV TYPE VLV LATCH PI 650' '6678 ~~4-1/2" BAKER PATCH SET, ID = 2.45" 9931' 4-1/2" OTiS X NIP w / 2-7/8" NP REDUCER, ID = 2.31" 9931' 2-7/8" XX PLUG (12/06/07) 9942' BKR PBR SEAL ASSY 9965' 9-5/8" X 4-1/2" BKR HB PKR, ID = 3.985" 9991' 9-5/8" X 7" BOT SHORTY LNR HGR 10025' H 3.70" BKR KB LT PKR w / GS, ~ = 2.56" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 10232' 3-3/16" TBG, 6.2#, L-80, .0076 bpf, ®= 2.786" 4-1/2" TNV WHPSTOCK (03/11/02) H 10719' RA PP TAG 10728' 4-1/2" GBP 10800' PERFORATION SUMMARY REF LOG: MCNL ON 03/20/02 ANGLE AT TOP PERF: 79 @ 11030' Note: Refer to PPoduction DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 2" 6 11030 - 11080 C 08/12/04 2' 4 11200 - 11450 C 03/21/02 2" 6 11636 - 11676 C 07/22/03 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~-{ 10378' H BKR SEAL LOCATOR ID = 2.39" 10382' 3-3/4" BKR DEPLOY SLV, ~ = 3.000" 10384' BTM BKR SEAL ASSY, ID = 2.39" 10391' 3-1/2" XN NIP, ID = 2.750" 4-1/2" & 7" MILLOUT WINDOW 10719' - 10730' (OFF WHIPSTOCK ) 10766' MILLABLE 3-3/16" X 2-7/8" XO, ID = 2.377" IPBTD 1 7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.377" H 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/05/83 ORIGINAL COMPLETION 11/15/06 006/TLH PERF DATE CORRECTION 08/13/89 RIG WORKOV ER 07!14/07 MGS/PJC RAL PX 8~ SET NP RED; XX PLUG 03/22/02 CTD SIDETRACK (C-28A) 08/04/07 GJB/SV PATCH SET (07/29/07) 05/19/06 KSB/TLH GLV GO (05/13/06) 08/21/07 SWGPJC RILL XX RUG 06/21/06 BSE/PJC SET CAT STANDING VALVE 12/14/07 KDGPJC SETXX PLUG @9931' {12/06/07) 09/15/06 JRP/TLH PALL CAT V LV/SET PX PL PRUDHOE BAY UNff WELL: G28A PERMfT No: 2020450 API No: 50-029-20867-01 SEC 19, 711 N, R14E 1865' SNL 8~ 1033' WEL BP Exploration (Alaska) i TREE = 4-1 /16" FMC WELLHEA4= McEVOY ACTUATOR = BAKER KB. ELEV = 72.59' BF. ELEV = 37.29' KOP = Max Angle = Datum MD = 2150' 36 @ 11612' 10767' Datum TVD = 8800' SS Calculated TOC of "Permafrost C" 13-3/8" CSG, 72#, L-80, ID = 12.347 Calculated 9-5/8" TOC ~ 2 $ A SAFETY NOTES: WELL ANGLE > 70° ~ 10970' 8~ > 11103'. Pre-Rig 2006' 41 /2" OTIS SSSV N, ID = 3.813 " O 2595' - 9-518'• DV COLLAR 2200' GAS LIFT MANDRELS 2742' MD TVD DEV TYPE VLV LATCH PORT DATE 3255 3044 42 OTIS DMY RA 0 05/13/06 I 5720' I Minimum ID = 2.31" ~ 9931' 4-1/2" X 2-718" NIPPLE REDUCER 41 /2" TBG, 12.6#. L-80, .0152 bpf, ID = 3.958" 9942' I Calculated T' TOC C~ PKR I 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 10232' 3-3116" TBG, 6.2#, L-80, .0076 bpf, ID = 2.786" TIWWHIPSTOCK (03!11/02) ~ 10719' RA PIP TAG 10728' a-1/2" CIBP 10800' PERFORATION SUMMARY R~ LOG: MCNL ON 0312U/02 ANGLE AT TOP P82F: 79 @ 11030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE 2" 6 11030 - 11080 C 08/12/04 2" 4 11200 - 11450 C 03/21 /02 2" 6 11636 - 11676 C 07/22/03 9000' f--IJet Cut Tubing 9965' Planned TOC 9931' I--14-1/7' OTIS X NIP 9842' HBKRPBRSEALASSY 9965' 9-5/8" X 4-1/2" BKR HB PKR, ID = 3.985" 9991' 9-5/8" X T' BOT SHORTY LNR HGR 10025' 3.70" BKR KB LT PKR w / GS, ID = 2.56" 10378' BKR SEAL LOCATOR, ID = 2.39" 000" ID = 3 10382' 3-3/4" BKR DEPLOY SLV , . 10384' BTM BKR SEAL ASSY, ID = 2.39" ID = 2 750" 1/2" XN NIP ' 3 . - , 10391 ' " I4RLLOUT WINDOW 4112 & T 10719' - 10730' (OFF WHIPSTOCK ) 10766' MILLABLE 3-3/16" X 2-7/8" XO, ID = 2.377" 11676' PBTD H 1115x' 7" LNR, 26#, L-80, .0383 bpf, O = 6.276" 11212' DATE REV BY COMMENTS DATE REV BY CO 01105!83 ORIGINAL COM PLETION 1 H PERF DATE CORREC 08/13/89 RIG WORKOV H2 07/14/07 MGSlPJC PULL PX & SET NIP R 03/22702 CTD SIDETRACK (C-28A) 08/04/07 GJB/SV PATCH SET (07/29/0 05/19/06 KSBlTLH GLV GO (05/13106) 08/21/07 SWGPJC PULL XX PLUG 06/21/06 BSE/PJC SET CAT STANDING VALVE 12/14/07 KDClPJC SET XX PLUG @993 09/15/06 JRPfT1.H PULL CAT VLV/SET PX FLU 2-7i8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.37T' ~ 11708' ~ MMENTS PRUDHOE BAY UNIT TION WELL: G28A ®; XX PLUG PERMIT No: '2020450 7) API No: 50-029-20867-01 SEC 19, T11 N, R14E 1865' SNL & 1033' WEL 1' (12/06707) BP Exploration (Alaska) TREE = 41 /15' FMC WELLHEADS ACTUATOR = McEVOY BAKER KB. ELEV = 72.59' BF. ELEV = 37.29' KOP = 2150' Max Angle = 36 @ 11612' Datum MD = _10767' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2742' Minimum ID = 2.31" @ 9931' 4-112" X 2-7/8" NIPPLE REDUCER 9-S/8" Whipstock 8450' HES EZSV --~~ 9-5/8" CSG, 47#, L-80, ID = 8.681" I 10232' 3-3116" TBG, 6.2#, L-80, .0076 bpf, ID = 2.786" 41/2" TNVWHIPSTOCK (03/11/02) 10719' RA PIP TAG 10728' 4-1/2" CIBP 10800' PERFORATION SUMMARY REF LOG: MCNL ON 03!20/02 ANGLE AT TOP PERF: 79 ~ 11030' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL OpnlSgz DATE 2' 6 11030 - 11080 C 08/12/04 2" 4 11200 - 11450 C 03/21102 2" 6 11636 - 11676 C 07!22103 PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 41 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9942' 8300' T' Liner Hanger /LTP 2-718" LNR, 6.5#, L-80, .0058 bpf, ID = 2.37T' 11708' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/05183 ORIGINAL COMPLETION 1 ffLH PERF DATE CORRECTION 08/13/89 RIG WORKOV ER 07/14/07 N1GS/PJC PULL PX & SET NIP RED; XX PLUG 03/22102 CTDSIDETRACK (C-28A) 08!04!07 GJBlSV PATCH SET (0729/07) 05/19/06 KSBlfLH GLV GO (05/13/06) 08/21/07 SWGPJC PULL XX PLUG 0621/06 BSE/PJC SET CAT STANDING VALVE 12/14/07 KDGPJC SET XX PLUG @9931' (12/06/07) 09/15/06 JRP/TLH PULL CAT VLVISE~ '='< _'_'..;~„ ---- (~28B O SAFETY NOTES: WELL ANGLE > 70° @ 10970' 8~ >~ 11103'. 2006' 4-112" OTIS SSSVN ID = 3.813 " 2595' 9-5/8" DV COLLAR GA S LIFT MANDRELS DATE 1~ 0060' ~~41/2" x T' Liner Hanger /LTP /~ 10213' T'Csg, 26#, L-80, TGI, ID = 6.276" ~~~~ ' 4t;' 4 1 /2" 12.6# (3.958" ID) 0.0152 bpf 99Q2' BKR PBR SEAL ASSY 9965' 9-5/8" X 4-1 /2" BKR HB PKR, ID = 3.985" 9991' 9-5/8" X 7" BOT SHORTY LNR HGR 10025' 3.70" BKR KB LT PKR w / GS, ID = 2.56" 10378' BKR SEAL LOCATOR, ID = 2.39" 10382' 3-3/4" BKR DEPLOY SLV, ID = 3.000" 10384' BTM BKR SEAL ASSY, ID = 2.39" \ 10391' 3-1 /2" XN NIP, ID = 2.750" 10766' ~-{ MILLABLE 3-3116" X 2-7/8" XO, ID = 2.377" 11676' PRUDHOE BAY UNfT WELL: G28A PERMIT Nu: `L020450 API No: 50-029-20867-01 SEC 19, T11 N, R14E 1865' SNL 8 1033' WEL BP Exploration (Alaska) ~~4 l~~ ~v__~.i j 1/ V~~~ ~O ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ M1T) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the followring BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and boa-ors ~~~6~ v . ~r vZC~ -iob /~aS~PI ProActive Diagnostic Services, Inc. Attn:. Robert A. Richey ~~~ ~U~! .~ ~~' 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1j ~.. 2) Leak Detection -WLD / WAF 07,Jun-08 Z-19A 1 BL / EDE 50-029-22251-01 Signed : Date : - - Print Name: ~~~u o PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-WAIL: ;~:a~a'"'e.~i3~' "'?.{~~P~4"s zi',~uA^~.:.~q^, WEB$ITE:~M.~.°8iit„t"s'.~.:u;..+~"c(?~?,~ ..+;is Leak Detection -WLD 15-Jun-08 G28A 1 BL / E~ 50-029-20867-0 C:\Documen~ and Settings\Oamet\Desktop\Transmit_BP.doc ~ rR~ FCEiVED . Æ~;'\" -- .,¡' . STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COM ION f sftUG 0 3 2007 REPORT OF SUNDRY WELL OPERATIONS \ o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 72.6 KB ~ 8. Property Designation: ADLO-028310 11. Present Well Condition Summary: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic CH Stimulate 0'> . WaiverO Time Exte~~~g;~ Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0450 - Exploratory Service 6. API Number: 50-029-20867-01-00 - 9. Well Name and Number: PBU C-28A . 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool - measured 11708 feet Plugs (measured) None true vertical 9032.38 - feet Junk (measured) None measured 11676 feet 5GANNEi) f.\\)"l\,'~ true vertical 9030.54 feet Total Depth Effective Depth Casing Conductor Production Liner Liner Liner Liner Surface Perforation depth: Length Size 80 20" 91.5# H-40 10195 9-5/8" 47# L-80 777 4-1/2" 12.6# L-80 741 3-3/16" 6.2# L-80 1221 7" 26# L-80 942 2-718" 6.5# L-80 2706 13-3/8" 72# L-80 Measured depth: 11030 - 11676 True Vertical depth: 9029 - 9031 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. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl shut-in shut-in x MD TVD Burst Collapse 39 - 119 39 - 119 1490 470 37 - 10232 37 - 8436.98 6870 4760 9942 10719 8202.31 - 8832.18 8430 7500 10025 - 10766 8270.77 - 8871.56 9991 11212 8242.83 - 9033.72 7240 5410 10766 - 11708 8871.56 - 9032.38 10570 11160 38 - 2744 38 - 2705 4930 2670 - - - - - - - - 4-1/2" 12.6# L-aO 36 - 10719 9-5/8" DV Packer 2595 4-1/2" Baker HB Packer 9965 4-1/2" Baker KB Top Packer 10025 0 0 RBDMS 8FL AVG 15 2007 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after Droposed work: Exploratory Development IV 16. Well Status after proposed work: Oil IV Gas WAG Tubing pressure o o Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ WDSPL Contact Gary Preble Title Data Management Engineer Phone 564-4944 Date 7/30/2007 Al . . .# C-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/28/2007 WELL SHUT-IN AT ARRIVAL. INITIAL WHP 550 PSIA RIG UP FOR 4-1/2" PATCH. ****CONTINUED 29-JUL-2007**** ,vnmmn ,_~. '_VA~~" 7/29/2007!****CONTINUED FROM 28-JUL-2007***** WELL SHUT-IN AT ARRIVAL. T/I/O 400/500/0 13.70" BAKER 13CR 45 "KB" STRADDLE PATCH SET IN 4-1/2" TUBING FROM ,'6650-6678 FT. 'DEPTH CORRECTED TO SLB LDL DATED 9-MAY-2007 'DEVIATION AT PATCH SET 50 DEGREES I PATCH SPECIFICATIONS: MIN ID 2.45" AT PACKERS, 2.972" THROUGH 13CR 3-1/2" STL JOINT OAL = 34.16' ! FINAL T/I/O 400/500/0. J~**JOB COMPLETE*** ."".,^~¡ FLUIDS PUMPED BBLS I 1 DIESEL 1 TOTAL Schlumbergep NO. 4290 zom Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WI CI CD L 0 . i D BL el Job# og escnpt on ate o or L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05107 1 17-22 11745213 LDL 04/29107 1 W-19A 11628772 MEM PROD PROFILE 05107/07 1 Y-24 11630477 LDL 05/08107 1 16-0BA 11686747 LDL 05120/07 1 G-05 11773110 LDL 05113107 1 16-03 11686743 LDL 05111/07 1 14-07 11637334 PRODUCTION PROFILE 05108107 1 V-03 11628770 MEM LDL 04130107 1 MPF-91 11628759 MEM TEMP SURVEY 03109/07 1 MPF-89 11628758 MEM TEMP SURVEY 03108107 1 MPS-10A 11638630 INJECTION PROFILE 05107107 1 B-34 11594500 INJECTION PROFILE 05122107 1 04-10 11594498 LDL 05119/07 1 B-07 11657125 PRODUCTION PROFILE 05/11107 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05119/07 1 C-28A N/A LDL 05/09/07 1 M-07 11630476 LDL 05107/07 1 P1-14 11745214 INJECTION PROFILE 04130/07 1 P1-16 11594494 INJECTION PROFILE 05101/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. SCANNED JUN·.2 1 2007 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ~ Received by: ~ -- Date Delivered: ~ {)Od -Cf.I5 ,'1 ....~-.."..._.-ht....:^"..,.,,'_>J.:.-=....... 1 :1....... p 06/07/07 . . e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc ("AnS. 1. Operations Performed: ¥. ~\ <A U"" AbandonD RepairWeliD PluQ PerforationsD Stimulate D Mas \j e;CJ\~cMtt~e Alter CasingD Pull TubingO Perforate New Pool D WaiverD Time ExtensionO Change Approved ProgramD Operation Shutdown 0 Perforate Œ] Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. 'Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 202.()45(1 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-20867-01-00 7. KB Elevation (ft): 9. Well Name and Number: 72.60 C-28A 8. Property Designation: 10. FieldlPool(s): ADL-002831 0 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11708 feet true vertical 9032.4 feet Plugs (measured) None Effective Depth measured 11676 feet Junk (measured) None true vertical 9030.5 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 39 - 119 39.0 - 119.0 1490 470 Liner 777 4-1/2" 12.6# L-80 9942 - 10719 8202.3 - 8832.2 8430 7500 Liner 1221 7" 26# L-SO 9991 - 11212 8242.8 - 9033.7 7240 5410 Liner 741 3-3/16" 6.2# L-80 10025 - 10766 8270.8 - 8871.6 Liner 942 2-7/8" 6.5# L-80 10766 - 11708 8871.6 - 9032.4 10570 11160 Production 10195 9-5/8" 47# L-SO 37 - 10232 37.0 - 8437.0 6870 4760 Surface 2706 13-3/8" 72# L-SO 38 - 2744 38.0 - 2704.8 4930 2670 Perforation depth: Measured depth: 11030 -11080,11200 -11450,11629 -11636,11636 -11669,11669 -11676 True vertical depth: 9028.64 - 9036.5,9034.08 - 9028.9,9030.38 - 9030.04,9030.04 - 9030.13,9030.13 - 9030.54 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-SO @ 36 - 10719 Packers & SSSV (type & measured depth): 4-1/2" Baker HB Packer @ 9965 4-1/2" Baker KB Liner Top Packer @ 10025 9-5/8" DV Packer @ 2595 12. Stimulation or cement squeeze summary: Intervals treated (measured): OCT 1 ~ , IØ)MS BF L Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: 766 35 39 900 1025 Subsequent to operation: 925 42.9 52 828 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ! OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or NIA if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature 91"" r,.--J-;--= , ,.... , ~ I J\h'fe 564-4657 Date 10/6/04 1\ Form 10-404 Revised 4/2004 UK\\J"~ML- STATE OF ALASKA ~ Rtr,'éNE-e ALAS~ OIL AND GAS CONSERVATION COtv.."IISSION .. \) a l~~~ REPORT OF SUNDRY WELL OPERA TIONSt\ . \'0"",,\,"0\\ ~ ~ ~ C-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/12/04 Perforate 11030'-11080' 6 SPF FLUIDS PUMPED BBLS 155 1 % KCL 21 50/50 Methonal 176 TOTAL Page 1 ,r---. lREE= 4-1/16" FWC WELLHEAD - M::BlOY ACTUATOR = BAKER KB. 8...EV = 72.59' BF. 8...EV = 37.29' KOP= 2150' Max Angle = 96 @ 11612' Qltum MD = 10767' QltumlVD- 8800' SS C-28A . 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2742' Minimum ID = 2.377" @ 10766' 3-3/16" X 2-7/8" XO 14-1/2" TOO, 12.6#, L-80, .0152 bpf. ID = 3.958" H 9942' 19-518" CSG, 47#, L-BO, ID = 8.681" H 10232' 3-3116" TOO, 6.2#, L-BO, .0076 bpf, ID = 2.786" 4-1/2" 1lW WHPSTOCK - 03l11iU2 10719' 1 RA PIP TAG H 10728' 1 4-1/2" CIBP H 10800' PERFORATION SUMv1ARY REF LOG: MO.JL ON 03/20/02 AI\K3LEATTOPFERF: 79 @ 11030' flbte: Refer to Production DB for historical perf data SIZE SPF INTERv' AL OoniSaz Qð. TE 2' 6 11030 -11080 0 0B/12iU4 2' 4 11200-11450 0 03l21,Q2 2' 6 11636-11676 0 03l22iU3 7" LNR, 26#. L-BO. ID = 6.276" 11212' 2006' 9931' 9942' 9965' 9991' 10025' ~ SAFETY NOTES: WELL ANGLE> 70° @ 10970' &>900@11103'. 4-1/2' OTIS SSSVN, ID = 3.813 " 9-5/8" r:N COLLAR 4-112' OTIS X NP, ID =3.813" BKRPBR SEALASSY 9-5/8" X 4-1/2" BKR H3 PKR.ID = 3.985" 9-5/8" X 7" BOT SI-ORrY LNR HGR 3.7CJ' BKR KB LT A<Rw / GS, ID = 2.56" BKR SEAL LOC'A TOR, ID = 2.39" 3-1/2' XN NP, D = 2.750" 4-1/2" & 7' MILLOUT WINDOW 1071'iJ - 10730' (OFF WHPSTOCK ) Qð. TE RBI BY COMv1ENTS DATE REV BY COMMENTS 01/05/83 ORIGINAL COMPl-ErION 07/09104 BY/KAK MN IDCORRECllON 08113/89 RIG WORKOVER 08/12/04 JGMfTLP ADD PERFS 03122102 CTD SlDErRACK (C-28A) 04l01iU2 CHITP CORRB:;llONS 07/05,Q3 CMOITLP MAX ANGLE CORRB:;TION 07/22,Q3 JAFITLH ADD FERF MLLABLE 3-3/16" X 2-7/8" XO, ID= 2.377" PRUDI-OE BAY ll'J1T WELL:C-28A PERMT fib: 2020450 API fib: 50-029-20867-01 SEC19, T11N, R14E 1865' SN... & 1033'W8... BP Exploration (Alaska) Permit to Drill 2020450 MD 11708,,---- -------- ----- --.----------~-- ~ I J@. fJ ~ 6 ~ ....t DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 5fJ~ / 7 t1~)~ ÄL API No. 50-029-20867-01-00 Well Name/No. PRUDHOE BAY UNIT C-28A Operator BP EXPLORATION (ALASKA) INC TVD 9032 ,---- Completion Date 3/22/2002""-- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Samples No ~--- Mud Log No Directional Survey Yes ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset ,Type - Med/Frmt Number Name ~ D v11487 LIS Verification Rpt U IkD C i ! Log Log VED C Asc c....-- I ED C Pdt I JED C Pdt - - ---------~ Log Log Run Scale Media No 1 Interval OH / Start Stop CH 10394 11660 Case 10394 11660 Case ~ Received Comments 1/21/2003 1/21/2003 LlSVerificatión Casin9conarlóqåtp~ 25 as 1 0230 11659 Case 4/19/2002 10250 11658 Case 4/19/2002 L-f0920 Gamma Ray Neutron (~1752 LIS Verification 25 as 25 BS 10230 11659 Case 4/19/2002 1 0230 11659 Case 4/19/2002 1 0394 1 0988 10740 11710 Open 10740 11710 Open <:-11752 Induction/Resistivity Gt1752 Rate of Penetration 25 25 ROP I DGR, EWR ROP, DGR, EWR Well CoreslSamples Information: Name Interval Start Stop Sample Set Number Comments ~ Sent Received Well Cored? ADDITIONAL INFORMATION y/@) Chips Received? ~ Daily History Received? cYYN ~/N Analysis Received? Formation Tops ----------- --.-- --------- ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020450 Well Name/No. PRUDHOE BAY UNIT C-28A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20867-01-00 MD 11708 TVD 9032 Completion Date 3/22/2002 Completion Status 1-01L Current Status 1-01L UIC N ------- -- - Compliance Reviewed By: ~D Date: J Æ IJ¡/JM '--I ------- --- - ----- -- ~~' J' STATE OF ALASKA"~ ALASKA IL AND GAS CONSERVATION corvhv./SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator SuspendD RepairWellD Pull Tubing D Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0450 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 72.60 8. Property Designation: ADL-0028310 11. Present Well Condition Summary: Total Depth Development I]] Stratigraphic D 9. Well Name and Number: C-28A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-20867-01-00 measured 11708 feet None Effective Depth true vertical 9032.4 feet None measured 11676 feet true vertical 9030.5 feet Casing Conductor Liner Liner Liner Liner Production Surface Length .80 777 1221 741 942 10195 2706 Perforation deDth: Plugs (measured) Junk (measured) Size 20" 91.5# H-40 4-112" 12.6# L-80 7" 26# L-80 3-3/16" 6.2# L-80 2-7/8" 6.5# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 39 119 39.0 - 119.0 1490 470 9942 - 10719 8202.3 - 8832.2 8430 7500 9991 - 11212 8242.8 - 9033.7 7240 5410 10025 - 10766 8270.8 - 8871.6 10766 - 11708 8871.6 - 9032.4 10570 11160 37 - 10232 37.0 - 8437.0 6870 4760 38 - 2744 38.0 - 2704.8 4930 2670 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 36 - 10719 RECE\VED JAN 15 2004 0'\ & Gas Cons. Comm\ss\on A\aska , 2595' Anchorage 9965 10025 Measured depth: 11200 - 11450, 11629 - 11636, 11636 - 11669, 11669 - 11676 True vertical depth: 9034.08 - 9028.9, 9030.38 - 9030.04, 9030.04 - 9030.13, 9030.13 - 9030.54 Packers & SSSV (type & measured depth): 9-5/8" DV Packer 4-1/2" Baker HB Packer 4-1/2" Baker KB Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: -&:I. ReDresentative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 30.2 58 700 Daily Report of Well Operations . ~ 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 - "'~~. C~ Form 1 0-404 Revi~ed 12/2003 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- @ @ @ 8158 Oil-Bbl 645 Tubing Pressure 1208 1111 1249 31.4 42 580 15. Well Class after proposed work: Exploratory D DevelopmentŒ) ServiceD 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant OR\G\NAeone 564-4657 Date 1/8/04 ') ) C-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/14/03 Drift w/211 Cent, sample bailer, no sample to 10700' 07/21/03 DT Mem GR/CCL Add Perf; MIRU DS CTU #9. Perform weekly BOP test. Load well with 100 bbls filtered KCL to reduce SIWHP. RIH with 2.0in JSN w/2 1/8in gage. TAG at 116961 ctm. Unable to wash down any deeper. POOH. RIH with PDS MEM GR/CCL. 07/22/03 RIH wI memory logging tools. Log up from TD to 10900' ctm. Flag pipe at 116001. POOH Good data make (-201) correction. TD @ 11677'. RIH wI Gun #1 (301 of 2in HSD PJ 2006 gun @ 6 spf 60 deg phasing). Correct depth at flag to bottom shot (11607'). RIH and tag TD at 116751 down, PU @ 11670, placing bottom shot at 116691. Perforate 116391 to 11669' (flag). POOH. All shots fired. MU and RIH wlGun #2 (101 of 211 HSD PJ 2006 gun @ 6 spf, 60 deg phasing). Correct depth based on Gun #1 flag flag TD tag (11,6701). PUH and shoot 116291 to 116391. POOH. All shots fired. RD DS CTU #9. Notify PCC and Pad Operator. Well is flowing. FLUIDS PUMPED BBLS 233 233 1 % KCL TOTAL Page 1 ) 4-1/16" FI\C rvc EV OY BAKER ....f2.59ï' ..".3'i:.2!f .."21!5(i .~ff@ff16 f 2: - ..- .10767' ..ääööi sS' lREE = WELLHEAD = ACTUð. TOR = '.Kë: äï3T;; . . . 13F:..ä.EV...; m.. 'kÒÞ~. ....m fvtÙcmÄrigie ;;;. m 'ï)atüni M:f~ . ï:~tum "iVt> .;;;;. .. I 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2742' ---.J Minimum ID = 2.39" @ 10378' BKRSEALASSYLOCATOR 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9942' C-28A ) SAÆTY NOTES: WELL ANGLE> 70° @ 10970' & > 90° @ 11103'. 2006' H 4-1/2" OTIS SSSVN, ID = 3.813" 1 =-i 2595' H 9-5/8" rN COLLAR 1 ~ e - - L GA S LIFT I'v1A NDRELS ST MD TVD IDEV TYPE I VLV LATCH I FORTI DATE I 1 3255 3044 42 OTIS 8/0 RA 20 03/25/02 I I l :8: i I 9942' I 9965' I 9991' I 10025' J ~ J .. 19-518" CSG, 47#, L-BO, ID = 8.681" H 10232' -----41 13-3116" TBG, 6.2#, L-80, .0076 bpf, ID = 2.786" 1 I 4-1/2" llW WHPSTOO< - 03111102 1-1 I RA PIPTAG 1-1 I 4-1/2" CIBP 1-1 10719' I 10728' 10800' PERFORATION SUM\t1ARY REF LOG: MCN... ON 03/20102 ANGLE A TTOP ÆRF: 92 @ 11200' r-.bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE Z' 4 11200-11450 0 03/21/02 2" 6 11636 - 11676 0 03/22/03 I A31D H 11154' 1 7" LNR, 26#, L-BO, ID = 6.276" H 11212' DA.TE 01/05/83 08/13/89 03122/02 04101/02 07/05/03 07/22/03 COM\t1ENTS ORIGINAL COM PLETION RIG WORKOVER CTD SIDETRACK (C-28A) CHnP CORREC~ONS CMOIlLP MAX ANGLE CORRECTION JAFIlLH AOO ÆRF 9931' 1-1 4-1/2" OTIS X NIP, ID =3.813" 1 H BKR PBR SEAL ASSY 1 H 9-5/8" X 4-1/2" BKR I-B PKR, ID = 3.985" 1 H 9-5/8" X 7" BOT SHORTY LNR HGR 1 H 3.70" BKR KB LT R<Rw IGS, ID = 2.56" 1 t 10378' H 1 10382' H i 10384' H I 10391' l-i BKRSEAL LOCATOR, ID =2.39".1 3-3/4" BKR DER...OYWENT SLV, D = 3.000" 1 BTMBKR SEAL ASSY, ID= 2.39" 1 3-1/2" XN NIP, D =2.750" 1 4-1/2" & 7" MILLOur WINOOW 10719' - 10730' (OFFWHlPSTOO<) 10766' H MLLABLE 3-3/16" X 2-7/8" XO, ID = 2.377" 1 .' 111676' HPBTD 1 I 2-7/f5' LNR, 6.5#, L-80, .0058 bpf, ID = 2.377' H 11708' 1 REV BY DATE REV BY COMWENTS PRLDHOEBAY l1'J1T WELL: C-2BA PERMT I'b: 2020450 APII'b: 50-029-20867-01 SEC 19, T11N, R14E 1865' SN... & 1033' WB.. BP Exploration (Alas ka) ) ) ¿)G) ~ .. 0 Lt..C-:~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 08, 2003 RE: MWD Fonnation Evaluation Logs: C-28A, AK-MW-22051 C-28A: Digital Log Images 50-029-20867-01 1 CD Rom \ ) 1 ?~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-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: to c it). C~3 (), .0 Signed:~Je-- ~ RECEIVED MAY 13 2003 AJaef(a Oü &. Gas Cons. Comm_n Anchorage ) ) aOd- 015 ( IL/~l WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tlJ. Avenue, Suite 100 Anchorage, Alaska January 21, 2003 RE: MWD Fonnation Evaluation Logs C-28A, AK-MW-22051 1 LDWG fonnatted Disc with verification listing. API#: 50-029..20867-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-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: Si~~Q¡¿q(U RECEIVED JAN 2 1 2003 Aluka Oit & Gas Cons. ConInI8ion Andmge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 18651 SNL, 10331 WEL, SEC. 19, T11 N, R14E, UM At top of productive interval 1809' SNL, 2120' WEL, SEC. 30, T11 N, R14E, UM At total depth 1667' SNL, 13981 WEL, SEC. 30, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72.601 ADL 028310 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/17/2002 3/19/2002 3/22/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11708 9032 FT 11676 9031 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, CCL, CNL Classification of Service Well 7. Permit Number 202-045 8. API Number 50- 029-20867-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number C-28A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 20061 MD 1900' (Approx.) 7" 3.1/2" X 3.3116' 2.7/8' WT. PER FT. Insulated 72# 47# 26# 9.3# 1 6.2# 6.16# GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 1101 36" 9 cu yds Concrete Surface 27441 17-1/2" 3993 cu ft Permafrost II Surface 10232' 12-1/4" 1413 cu ft Class IGI, 130 cu ft PF IC' 99911 10719' 8-1/2" 441 cu ft Class 'G' 100251 117081 3-3/4" 61 cu ft Class 'GI AMOUNT PULLED 23. CASING SIZE 20" X 30" 13-3/8" 9-5/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 11200' - 11450' 9034' - 9029' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 10719' PACKER SET (MD) 9965' 25. MD TVD 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production March 27, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL -BSl TEST PERIOD GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BsL GAs-McF WATER-Bsl OIL GRAVITY-API (CORR) 28. CORE DATA "'~',..:" (' i - -~ "~ t ,-~. ~:l~ Brief description of lithology I porosity I fractures, apparent dips and presence of oil, gas or water. Submit cor'èchips.- ... - . - . No core samples were taken. :-- -'..... .J", .-. .~ "''':.''. . .~J ~~. .,. ..:... . ¡,Þ .:. , 'io....'~. ¡ G ,1 ¡\ " RBDMS 8FL MAY j SOBtnit In Duplicate Form 10-407 Rev. 07-01-80 ) ) 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 28 10795' 8896' 22TS 10859' 8950' Zone 2A 109291 8996' 31. list of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Te"ieHubble ~AJ\i,( ~ nle Technical Assistant C-28A 202-045 Well Number Permit No. I Approval No. Date rJ-/. as .,0 ~. 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 otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no Cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 I. Ii ,I .1;; , ) ') BP EXPLORATION Operatio.ns SUl11rrja:ry.RepQrt Page.1 of8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 3/14/2002 00:00 - 14:00 14.00 MOB P PRE Move from DS18-10 to C pad in the WOA. 14:00 - 16:00 2.00 MOB N WAIT PRE Arrive on C pad. P&A of C-28 still in progress by service coil unit. Standby while Service coil rigs down, and cleanout rigup is drained and moved. Rig on standby at 14:00. 16:00 - 17:00 1.00 MOB N WAIT PRE Hold SIMOPS meeting for rig activity with induction heating of flowline in simultanious operations. Conclusion of meeting is that a variance will be issued and simultanious operations will commence. 17:00 - 21 :00 4.00 MOB N WAIT PRE Continue waiting on rig down of cleanout rig up. 21 :00 - 21 :30 0.50 MOB N WAIT PRE Safety meeting prior to pad operator commencing test of impediance heating on frozen flowline. 21 :30 - 00:00 2.50 MOB N WAIT PRE Veco DSM, Rig Crew, Tool Service all put on hold while test of impedence heating is performed. Continue to wait. 3/15/2002 00:00 - 04:00 4.00 MOB N WAIT PRE Continue standing by waiting on pad prep. 04:00 - 04:30 0.50 MOB P PRE Safety meeting prior to moving onto well C-28. 04:30 - 05:30 1.00 MOB N WAIT PRE Continue to wait while pad prep is completed. 05:30 - 07:00 1.50 MOB N WAIT PRE Make pre rig inspection of pad. Found flowline still pressurized to 500 psi, lateral valve open and frozen. Call for grease crew to service lateral valve and depressure S-riser. 07:00 - 07:15 0.25 MOB P PRE SAFETY MEETING. Review rig back over well procedure and hazards. 07: 15 - 08:00 0.75 MOB P PRE Back rig over well and set down. 08:00 - 09:00 1.00 RIGU P PRE ACCEPT RIG AT 08:00 HRS, 03-15-02. Spot trailers, cuttings tank. General rig-up. 09:00 - 10:00 1.00 BOPSUR P DECaMP Nipple up BOP equipment. 10:00 - 16:00 6.00 BOPSURP DECaMP Perform inital BOP pressure I function test. Witness waived by AOGCC. Sent Test report to AOGCC. 16:00 -16:15 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure and hazards for milling BHA M/U. 16:15 - 17:00 0.75 STWHIP P WEXIT Fill coil with KCL water. Press test CT 17:00 - 19:00 2.00 STWHIP N RREP WEXIT Repair inlet micro-motion rate indicator and mud pump #1 packing oiler. 19:00 - 19:15 0.25 STWHIP P WEXIT Safety meeting prior to picking up window milling BHA. 19:15 - 20:00 0.75 STWHIP P WEXIT M/U 3.80" Dia Speed Mill, string reamer, Wthrfd Motor, PH6, circ sub, hyd discon, checks and CTC. Pull test and PT Baker CTC. 20:00 - 22:00 2.00 STWHIP P WEXIT RIH 22:00 - 22:20 0.33 STWHIP P WEXIT Stop at 10500', adjust "In Rate" micro motion meter. Kick pumps on. In MM doesn't work. Weight check up =43klbs at 1 0500'. RIH, tag top of cement at 10701.5'. Will use last service coil tag of 10653'. Make -48.5' correction. Pit Volume 262 bbls. 22:20 - 22:30 0.17 STWHIP P WEXIT 10653', Begin milling operations. 2.5/2.5/1280 psi free spin. Milling at 1900 psi, 1600 psi weight on bit. Pit volume 252 bbls. 22:30 - 22:55 0.42 STWHIP N RREP WEXIT 10655.4', Lost 20 bbls in last 15 minutes based on pit volume meter. Loosing fluid off of screens to cuttings box. Change out screens. 22:55 - 23:55 1.00 STWHIP P WEXIT Return to milling. 2.4/2.4/1700 psi. Making good Rap in cement of about 30 fph. Pit volume holding steady at 237 bbls. 23:55 - 00:00 0.08 STWHIP P WEXIT 10678.5', Pump 10 bbl of 2# biozan sweep. Continue milling cement. Depth at midnight is 10681'. 3/16/2002 00:00 - 00:30 0.50 STWHIP P WEXIT 10681', Continuing to mill cement in 4.5" tubing. Pit vol = 239 Printed: 3/25/2002 8:10:25 AM ) ) BP EXPLORATION Operati,ons Summary Report Page 2 ot8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From- To Hours . Activity ,Code NPT Phase Description' otOperations 3/16/2002 00:00 - 00:30 0.50 STWHIP P WEXIT bbls. 00:30 - 00:50 0.33 STWHIP P WEXIT 10694.6', Stall, weight check. Clean PU at 42klbs. Resume milling. 00:50 - 00:55 0.08 STWHIP P WEXIT 10700', Stall, weight check. Clean PU at 42klbs. Resume milling. 00:55 - 01 :30 0.58 STWHIP P WEXIT 10701.9', Pump 10 bbl sweep. Continue milling. 2.5/2.5/1650 psi. 01 :30 - 02:20 0.83 STWHIP P WEXIT 10713.5' Stall, PU clean. Tag Stall. Probably pinch point on whipstock. Tag a couple more times. Can't make any Rap. Assume whipstock. Make +5.5' correction to 10719'. Begin window milling. 02:20 - 03:00 0.67 STWHIP P WEXIT 10721', pump 10 bbls of 2# biozan sweep. Continue milling, holding 2000 Ibs WOB. 03:00 - 03:45 0.75 STWHIP P WEXIT 10721.8', pump 10 bbl sweep. 03:45 - 04: 15 0.50 STWHIP P WEXIT 10722.9', pump 10 bbl bio sweep. 04:15 - 05:00 0.75 STWHIP P WEXIT 10723.4', pump 10 bbl bio sweep. 05:00 - 06:00 1.00 STWHIP P WEXIT 10723.8', Weight check. Clean pickup at 42klbs. Free spin 1400 psi. Getting ahead of ourselves and stacking weight. PU, Tag at 10721.7', start time drilling at 6 minutes/0.1'. 06:00 - 07:45 1.75 STWHIP P WEXIT 10722.4', Time milling. Getting good drilloffs based on WOB. 07:45 - 09:45 2.00 STWHIP P WEXIT 10724.1'. Time milling, 09:45 - 10:30 0.75 STWHIP P WEXIT 10724.6. Milling based on pressure and WOB. 2400 psi, 6000 WOB 10:30 - 11 :30 1.00 STWHIP P WEXIT 10725.3'. Milling. 2420 psi, 7900 WOB. 11 :30 - 13:00 1.50 STWHIP P WEXIT 10725.6'. Milling, Stacking wt. back ream window, milling, 2500 psi, 7800 WOB 13:00 - 15:00 2.00 STWHIP P WEXIT 10725.9'. Milling, Back ream window. Up Wt = 45K, free spin 1550 psi. 15:00 - 17:00 2.00 STWHIP P WEXIT 10726.5'. Milling, Ream window. Stacking WT. 2400 psi, 7000 WOB. Swap to FloPro for better wt transfer. Up WT = 42K, Dwn Wt. 15K dwn wt. Free Spin = 2400 psi. 17:00 - 17:30 0.50 STWHIP P WEXIT No more progress, slow pump to 2.3 bpm, no progress. Pull thru window. Stop pump, RIH. Tag btm at 10725 ft. Pick up, RIH with 1.0 bpm, Tag btm at 10724 ft. 17:30 - 17:50 0.33 STWHIP P WEXIT 10726.7". Milling, 2.6 bpm, 3380 psi. 9500 WOB, free spin = 2400 psi. No Progress. Present TD is 10,725 ft. 6 ft of window milled. Clean window area. No Progress. 17:50 - 19:30 1.67 STWHIP P WEXIT POOH to check mill and motor. 40K up wt. 19:30 - 21 :30 2.00 STWHIP P WEXIT Tag up at surface. Break off motor and mills. Motor appears tight with wrench. Mills in perfect shape. Little face wear on whipstock mill. Both mills gauge at 3.80". No wear on cutright on string reamer. 2 Chipped cutters on string reamer though. PT old MHA and CTC, ok. PT new MHA, ok. PT 2 jts of PH6, ok. MU new mills, new motor, same 2 joints of PH6, new MHA, same CTC. 21 :30 - 23:30 2.00 STWHIP P WEXIT RIH with BHA #2. Tag up at and set depth to last tag of 10724.6'. 23:30 - 00:00 0.50 STWHIP P WEXIT Kick pumps on to 2.5 bpm. Free spin; 2450 psi at 2.5 bpm. Start milling again. 2.5/2.5/2650 psi. 350 Ibs motor work, good Printed: 3/25/2002 8:10:25 AM ) ) Page 3 of8 BPEXPLORA TION Operations Summary RepQrt Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From';Tó Hours Activity Code NPT Phase 3/16/2002 3/17/2002 23:30 - 00:00 0.50 STWHIP P 00:00 - 01 :00 1.00 STWHIP P 01 :00 - 02:00 1.00 STWHIP P 02:00 - 02:20 0.33 STWHIP P 02:20 - 05:30 3.17 STWHIP P 05:30 - 06:20 0.83 STWHIP P 06:20 - 07:00 0.67 STWHIP P 07:00 - 08:30 1.50 STWHIP P 08:30 - 09:30 1.00 STWHIP P 09:30 - 11 :00 1.50 STWHIP P 11 :00 - 12:00 1.00 STWHIP P 12:00 - 12:15 0.25 DRILL P 12:15 - 13:00 0.75 DRILL P 13:00 - 14:50 1.83 DRILL P 14:50 - 15:20 0.50 DRILL P 15:20 - 16:00 0.67 DRILL P 16:00 - 16:45 0.75 DRILL P 16:45 -17:15 0.50 DRILL P 17:15 - 18:40 1.42 DRILL P 18:40 - 18:50 0.17 DRILL P 18:50 - 18:55 0.08 DRILL P 18:55 - 19:20 0.42 DRILL P 19:20 - 20:25 1.08 DRILL P 20:25 - 20:30 0.08 DRILL P 20:30 - 21 :15 0.75 DRILL P 21 :15 - 22:05 0.83 DRILL P 22:05 - 22:15 0.17 DRILL P 22:15 - 00:00 1.75 DRILL P 3/18/2002 00:00 - 01 :00 1.00 DRILL P 01 :00 - 02:30 1.50 DRILL N WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Description of Operations drill offs. 1500 Ibs weight on bit. Continue window milling from 10725.5'. 2.5/2.5/2700 psi. 10726.6', getting good drill offs, milling at 3500 psi WOB, 2760 psi, 310 Ibs of motor work. No fluid losses. Drilling with mud, not pumping sweeps. Getting metal back on ditch magnets. 10727.1', Continue milling. 10727.3', PU for weight check. Smooth up at 38klbs. RIH, resume milling. 10728.3', Drilling break. Continue milling. 10729.8', Stall, PU clean at 41klbs. Resume milling. Bottom of window at 10730 ft. 11 ft long window. 10732'. Drilled to 10,739 ft. with 3.80" mill. Back ream window. Clean. Ream dwn. Back ream. Stop pump went thru window clean. Back ream up thru window, clean. PBTD = 10,739 ft. POOH. LlO Milling BHA. M/U new CTC. Pull I press test CTC. Replaced CT measuring wheel on injecter. SAFETY MEETING. Pre-Spud meeting with crew. Review well plan and hazards. Review BHA MIU Procedure and hazards. M/U MWD BHA #3. 2.83 deg motor, Rebuild STC M-09 Bit #3. RIH with MWD BHA #3. Shallow Test Sperry tools, OK. RIH. Correct CT depth to CT Flag [-17 ft]. Orient TF to 150L. Set down at 10729 ft. Twice. Don't know for sure bit is out window. Pull up hole to tie-in with BHCS/GR at 10400 ft. Log Tie-in with GR. Added 11 ft to CTD [net correction from surface, -6 ft]. RIH and tag TD 10,739'. Drilling, TF = 95L, Slow hard drilling. 2.7/2.7 bpm, 3300 psi, ROP = 40 FPH. 10781', Lost returns. 2.5/0.7/2950 psi. Pick up to shoe. Returns coming back slowly. 1.4 bpm at best. Resume drilling. Returns healing up. 2.6/2.1/3100. ROP 45 fph. TF=75L. 10784.7'. Orient around. Need to get tool face down more, and can't push to achieve this. Resume drilling. 2.5/2.2/3070 psi, TF132L, 85 fph. 10811'. Take a click. Resume drilling. 10840',2.7/2.6/3400 psi, TF=64L, ROP=45 fph, 30% chert in cuttings. 10882', wiper trip to shoe. Clean pickup, Resume drilling. 10961', Continue drilling build section. 2.5/2.5/3220 psi. TF 4R, ROP=60 fph. 10987', orient around. Only getting about every 10th click. Tried everywhere in open hole, and up in casing. After attempting to get clicks for 1.5 hours there was an additional problem in the BHA. CTP was up to 4100 psi, and rate down to 2.0 bpm. Probably some plugging of the bit or BHA. Printed: 3/25/2002 8: 1 0:25 AM ) .) BP EXPLORATION Ope~ations Summary Report Page 40fB Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-2B C-2BA REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From- To Hours Activity Code NPT Phase Description of Operations- 3/18/2002 02:30 - 04:20 1.83 DRILL P PROD1 Trip for plugged BHA. Have not finished build and turn, however DD can make it to TD with 1.7 deg motor. Ahead of well plan with turn and build. 04:20 - 04:45 0.42 DRILL P PROD1 Safety meeting prior to troubleshooting BHA. 04:45 - 07:40 2.92 DRILL P PROD1 Lay down BHA #3, troubleshoot same. Found Sperry Orienter had flooded [seal failed] causing piston to drop, lIocking orienter. Pick up lateral section BHA with resistivity. Test Resistivity tool. 07:40 - 09:45 2.08 DRILL P PROD1 RIH with MWD Res BHA #4 with 1.7 deg motor and DS49 bit #4. Shallow test. RIH 09:45 - 11 :00 1.25 DRILL P PROD1 Tag TD at 10990. Correct to 10987 ft. Log up with MWD Res. at 150 FPH. Tied-in with RA tag [-3 ft CTD]. 11 :00 - 11 :30 0.50 DRILL P PROD1 RIH to TD. Clean hole. Tag TD at 10989 ft. 11 :30 - 12:30 1.00 DRILL N DFAL PROD1 Orient TF. Unable to orient in open hole. Pulled into 4-1/2" tbg. Unable to orient. RIH to TD. drilled 4 ft. Stack wt. Still not able to orient. 12:30 - 14:15 1.75 DRILL N DFAL PROD1 POOH to change out orienter. 14:15 -15:00 0.75 DRILL N DFAL PROD1 Change out orienter and bit. Bit #4 had 2 chipped center PDC and chipped gauge. 15:00 - 16:45 1.75 DRILL N DFAL PROD1 RIH with MWD Res BHA #5 with 1.7 deg motor and DS49 bit #5. Shallow test orienter. RIH 16:45 - 18:10 1.42 DRI LL N DFAL PROD1 Ran slow thru window. No wt loss. RIH to TD. Unable to orient in open hole again, possibly due to high dogleg [37 deg] and long BHA due to RES tool. This combo probably requires more torque than the Sperry Orienter can give. Pull up into 4-1/2" tbg and orient. RIH with good TF. Tag TD at 11008', correct to 10996' [-12 ft CTD]. 18:10 - 18:35 0.42 DRILL P PROD1 Drilling build section. TF = 45L, 2.6/2.5 bpm, 18:35 - 21 :05 2.50 DRILL P PROD1 11014' PU to just below shoe to orient. Gave it 14 clicks at 10743', got 1 or 2. RIH to just above TD in the 20' of hole drilled with the lower bend motor. Attempt to get 1 click at 11008' (TD=11 013'), did not get it. Try a couple of clicks. Unable to get any clicks at TD. PUH to above the window. Try a couple of clicks, and got them. Orient to 90L. RIH, TF wraps around 200 deg. Pull back up above window, orient 200 deg out, try to RIH to TD. Trap pressure thru window to hold tool face. On bottom need 3 more clicks. Pull back up above window. Leave pumps on. Get 3 clicks. RIH to TD pumps on. 21:05 - 21:15 0.17 DRILL P PROD1 11014', Finally have a tool face we can live with. TF=95R. Resume drilling. Free spin 3130 psi. 2.5/2.5/3350 Pit vol=302 bbls. 21:15-21:40 0.42 DRILL P PROD1 11024', Need 2 clicks. Try on bottom. No success. Pull all the way back up inside casing. to get 2 clicks. 21:40 - 22:05 0.42 DRILL P PROD1 Resume drilling. TF 74L. 22:05 - 22: 1 0 0.08 DRILL P PROD1 11074' need to orient straight up. Attempt on bottom. BHAis all in 20 deg dogleg hole. 22:10 - 22:30 0.33 DRILL P PROD1 Resume drilling. 22:30 - 23:10 0.67 DRILL P PROD1 11116', Well landed horizontally at 8964.8' TVD. Where geos requested. Orient around to 90L to drill lateral section. 23:10 - 23:50 0.67 DRILL P PROD1 Resume drilling later section. Cuttings showing some signs of Printed: 3/25/2002 8: 1 0:25 AM ) ) BPEXPLORATION Operations Summary Report Page 5 of8. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From- To Hours Activity Code NPT Phase Descri ption of Operations 3/18/2002 23:10 - 23:50 0.67 DRILL P PROD1 HOT. Reduce TVD to 8960' as per geos. 2.6/2.6/3400 psi. Pit vol 299 bbls. 23:50 - 00:00 0.17 DRILL P PROD1 11172', orient around to 90L. 3/19/2002 00:00 - 00: 1 0 0.17 DRILL P PROD1 11172', Continue orienting. 00: 1 0 - 00:35 0.42 DRILL P PROD1 Resume drilling. 2.6/2.6/3440 psi, TF=100L. Pit vol=294 bbls. 00:35 - 01 :00 0.42 DRILL P PROD1 11202', wiper trip to shoe. Clean pickup off bottom. 40klbs. 01 :00 - 01 :35 0.58 DRILL P PROD1 Resume drilling. 3315 free spin. 2.6/2.6/3590. 01 :35 - 01 :40 0.08 DRILL P PROD1 11252', take a click. 01 :40 - 01 :45 0.08 DRILL P PROD1 Resume drilling, 2.7/2.7/3950 01 :45 - 01 :55 0.17 DRILL P PROD1 11275', Orient to 90R. 01 :55 - 02:50 0.92 DRILL P PROD1 Resume drilling, 2.7/2.7/3720 psi. 02:50 - 03:25 0.58 DRILL P PROD1 11357', wiper trip to shoe. Clean PU off bottom at 41 klbs. 03:25 - 03:35 0.17 DRILL P PROD1 Resume drilling, 2.7/2.7/3950 TF 116R, pit volume 283 bbls. 03:35 - 03:50 0.25 DRILL P PROD1 11380', orient around. 03:50 - 04:00 0.17 DRILL P PROD1 Resume drilling, 2.7/2.7/3720, TF104R, Pit vol=280 bls. 04:00 - 04:20 0.33 DRILL P PROD1 Orient around to 80L. 04:20 - 04:35 0.25 DRILL P PROD1 Resume drilling, 2.7/2.7/3950 psi. TF83L, Pit Vol=280 bbls. 04:35 - 05:00 0.42 DRILL P PROD1 11452', Orient around. 05:00 - 05:25 0.42 DRILL P PROD1 Resume drilling, 2.7/2.7/4070 psi. TF=130L, Pit Vol=276 bbls. 05:25 ~ 06:05 0.67 DRILL P PROD1 11503', Wiper trip to shoe. Slightly draggy PU off bottom @ 45 klbs. Cleaned up quickly to 39 klbs. Clean back to bottom. 06:05 - 06: 15 0.17 DRILL P PROD1 Orient to high side. 06:15 - 06:25 0.17 DRILL P PROD1 Resume drilling. 2.5/2.5/3380, 16L TF, Pit volume 272 bbls. 06:25 - 06:45 0.33 DRILL P PROD1 11525', orient around to 90L. 06:45 - 07:30 0.75 DRILL P PROD1 Drilling, TF = 90L, 2.5/2.5 bpm, 3400 psi, Drilled to 11575' 07:30 - 08:00 0.50 DRILL P PROD1 Orient TF to 45R. 08:00 - 08:30 0.50 DRILL P PROD1 Drilling, TF = 45R, 2.6/2.6 bpm, 3420 psi, Drilled to 11,614 ft. Sticky high perm. formation. 20K Overpull. 08:30 - 09:40 1.17 DRILL P PROD1 Wiper trip to window. Clean hole except for 11575 ft. [20K overpull]. 09:40 - 10:00 0.33 DRILL P PROD1 Drilling, TF = 80 R, 2.5 I 2.5 bpm, 3300 psi, Drilled to 11,634 ft. 10:00 -10:15 0.25 DRILL P PROD1 Orient TF to 160R. 1 0: 15 - 11: 15 1.00 DRILL P PROD1 Drilling, TF = 160R, 2.5/2.5 BPM, 3350 PSI, Drilled to 11 ,692 ft CTD 11:15 -12:45 1.50 DRILL P PROD1 Log MAD pass with GR I RES while making wiper trip to window. Log MAD pass up to 10,905 ft at 600 FPH. Pull near to window. Logged GR tie-in with RA tag at 10,728 ft. [added 17 ft]. 12:45 - 13:20 0.58 DRILL P PROD1 RIH to TD. Clean hole back to TD. DWN WT = 14K, Up WT= 42K off bottom. Tagged final corrected TD at 11,708 ft BKB. 13:20 - 15:45 2.42 DRILL P PROD1 POOH to run Liner. Clean trip out in open hole. 15:45 - 16:45 1.00 DRILL N SFAL PROD1 At Surface. Attempt to download Sperry Res/GR memory. Observe communications cable broken & changed out same. 16:45 - 17:45 1.00 DRILL P PROD1 Download memory resistivity data. 17:45 -18:15 0.50 DRILL P PROD1 PJSM. UD drilling BHA #5. 18:15 -18:40 0.42 CASE P COMP Crew change & RIU to run liner. 18:40 - 19:40 1.00 CASE P COMP Safety mtg re: liner Safety Standdown re: "Our Commitment. . . " 19:40 - 21 :30 1.83 CASE P COMP MU 29 jts 2-7/8" 6.16# L-80 STL and 12 jts 3-3/16" 6.2# L-80 TC11 liners with float equipment, pup, 'XN' nipple and XO's 21 :30 - 22:40 1.17 CASE P COMP Install Baker CTLRT. Install Baker CTC. PT 35k, 3500 psi Printed: 3/25/2002 8: 1 0:25 AM ) ) BP EXPLORATION Opera~lonsSummary Report page'6ot 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From- To Hours Activity Code NPT Phase Description ot Operations 3/19/2002 22:40 - 00:00 1.33 CASE P COMP RIH wI CT to 9500' 3/20/2002 00:00 - 00:40 0.67 CASE P COMP RIH wI liner on CT. 38k @ 10650'. RIH to TD at 11724' CTD. Recip 25' and pulling heavy. Park at TO and correct depth to 11708' 00:40 - 01 :35 0.92 CASE P COMP Load 5/8" steel ball and circ to seat. Sheared at 2900 psi. PUH 41 k and released. Stack 8k 01 :35 - 03:00 1.42 CEMT P COMP Displace to 2% KCI. Full returns thruout. Send used mud to MI Safety mtg re: cementing Mix cement. Cement to wt @ 0235 hrs 03:00 - 03:20 0.33 CEMT P COMP PT DS cementers @ 3500 psi. Load CT w/11.0 bbls 15.8 ppg 'G' cement wI latex 03:20 - 04:00 0.67 CEMT P COMP Load wiper dart, launch and check. Displace wI 2% KCI. Dart latched wiper plug on the money at 58.8 bbls. Incr rate to 3.0/1440 and displace to latch collar at 66.9 bbls. 10.8 bbls cement pumped around shoe. Floats held. Unsting w/1 000 psi 36k. CIP 0400 hrs 04:00 - 06:00 2.00 CEMT P COMP Jet TOL. POOH jetting to surface. Dump 12 bbls of cement contaminated (10.4 ppg) fluid 06:00 - 07:00 1.00 CEMT P COMP LD CTLRT. SIB injector. 07:00 - 07:45 0.75 EVAL P COMP PJSM & RIU for P/U 1 1/4" CHS tbg & CNL tools. 07:45 - 09:45 2.00 EVAL P COMP P/U BHA #7 (1402.86') with GRlCCLlMCNL in flow-thru carrier & 44 jts of 1-1/4" CSH tbg. P/U injector. 09:45 - 11 :25 1.67 EVAL P COMP RIH BHA #7 with CT. 11 :25 -12:15 0.83 EVAL P COMP Log down from 10250' at 30fpm. Observe no restrictions or cement patches. Meanwhile pump down pill @ 2.5bpm & 3200psi. 12:15 -12:30 0.25 EVAL P COMP Tag PBTD at 11679' CTD. Wait till perf pill is out of logging tool. 12:30 - 13:15 0.75 EVAL P COMP PUH 41 k & log-up @ 30fpm while laying in 25 bbls high LSRV fresh perf pill in liner. 13:15 -14:45 1.50 EVAL P COMP POOH logging tools from 10250'. 14:45 - 16:00 1.25 EVAL P COMP OOH. SIB injector & blowdown 4 bbls of fluid in CT. 16:00 - 16:15 0.25 EVAL P COMP PJSM on SIB CSH & handling CNL source. 16:15 -16:45 0.50 EVAL P COMP Standback CSH. 16:45 - 17:00 0.25 EVAL P COMP LD GRlCCLlMCNL tool. Download tool & observe only log down data. Suspect memory catridge must have died during log up. 17:00 - 18:00 1.00 EVAL P COMP Line up to & test liner lap. Compressive strength of cement @ 15:25 was @ 2000psi. /A 20 psi @ onset of test. Staged up in 500 psi intervals, monitoring I/A. PT @ 2000 psi, leaked all pressure in 20 mins, no change in IA pressure thoughout test. Review forward plan with town & decide to run KB Inr top Pkr after perforating. 18:00 - 19:45 1.75 PERF N WAIT COMP W. O. perf guns. SWS personnel on other jobs and XO day for crews. Meanwhile fax CNL log data to town geo. CNL GR below 11320' was significantly different from MWD GR. Cause was determined to be tool vibration from high rate pumping of perf pill and displacement fluid 19:45 - 20:15 0.50 PERF P COMP Load guns in pipeshed 20:15 - 20:30 0.25 PERF P COMP Safety mtg re: perf guns 20:30 - 21 :15 0.75 PERF P COMP MU 12 2" SWS perf guns and firing head Printed: 3/25/2002 8:10:25 AM ) ) BP EXPLORATION Oper~tionsSummaryRéport P8ge10f8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From - To Höurs ...Acti\lity Code NPT Phase Descriptiön of Operations 3/20/2002 21 : 15 - 22: 15 1.00 PERF P COMP MU 18 stds CSH workstring 22:15 - 00:00 1.75 PERF P COMP RIH wI CT to 9500' 3/21/2002 00:00 - 00:25 0.42 PERF P COMP Continue RIH wI perf guns 00:25 - 00:35 0.17 PERF P COMP Tag PBD at 11683' CTD. Corr to 11673'. PUH 42k to set depth 00:35 - 01:15 0.67 PERF P COMP Pump 5 bbls fresh mud. Load 5/8" steel ball. Displace with 2% KCI. Ball seat sheared at 2700 psi. Good indications of firing Perforated 11200-450' wI SWS 2" Power Jets @ 4 spf 01:15 - 03:00 1.75 PERF P COMP POOH and losing fluid. Lose 30 bbls while POOH 03:00 - 04:00 1.00 PERF P COMP Standback CSH 04:00 - 04:10 0.17 PERF P COMP Safety mtg re: perf guns. Fill hole w/1 0 bbls 04:10 - 05:35 1.42 PERF P COMP LD perf guns-all shots fired. Load out guns. Fill hole. Losing 4 bbls/hr static 05:35 - 06:00 0.42 RUNCOIVP COMP Load L TP tools to floor 06:00 - 06: 15 0.25 RUNCOIVP COMP Safety mtg re: L TP 06: 15 - 06:35 0.33 RUNCOIVP COMP MIU Baker seal unit, 4.5" KB L TP, RItool, hyd disc, 1jt of 2-3/8 PH6 tbg & CTC. Total length = 50.54 ft. 06:35 - 09:00 2.42 RUNCOIVP COMP RIH with KB L TP BHA#9 @ 73fpm, 0.2 bpm. 09:00 - 10:00 1.00 RUNCOIVP COMP Up wt @ 10350' = 42.5K, dn wt = 19K. Stung seal unit into deploy sleeve @ 10389.3' CTD. Set down 10K @ 10395' CTD. Sting out with seal assy to 10364.3' & pump 5/8" AL ball. Circ @ 2bpm, 800psi. Ball on seat @ 51.9 bbls. RBIH & set down 10K @ 10395' CTD. P/U to 10387.5' (1.5' from up wt). Set pkr slips with 2500psi. Pull 5K over to energize Pkr element. Stack 10K @ 10393.6 ft. Locator is 0.5' off deploy sleeve. 10:00 - 10:45 0.75 RUNCOIVP COMP Pltest pkr @ 2000 psi - leaked 1800psi in 10mins. Carryout injectivity test via the backside - 0.7bpm @ 1800psi. Review options with town, decide to release Rltool & leave L TP in hole. Will decide to either run a csg patch into L TP or fishout L TP & rerun with csg spacers to place L TP above punched holes @ 1 0050'. 10:45 - 12:30 1.75 RUNCOIVN DPRB COMP Press up to 3400psi & release from KB Packer. POOH with Rltool. Top of KB L TP - 10373.42' BKB. Meanwhile decide to go fish out L TP, redress (if possible) & rerun with csg spacers. Line up tools for subsequent operations. 12:30 - 13:00 0.50 RUNCOIVN DPRB COMP OOH. UO Baker RItool BHA#9. 13:00 - 13:30 0.50 RUNCOIVN DPRB COMP M/U L TP retrieving BHA #10 with "GS" spear, hyd disc, dual acting jar, BPV & CTC (OAL = 13.74'). 13:30 -15:10 1.67 RUNCOIVN DPRB COMP RIH with BHA#10 @ 73fpm, 0.2 bpm. 15:10 - 15:30 0.33 RUNCOIVN DPRB COMP Up wt @ 10350' = 41K, dn wt = 19K. Tag L TP @ 10390'. Latch into L TP "GS" profile & jar on pkr slips 9 times. Pull L TP free with 66k max pull. 15:30 - 18:30 3.00 RUNCOIVN DPRB COMP POOH wI LTP. Hung up at 9900', but came thru w/15k overpull. POOH 18:30 - 19:00 0.50 RUNCOIVN DPRB COMP LD fishing BHA and L TP assy. All seals and slips in excellent condition 19:00 - 22:30 3.50 RUNCOIVN DPRB COMP Baker take L TP assy back to shop and redress. Meanwhile, strap and drift tbg. Lose 22 bbls in 3.5 hrs static 22:30 - 00:00 1.50 RUNCOIVN DPRB COMP Safety mtg re: L TP assy. MU seal assy, 11 jts 3-3/16" 6.2# L-80 TC11 tubing, L TP, running tools, one jt PH6 tbg 3/22/2002 00:00 - 00:25 0.42 RUNCOIVN DPRB COMP Fill CT wI 20 bbls. PT CTC @ 3500 psi 00:25 - 02:25 2.00 RUNCOIVN COMP RIH wI L TP patch assy (400' OA) 85'/min 0.7/140 Printed: 3/25/2002 8:10:25 AM ) ) BPEXPLORATION OpèrationsSI,Jïnmary Report . page 8 of ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-28 C-28A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/12/2002 Rig Release: 3/22/2002 Rig Number: Spud Date: 3/12/2002 End: Date From ..:To Hours Activity Code NPT Phâse Dëscriptionof Operations 3/22/2002 02:25 - 03:30 1.08 RUNCOIVN CaMP 42.5k @ 10350'. Sting into liner deployment sub at 10395' CTD 10379.77 ELMO, set down on locator at 10400'. PUH 42k to ball drop at 10358'. Launch 5/8" aluminum ball and circ to seat. RIH and set L TP as prior set with locator 1.5' above deployment sub Top of Baker KB packer is 10024.56' ELMO (after release) 03:30 - 03:55 0.42 RUNCOIVP CaMP Pressure wellbore above packer to 2000 psi w/1 bbl. Held 1930 psi solid for 15 minutes wI no change to IA. Bleed off pressure 03:55 - 05:45 1.83 RUNCOIVP CaMP Pressure ball seat to 3550 psi and sheared. Pull setting tool out of packer. POOH wI running tools 05:45 - 06: 15 0.50 RUNCOIVP CaMP LD setting assy. Pits are clean. Vac truck empty and waiting for return fluid 06:15 - 06:45 0.50 RIGO P CaMP Crew change & PJSM for FP well. 06:45 - 08:00 1.25 RIGD P CaMP RU nozzle assy. RIH to 2000' & POOH freeze protecting with MeOH. SI swab (24). 08:00 - 08:15 0.25 RIGD P CaMP Safety mtg re: N2 08:15 - 10:30 2.25 RIGO P CaMP PT N2 @ 2500 psi. Blow down CT wI N2 & bleed off 10:30 - 12:00 1.50 RIGD P CaMP RD injector for move 12:00 - 14:00 2.00 RIGO P CaMP NO BOPE. NU tree cap and test RREL @ 1400 hrs 3/22/2002 Printed: 3/25/2002 8: 1 0:25 AM ) ) dOd.-otjS 25-Mar-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-28A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,700.00' MD Window / Kickoff Survey 10,719.00' MD (if applicable) Projected Survey: 11,708.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED hPR f;. 2002 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska BPXA PBU_WOA C Pad, Slot C-28 C-28A Job No. AKMW22051, Surveyed: 19 March, 2002 ~,-,,/ SURVEY REPORT 25 March, 2002 Your Ref: 500292086701 SuTface Coordinates: 5959353.00 N, 664359.00 E (70017' 42.9674- N, 148040' 08. 7363- W) Kelly Bushing: 72. 60ft above Mean Sea Level --~ S¡ ]"'''i. ".".y-sUl'1 bRIL.LING .SÈAV'CeS A Halliburton Company Survey Ref: svy11156 ~erry-sun Drilling Services . N Survey Report for C-28A Your Ref: 500292086701 Otr\~\\~ 'JobNo.AKMW22051, Surveyed: 19 March, 2002 BPXA North Slope Alaska PBU_WOA C 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) 10700.00 35.280 210.690 8744.06 8816.66 5124.50 S 1120.52 W 5954205.23 N 663350.80 E -2602.48 Tie on Point 10719.00 35.130 210.690 8759.58 8832.18 5133.91 S 1126.11 W 5954195.69 N 663345.42 E 0.789 -2610.63 Window Point 10742.10 32.340 198.810 8778.81 8851.41 5145.49 S 1131.51W 5954183.99 N 663340.28 E 30.957 -2619.24 10773.90 33.660 179.510 8805.56 8878.16 5162.41 8 1134.18W 5954167.03 N 663337.98 E 33.200 -2626.85 10805.00 29.090 160.280 8832.17 8904.77 5178.198 1131.55 W 5954151.31 N 663340.96 E 35.217 -2629.06 .~ 10834.44 32.700 141.610 8857.49 8930.09 5191.198 1124.17 W 5954138.47 N 663348.61 E 34.648 -2625.92 10876.97 41.840 116.760 8891.49 8964.09 5206.70 8 1104.22 W 5954123.39 N 663368.90 E 41.049 -2611.52 10905.28 50.190 113.090 8911.13 8983.73 5215.24 S 1085.75 W 5954115.27 N 663387.55 E 30.925 -2596.45 10946.28 65.830 106.390 8932.80 9005.40 5226.77 8 1053.09 W 5954104.45 N 663420.45 E 40.553 -2568.74 10999.47 77 . 180 114.690 8949.68 9022.28 5244.54 8 1006.03 W 5954087.72 N 663467.90 E 25.949 -2529.14 11029.48 78.770 108.520 8955.93 9028.53 5255.33 S 978.75 W 5954077.52 N 663495.40 E 20.794 -2506.35 11071.48 82.200 98.650 8962.89 9035.49 5265.03 8 938.54 W 5954068.70 N 663535.81 E 24.569 -2470.88 11102.60 89.780 98.300 8965.07 9037.67 5269.60 8 907.86 W 5954064.81 N 663566.59 E 24.383 -2442.97 11136.23 91 . 1 90 91.080 8964.78 9037.38 5272.35 8 874.37 W 5954062.79 N 663600.14 E 21.873 -2411.84 11166.68 94. 100 82.620 8963.37 9035.97 5270.68 8 844.02 W 5954065.12 N 663630.43 E 29.350 -2382.39 11196.63 92.600 73.990 8961.62 9034.22 5264.63 8 814.78 W 5954071.82 N 663659.54 E 29.197 -2352.66 11232.57 89.170 65.630 8961.07 9033.67 5252.24 8 781.08 W 5954084.94 N 663692.96 E 25.137 -2316.81 11276.21 90.750 53.020 8961.10 9033.70 5230.02 8 743.63 W 5954107.97 N 663729.92 E 29.121 -2274.42 11301.54 92.470 62.040 8960.38 9032.98 5216.448 722.29 W 5954122.01 N 663750.95 E 36.236 -2250.00 11335.66 94.580 70.530 8958.28 9030.88 5202.75 S 691.14W 5954136.38 N 663781.79 E 25.593 -2216.18 11378.53 90.220 82.970 8956.48 9029.08 5192.96 S 649.54 W 5954147.07 N 663823.17 E 30.718 -2173.55 11398.93 90.220 89.670 8956.40 9029.00 5191.66 S 629.19 W 5954148.83 N 663843.49 E 32.843 -2153.75 '-,/ 11439.83 90.220 83.680 8956.24 9028.84 5189.28 S 588.38 W 5954152.09 N 663884.24 E 14.645 -2114.10 11480.75 85.730 72.050 8957.69 9030.29 5180.71 S 548.48 W 5954161.53 N 663923.94 E 30.442 -2073.46 11510.18 88.370 66.580 8959.21 9031.81 5170.33 S 520.99 W 5954172.51 N 663951.19 E 20.614 -2044.13 11534.47 89.250 63.940 8959.71 9032.31 5160.17 8 498.94 W 5954183.15 N 663973.02 E 11 .454 -2020.04 11585.16 89.430 54.600 8960.30 9032.90 5134.30 S 455.42 W 5954209.97 N 664015.96 E 18.428 -1970.78 11612.35 95.680 61.300 8959.09 9031.69 5119.90 S 432.42 W 5954224.87 N 664038.64 E 33.671 -1944.52 11659.50 88.990 66.230 8957.17 9029.77 5099.09 S 390.20 W 5954246.59 N 664080.40 E 17.617 -1898.01 11668.46 86.700 67.820 8957.50 9030.10 5095.60 S 381.96 W 5954250.27 N 664088.56 E 31.107 -1889.10 -- - ------------ -- -------_._-~--~ ------_.-- 25 March, 2002 - 14:24 Page 2 of 3 DrillQuest 2.00.09.003 ~.... ." \"." I¥J#rry-Sun Drillin..g Services F\N\ ~ ~ ¡;.. Survey Report for ~28A Your Ref: 500292086701 D E Job No. AKMW22051, Surveyed: 19 March, 2002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11708.00 86.700 67.820 8959.78 9032.38 Local Coordinates Northlngs Eastlngs (ft) (ft) 5080.70 S 345.40 W 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. Magnetic Declination at Surface is 26.405° (16-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 72.590° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11708.00ft., The Bottom Hole Displacement is 5092.42ft., in the Direction of 183.889° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10700.00 10719.00 11708.00 8816.66 8832.18 9032.38 1120.52 W 1126.11 W 345.40 W Tie on Point Window Point Projected Survey 5124.50 S 5133.91 S 5080.70 S Survey tool program for C-28A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 11708.00 9032.38 MWD Magnetic (C-28A) 25 March, 2002 - 14:24 Page 30f3 Global Coordinates Northlngs Eastlngs (ft) (ft) 5954265.97 N 664124.78 E Dogleg Rate (o/100ft) Vertical Section . BPXA PBU_WOA C Pad Comment 0.000 -1849.76 Projected Survey .~ -" DrillQuest 2.00.09.003 Sc_luIIbll'ger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AlTN: Sherrie -~ Well Job # J-16A ~-OID ~ D.S. 5-32A ~nd-OD I C-28A ;:3,Ori.-()l S 22166 SCMT 22162 MCNL 22164 MCNL ~ Log Description Date 03/29/02 03/05/02 03/20/02 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: RECEIVED LPP 1 9 2002 J .. .. \ ¡ Alaska Oil & GasCOt1s.Ctn'I'- Anchorage Bluellne 04/15/02 NO. 1982 Company: State of Alaska Alaska 011 & Gas Cons Comm Aftn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD 2 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherríe Received~~ ,LJko(>:J ) iI. ~~~~E :f !Æ~l~~~l AIASIiA OIL AND GAS CONSERVATION COlWlISSION / / TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood , CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK. 99519 Re: PBU C-28A BP Exploration (Alaska), Inc. Permit No: 202-045 Sur Loc: 1865' SNL, 1033' WEL, Sec. 19, TIIN, R14E, UM Btmhole Loc. 1695' SNL, 1477' WEL, Sec. 30, TIIN, RI4E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for PBU C- 28A. 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, Jt~, ~r -RrV Cammy Oechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 28th day of February, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA STATE OF ALASKA )- AND GAS CONSERVATION COMI\ PERMIT TO DRILL 20 AAC 25.005 JMH- W£7Å Z/ Z f /0 .1- \ 7-[1$/02- , jl :1J' ))ION kr" (~%' 1 a. Type of work 0 Drill II 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 1865' SNL, 1033' WEL, SEC. 19, T11 N, R14E, UM At top of productive interval 1563' SNL, 2081' WEL, SEC. 30, T11 N, R14E, UM At total depth 1695' SNL, 1477' WEL, SEC. 30, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028305,1695' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 107191 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina Lenath 3-3/4" 3-3116" x 2-7/8 6.2# /6.16# L-80 ST-L 1220' 1 b. Type of well 0 Exploratory Dßtratigraphic Test II Development Oil 0 Service 0 Development Gas [g Single zone,tt> 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool 72.60' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028310 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C-28A 9. Approximate spud da,te 03/11/02 ¡ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) ,,2369- z.o/"?/",,~ 11620' MD /8960' TVDss . 17. Anticipated pressure {s,e 20 AAC 25.035 (e) (2)} 90 Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (include staae data) 10400' 8500' 11620' 8960' 52 cu ft Class 'G' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Size Cemented MD g ~æ fj ~ ~ U'.~ .~ ~ <."1 ~ö u~-g co «:Ie::: C)<e w oð w.... Ô ~ I < TVD Casing Structural Conductor Surface Intermediate Production Liner 11212 feet 9235 feet 11154 feet 9188 feet Length Plugs (measured) c w :> - w EZ Drill Bridge Plug on bottom at 111541 U W ~ 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 Junk (measured) 4-1/2" x SSSV parts in hole (12/95). 110' 20" x 30" 2744' 13-3/8" 10232' 9-5/8" 1221' 7" 9 cu yds Concrete 3993 cu ft Permafrost II 1413 cu ft 'G', 130 cu ft PF 'C' 110' 2744' 10232' 110' 2705' 8437' 441 cu ft Class 'G' 9991' - 11212' 8243' - 9235' 20. Attachments Open Perfs: 10932' - 11006' Sqzd Perfs: 10847' - 10879', 10902' - 10910', 10923' - 10932' true vertical Open Perfs: 9007' - 9067' Sqzd Perfs: 8937' - 8964', 8983' - 8989', 9000' - 9007' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Alistair Sherw~Od' -4378 .. . . .. . .. Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the for~in I~ tr nd correctfo the best of my kn~~ledge . / Signed AlistairSherwood (U (f'b-rcrV't. Title CT Dnlllng Engineer Date/:/2-( ¿,§ /ò 2- Commission Use Only . \ Permit Number API Number ~om~ Ca,k\ 'l See cover letter Zt?2- - 0 c.¡ ç;- 50- 029-20867-01 .\J \ \ Ò U 0\ for other requirements Conditions of Approval: Samples Required 0 Ves ~No Mud log equire( 0 Ves lS;tNo Hydrogen Sulfide Measures .f(I"Ves 0 No Directional Survey Required 6(rr'es 0 No Required Working Pressure for BOPE D2K 0 3K D4K 0 5K 0 10K 0 15K J2l13.5KPß.!~~ 7 Other: I<::N!- -' , 'ø2b~ OR~GtNÅJl.. . "D " -. by order of ~ ~K1 )a Approved By \ ,~ ~ G~E[' ¡:~;\ Commissioner the commission Date \ 0 .- Form 10-401 Rev. 12-01-85 ". M. t ~ell~~, ~ ,.'\. t í ~ b . I T I. t .. ;: \,~ \ \\:: ITI n rpl ae t i",) ~ ¡ \. 'WR Perforation depth: measured ') BPX C-28a Sidetrack ) Summary of Operations: A CTO sidetrack of production well C~28 will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Screen & Prep Well: Screen - MIT-IA. PPPOT~tbg hanger seals. MIT-OA and pressure test tree valves. Prep - Will be started as soon as possible, hopefully before by Mon 4th Mar, 02 i / . Punch 2 sets of holes, (6' interypls) in the 4%" tbg tailpipe at 1 0,372' ~d 10,866' . Set cement retainer at 10,780', between the punched holes& pump 17bbls cement to P&A open perfs and fill 4%" tbg x 7" liner annuls to the top set of holes. . Install a 4%" monobore whipstock at 10,270'md, (8,833' tvd), orientated 1200 left of highside . Phase 2: Drill and Complete CrD sidetrack: Planned for Mon 11th Mar, 02 2%" coil will be used to drill a -900 ft, 3%" open hole sidetrack, (as per attached plan) from a 2 string window cut thru 4Y2 tbg & 7" liner. The sidetrack will be completed with 1,220 ft of solid, cemented & ..-/ perforated, 3-3/16" x 2-7/8" liner. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: I . No annular injection on this well. . All drilling and completion fluids and all other Class 1\ wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 3-3/16", l-80, liner will be run from 10,400'md (TOl, 8,500' TVDss) to approximately 10,820'md, (100' outside of the window). 2-7/8" solid liner will complete the open JJole section to TO at 11,620' md. The completion will be cemented in place with approximately 9.2 bbls (annular volume +40% excess in OH) of 15.8 ppg class G cement. Well Control: . BOP diagram is attached. /' . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . Real time MWO & Gamma Ray logs will be run while drilling the open hole section. . A memory CNUGR/CCl will be run inside liner prior to perforating. Hazards . H2S is not a hazard on C pad. There is no record of C-28 being tested. . No faults are expected while drilling, however several close approaches are made. lost circulation may be experienced depending on the size of associated damaged zones. Reservoir Pressure Reservoir pressure is estimated to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,244 psi. v TREE = 'WELLHEAD= AciÙÄ TOR; Kè~ËlEŸ;;'... .. BF.ELsT ;. KOP= Max)i,ngle; . ., ...."",.... "on..",... ....".."" Datum MD = DcitumlVD; 4"FMC McEVOY ......,,,,. ,,,,..,,, .... BAKER 72.59' 37.29' 2150' ., "'".. ..... ...h... 50 @ 6600' . . . . . . . . . . . . . . ... .. ... ...,.. . 11212' "". ...... .....",,,..,,... 8800' SS ) 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2742' Minimum ID = 3.725" @ 10904' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR l-i 9991' C-28 ) SAFElY NOTES (8 2006' l-i 4-1/2" SSSV, OTIS LANDING NIP, ID = 3.813" 1 ~ ~ GAS LIFT MANDRELS ST MD TVD DEV ìYÆ SIZE LATCH 1 3255 3044 42 OTIS 1-1/2' RA L I I 9931' l-i 4-1/2" OTIS X NIP, ID = 3.813" 1 ~ ) 9942' l-i BAKER PBR SEAL ASSY 1 :g: ~ 9965' l-i 9-5/8" x 4-1/2" BAKER HB PKR, ID = 3.985" 1 .. I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 10232' r---.4 / 10895' l-i BAKER K-22 ANCHOR/LATCH 1 8 & I 10896' l-i 7" x 4-1/2" PKR, BAKER SAB, ID = 4.000" 1 r l I 10904' l-i 4-1/2" OTIS XN NIP, ID = 3.725" 1 I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 10906' 1 I 10906' 1-1 4-1/2" TTL WI OTIS WLEG 1 I 10887' l-i ELMD TT LOGGED 08/28/89 1 ÆRFORA TION SUMMARY REF LOG: DA BHCA on 12/30/82 ANGLE A T TOP ÆRF: 35 @ 10902' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10847-10879 S 08/11/89 3-3/8" 4 10923-10960 S 08/11/89 3-3/8" 4 10932-10966 0 08/28/89 3-3/8" 4 10902-10910 S 09/05/94 3-3/8" 6 1 0966-11 006 0 03/19/97 I PBTD l-i 11154' 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" l-i 11212' DATE 01/05/83 08/13/89 01/31/01 02/28/01 05/22/01 REV BY COMMENTS ORIGINAL COMPLETION RIG WORKOVER CONVERTED TO CANV AS FINAL CORRECTIONS -, ~ FISH - UNKNOWN DEPTHS 4-1/2" X SSSV PA RTS IN HOLE 12/7/95 2- SPlrr RINGS 1/4" X 1/4" X 3.80" OD 4- PIECES OF PA CKING 1- 0 RING 2- TEFLON SPACERS I 11154' l-i EZ DRILL BP ON BTM DA TE REV BY COMMENTS PRUDHOE BA Y UNrr W8...L: C-28 ÆRMrr No: 82-1950 API No: 50-029-20867-00 Sec. 19,T11N,R14E BP Exploration (Alaska) SIS-lsl SIS-MD RNITP TREE = WELLHEAD= ACTUATOR; .. KB. ELEV = SF: ELËV;; .. KOP= Måx Änglë.,,; ... ..... ... ..,,''''', ..."...."",..".. Datum MD = .6aìuíïï'T\i[Þ; .. 4" FMC McEVOY .BÄkffi 72.59' 37.29' 2150' ... "..,,,,,,.,,,,...... ,'. ",,,.or., ,." ""..".........",,,.. .. 50 @ 6600' ... ............ ................. 11212' ....."" ....."'...."""",,,.. 8800' SS ") 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2742' Minimum ID = 3.725" @ 10904' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR 1-1 9991' C-28A Proposed CTD Sidetrack (I) r--J ~ L I I \ ) :8: ~ .. I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10232' ~ ~ 4-1/2" TBG straddle tailpipe, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I-;;;; Perforate Straddle @ 10372' - 10886' One Step Cement Retainer 1-1 10780' 1 ÆRFORA TION SUMMARY REF LOG: DA BHCA on 12/30/82 ANGLE A T TOP ÆRF: 35 @ 10902' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4" 4 10847-10879 isolated proposed 3-3/8" 4 10923-10960 isolated proposed 3-3/8" 4 10932-10966 isolated proposed 3-3/8" 4 10902-10910 isolated proposed 3-3/8" 6 10966-11006 isolated proposed I PBTD 1-1 11154' 1 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" 1-1 11212' DATE 01/05/83 08/13/89 01/31/01 02/28/01 05/22/01 REV BY COMMENTS ORIGINAL COMPLETION RIG WORKOVER CONVERTED TO CANVAS FINAL CORRECTIONS :;,;-¡;~r~: ~, ,~I DA TE REV BY SIS-lsl SIS-MD RNITP COMMENTS ) SAFETY NOTES 2006' 1-1 4-112" SSSV, OTIS LANDING NIP, ID = 3.813" 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE SIZE LATCH 1 3255 3044 42 OTIS 1-1/2' RA 9931' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 9942' 1-1 BA KER PBR SEAL ASSY 1 9965' 1-1 9-5/8" X 4-1/2" BAKER HB PKR, ID = 3.985" 1 110400'1-1 Top of Proposed 3-3/16" Liner 1 10720'1--1 Mill Window off Mechanical Whipstock 1 110780'1-13-3/16" X 2-7/8" XO 1 13-3/16" X 2-718" Liner, Cemented & Perf'd 1-1 11620'1 ~ ~ 10896' 1-1 7" X 4-1/2" PKR, BAKER SAB, ID = 4.000" 1 10904' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 10906' - 4-1I2"1TL WIOTIS WLEG 1 10887' - ELMD TT LOGGED 08/28/89 1 FEH -UNKNOW N DEPTHS 4-112" X SSSV PARTS:N HOLE 12n195 2 - S PLII' R:N G S 1/4 " X 1/4" X 3 B 0 " 0 D 4-PJECES OF PACK:NG 1-0 R:NG 2-TEFLON SPACERS 11154' 1-1 EZ DRILL BP ON BTM PRUDHOE BA Y UNrr WELL: C-28 PERMrr No: 82-1950 API No: 50-029-20867-00 Sec. 19,T11N,R14E BP Exploration (Alaska) BP Amoco - B.. B'" Contact Information: T ^M é LEGEND - Gc-3B (GC-3B) - 6-30 (6-30) - B-3O (B-30A) - C-28 (C-28) - PIan#2 C-28A - Plan #2 Plan: Plan #2 (C-28/Plan#2 C-28A) Azimuths to True North Magnetic North: 26.43. Magnetic Field Strength: 57502nT Dip Angle: 80.80. Date: 217/2002 Model: BGGM2oo1 Created By: Brij Potnis Date: 21112002 ObP WULPATH DETAILS "..112 C.2'A 100282011701 Direct: (907) 267-6613 E-mail: brij.potnis@inteQ.com Baker Hughes INTEQ: (907) 267-ô6Q0 h~TEQ ".rø~:~:r:.~ t.~~..oo IUs: .'.D.t.1I\: J) I 2. 1Z114111'2 OOJOO 72.1011 y~~s: o+~ 71.00' ~~ :~ 0.00 - ----~---- 'c---:-~---;-m_-¡_---,'_-----UTU. - -- --!n~h~_-=-__c_L-=d~_~~i-~u- -~~- - --r- -:--Î-- -4750 --: , . 0.00 - ----- - ---->- --------- REFERENCE INFORMATION Co-ordinate ~Æ) Reference: Well Centre: C-2B, True North v~~ (V~! ~:¡::::: ~~~~ã MO~~~)el Measured Depth Reference: 33: 28 1 ~1411982 OO:()() 72.60 Calo.Jlation Method: Minimum Curvature -4800 = -,------- -4850 .J 2 -~~ --I -4900 ..; ! IICT'ION DETAILS .I).W DL.. TFac. Y$8c Target t 10100..00 3S.Z8 210.88 874&.08 -512""'2 .tt2Q..4.4 0.00 0.00 aZ408.58 2 10710.00 u.u 210". 8711.11 -8133.... .1128.01 0.18 180.00 .24t8AG .a 10128 00 ~20 20718 87.'.1'1 -113'..84 .1'12&.10 20.00 Ut.OO .2GO.H : H~t5 E::i ~~n æ* ~æ~ ~= ~= ~~= :~¡ 7 t 1120.00 80.05 41-00 8880. t:5 .5101." ...ns.eo 12.00 270.00 .1733.88 -4950 --' AHNOTATION8 TVD MO A8_tatiott '7.u.o. 1.700.00 TIP 'UI", 18718.01 KOP .7.7.11 18721.00 1 'NO~' 11017." 2 'HOA~ 11tI7.oo ~ '"°.1111272.00 . 'NI.U 11120.00 TO 8350 8400 -- 8450 8500 - C - .- 8550 - j¡ 8600:: - II) - : = 8650 . a. h & 8700 -- m 8750 U 1:: 8800- ~ II» > 8850 -- II» - ~ 8900 ~ 8950 . ~ 9000 9050 - 9100 . tEJ.JN ~ C3tT2' ~~ ~,~..~~ ~,.Y ~~ ~g.....'~",~~...", 1 .........uv ~'JY -..... r-uo.. .... -- 000 .!I{fiOð .n.67 ~~ 000 -ðM381 .'.U.SV ~ .~ -1 I ' : ---y--- --!~ I , - ¡ -. ¡ - i-- ---~---~-r -5600 -: ;¡ - --~-----L-_- -J_- : f -r ¡ -- ---r---T---J~ i : I , '._~-~~-;---- , i- -~ .: -tH:~,~- !. , -.:,~ j_1 ,i,:J-+t ' ,i,."!,,~,,,r:~-,~I-~!,~t ~1~~~-1400-1350-1300-125O-12~~1~~~11OO-105O-1000 -~~ -900 -850 -800 -750 -7C)() -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 West(-)/East(+) [50ft/in) , . I ' " , I f - ; ~- - ¡- ! - ¡, I I -~. _L,' -Ii - i í ¡: ~~------_--.1_-- 1 ---'-_-t-_L----=-4--. ~ - -~,: - -:, --- ~~ -.---+---- ~---~-----¡----- !---- I! ¡ i ¡ i t -- ! ---t - : - " ! . ! t-_n: 11 ~: - '. I ! - ,- - I ; I I ¡. - n ~ .'" , I! ,i - -, -! ¡ -~[ c-: l1~l~k!2, ¡-T~ì fl- :--!¡~~-i r ¡ i- 1--; ~! 1- . I f ¡ f r ¡ +--:-+- ;-+-c+---¡- i i__- ~--~~-~-' -¡'~--+-+~--b+-+- - - ---I ---~--+~+~ f -. I - : I - --- '- -r I -; f - : ¡ ! i . , , i . . , .;-, : - - 'C+----~Ct=n¡'¡+j. ---I -'-f:~ - ,-; -iT; : : -,-;-~ --,~n, I : ~'==c~-~~'r ;-,:-,~:-,.-c:, c-,;-~- :c~, ;-,;~~+¡:, ¡- , ,.,+;=¡ - - "-fiT'" -r"~F;iT'Ti7 ¡:-r, -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1950 -1900 -Hi50 -1800-1750 -1700-1650 -H~00-1550 -1500 -1450 -1400 -1350 -1300-1250 -1200 -1150 -11 00 -1050 -1600 -950 -900 -850 Vertical Section at 75.00° [50ft/in) -- . ,I - -1. -~-8.' ~ JO(ß.~A. )L.,-c-..; ~1; -~- . flY - ¡ fI- ;. ? . ! I C-2~A T2J : ¡ ii' ; ---- 2/7/2002 3:01 PM ) ) ... IN"IRQ bp BP Amoco Baker Hughes INTEQ Planning Report COl11pany: Field,: Site: Well: WelJpath: Field: Date:, 2/7/2002 ' Time: .15;02':22 PlIge: Co~..diriate(NE) Reference: W~II: C~28,.TrueNor1h " . ' Vertical(TVD) Refere~ce: System: Meéi" SeaLEwel. .' Section (VS)Reference: . Well (0.00N,O.OOE,75.00Azi) Survey Calculation Method: Minimum Curvature , , Db: BPAmoco' , , Pri.\dhòe,Bay PB CPad ' C~28 Plan#2 C~28A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: C-28 C-28 Well Position: Well: Map Zone: Coordinate System: Geomagnetic Model: 5957218.72 ft 662550.03 ft Alaska, Zone 4 Well Centre BGGM2001 Latitude: Longitude: North Reference: Grid Convergence: 70 17 22.367 N 148 41 2.797 W True 1.24 deg Slot Name: +N/-S 2094.80 ft Northing: 5959352.98 ft +E/-W 1854.82 ft Easting: 664359.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 28 70 17 42.967 N 148 40 8.736 W Wellpath: Plan#2 C-28A 500292086701 Current Datum: 33: 28 12/14/1982 00:00 Magnetic Data: 2/7/2002 Field Strength: 57502 n1' Vertical Section: Depth From (1'VD) ft 0.00 Plan #2 Identical to Lamar's Plan #2 Principal: Yes Plan: Targets Name Description TVD ft C-28A Polygon2.1 0.00 -Polygon 1 0.00 -Polygon 2 0.00 -Polygon 3 0.00 -Polygon 4 0.00 -Polygon 5 0.00 -Polygon 6 0.00 C-28A Fault1 0.00 -Polygon 1 0.00 -Polygon 2 0.00 C-28A Fault2 0.00 -Polygon 1 0.00 -Polygon 2 0.00 C-28A Fault3 0.00 -Polygon 1 0.00 -Polygon 2 0.00 C-28A Fault4 0.00 -Polygon 1 0.00 -Polygon 2 0.00 -Polygon 3 0.00 -Polygon 4 0.00 C-28A T2.1 8960.00 Height 72.60 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Date Composed: Version: Tied-to: +N/-S ft -5291.78 -5291.78 -5181.80 -5150.05 -5036.55 -5146.54 -5260.03 Map Map Northing )Lasting ft ft 5954044.82 663651.31 5954044.82 663651.31 5954154.82 663651.29 5954189.86 663801.28 5954309.94 664101.25 5954199.93 664101.28 5954079.86 663801.30 +E/~W ft -823.65 -823.65 -821.27 -670.54 -367.99 -370.37 -672.92 -5109.08 -714.67 5954229.85 663756.27 -5109.08 -714.67 5954229.85 663756.27 -4561.66 -587.80 5954779.87 663871.13 -5553.87 -1424.50 5953769.67 663056.38 -5553.87 -1424.50 5953769.67 663056.38 -5385.14 -900.69 5953949.81 663576.34 -5343.42 -979.82 5953989.78 663496.33 -5343.42 -979.82 5953989.78 663496.33 -5531.28 -618.77 5953809.88 663861.37 -5416.98 -816.36 5953919.82 663661.34 -5416.98 -816.36 5953919.82 663661.34 -5249.12 -252.56 5954099.96 664221.30 -5139.30 219.96 5954220.08 664691.27 -5249.12 -252.56 5954099.96 664221.30 -5236.79 ~822.46 5954099.82 663651.30 C-28 10719.00 ft Mean Sea Level 26.43 deg 80.80 deg Direction deg 75.00 2/7/2002 1 From: Definitive Path , <-...;- . Latitude --:-.,.> <--. Lo~gitude--"'> DegMln Sec Deg Min ..... Sec 70 16 50.922 N 148 40 32.726 W 70 16 50.922 N 148 40 32.726 W 70 16 52.004 N 148 40 32.657 W 70 16 52.316 N 148 40 28.266 W 70 16 53.433 N 148 40 19.454 W 70 16 52.351 N 148 40 19.524 W 70 16 51.235 N 148 40 28.335 W 70 16 52.719 N 148 40 29.552 W 70 16 52.719 N 148 40 29.552 W 70 16 58.103 N 148 40 25.858 W 70 16 48.344 N 148 40 50.224 W 70 16 48.344 N 148 40 50.224 W 70 16 50.004 N 148 40 34.969 W 70 16 50.414 N 148 40 37.274 W 70 16 50.414 N 148 40 37.274 W 70 16 48.567 N 148 40 26.757 W 70 16 49.691 N 148 40 32.513 W 70 16 49.691 N 148 40 32.513 W 70 16 51.342 N 148 40 16.092 W 70 16 52.422 N 148 40 2.329 W 70 16 51.342 N 148 40 16.092 W 70 16 51.463 N 148 40 32.691 W ) BP Amoco ) ..8 i þp ea.. Baker Hughes INTEQ Planning Report ...- -,.-.,...,----------_..-- IN'fEQ Company: BP Amoco Date:. 2/712002 Time:.. .15:02:22 P~ge: 2 Field: Prudhoe Bay Co-ordinate(NE) .Reference: Wen: C..28, True North Site: PB C Pad Vertical (TVD) R~ference: System: Mean Sea level Well: C-28 Section (VS) Reference: Wen (O.OON ,O.00E,75.00Azi) WelIpath: Plan#2 G-28A Survey Calculation Method: . Minimum Curvature Db: . Oracle Targets Map Map <--'- .. Latitude... ..,....;..> <-.... Longitude -...;.> Name Descl'iption TVD +N/'-S +E/-W N()rthi~g Easting Deg MinSec DegMin Sec ft ft ft ft ft C-28A T2.2 8960.00 -5105.46 -419.50 5954239.92 664051.27 70 16 52.755 N 148 40 20.955 W Annotation MD TVD ft ft 10700.00 8744.06 TIP 10719.00 8759.58 KOP 10729.00 8767.81 1 11057.00 8960.35 2 11167.00 8960.43 3 11272.00 8960.51 4 11620.00 8960.13 TO Plan Section Information MD loci Azim TVD +NI-S +E/-W DLS Build TUfn TFO Target ft deg deg ft ft ft degl100ft degl100ftdég/100ft deg 10700.00 35.28 210.69 8744.06 -5124.42 -1120.44 0.00 0.00 0.00 0.00 10719.00 35.13 210.69 8759.58 -5133.84 -1126.03 0.79 -0.79 0.00 180.00 10729.00 34.20 207.58 8767.81 -5138.80 -1128.80 20.00 -9.31 -31.13 241.00 11057.00 90.08 90.36 8960.35 -5256.45 -956.31 32.00 17.04 -35.74 247.00 11167.00 89.85 77.17 8960.43 -5244.53 -847.20 12.00 -0.21 -12.00 269.00 11272.00 90.07 89.76 8960.51 -5232.60 -743.09 12.00 0.21 12.00 89.00 11620.00 90.05 48.00 8960.13 -5109.99 -425.60 12.00 0.00 -12.00 270.00 Survey MD Incl Azim SSTV.D N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10700.00 35.28 210.69 8744.06 -5124.42 -1120.44 5954205.65 663350.95 0.00 -2408.56 0.00 TIP 10719.00 35.13 210.69 8759.58 -5133.84 -1126.03 5954196.10 663345.57 0.79 -2416.40 180.00 KOP 10725.00 34.56 208.84 8764.51 -5136.81 -1127.74 5954193.09 663343.93 20.00 -2418.81 241.00 MWO 10729.00 34.20 207.58 8767.81 -5138.80 -1128.80 5954191.09 663342.91 19.96 -2420.36 242.50 1 10750.00 32.10 195.88 8785.41 -5149.41 -1133.07 5954180.38 663338.88 32.01 -2427.23 247.00 MWO 10775.00 31.16 180.70 8806.73 -5162.29 -1134.97 5954167.4 7 663337.26 32.00 -2432.39 256.80 MWO 10800.00 32.03 165.49 8828.06 -5175.20 -1133.38 5954154.60 663339.13 32.00 -2434.20 269.75 MWD 10825.00 34.59 151.66 8848.98 -5187.88 -1128.34 5954142.03 663344.44 32.00 -2432.62 282.73 MWD 10850.00 38.49 139.90 8869.08 -5200.10 -1119.95 5954130.00 663353.10 32.00 -2427.67 294.31 MWD 10875.00 43.37 130.20 8887.98 -5211.61 -1108.36 5954118.74 663364.94 32.00 -2419.46 303.77 MWD 10900.00 48.93 122.20 8905.31 -5222.19 -1093.81 5954108.49 663379.72 32.00 -2408.14 311.11 MWD 10925.00 54.95 115.50 8920.73 -5231.63 -1076.57 5954099.42 663397.16 32.00 -2393.93 316.66 MWD 10950.00 61.29 109.75 8933.93 -5239.76 -1056.98 5954091.73 663416.92 32.00 -2377.12 320.80 MWO 10975.00 67.84 104.66 8944.67 -5246.40 -1035.43 5954085.56 663438.61 32.00 -2358.02 323.85 MWO 11000.00 74.54 100.04 8952.73 -5251.44 -1012.33 5954081.02 663461.81 32.00 -2337.01 326.04 MWD 11025.00 81.33 95.70 8957.95 -5254.77 -988.13 5954078.22 663486.07 32.00 -2314.50 327.53 MWD 11050.00 88.16 91.52 8960.25 -5256.34 -963.31 5954077 .20 663510.93 32.00 -2290.92 328.44 MWD 11057.00 90.08 90.36 8960.35 -5256.45 -956.31 5954077.24 663517.92 32.07 -2284.19 328.80 2 11075.00 90.04 88.20 8960.33 -5256.23 -938.31 5954077.86 663535.91 11.98 -2266.75 268.90 MWD 11100.00 89.99 85.20 8960.33 -5254.79 -913.36 5954079.84 663560.83 12.00 -2242.27 269.00 MWD 11125.00 89.93 82.20 8960.35 -5252.05 -888.51 5954083.13 663585.61 12.00 -2217.56 269.00 MWD 11150.00 89.88 79.20 8960.39 -5248.01 -863.84 5954087.70 663610.18 12.00 -2192.69 269.00 MWD 11167.00 89.85 77.17 8960.43 -5244.53 -847.20 5954091.55 663626.74 11.97 -2175.72 269.12 3 11175.00 89.86 78.13 8960.45 -5242.82 -839.39 5954093.43 663634.51 11.94 -2167.73 89.24 MWD 11200.00 89.92 81.12 8960.50 -5238.32 -814.80 5954098.47 663659.00 12.00 -2142.81 89.00 MWD 11225.00 89.97 84.12 8960.52 -5235.11 -790.01 5954102.22 663683.71 12.00 -2118.03 88.99 MWD 11250.00 90.02 87.12 8960.52 -5233.20 -765.08 5954104.67 663708.58 12.00 -2093.47 88.99 MWD ) BP Amoco ) .£ Baker Hughes INTEQ Planning Report .- ,- -.------- ..------- -.- IN'r EQ Company: BP AmocQ Date: 2/7/2002 Time:. .. .15:02:22 FIeld: Prudhoe Bay Co-ordi~ate(NE)Referenee: Well: C-28, True North Site: PB C Pad Vertical (TVD) Reference: Sys~em: Mean Sea Lev~1 Well: C-28 Section. (VS) Reference: Well (O.CON I O~OOE. 75,00Azi) WelJpath: Plan#2C-28A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE nLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11272.00 90.07 89.76 8960.51 -5232.60 -743.09 5954105.75 663730.56 11.99 -2072.07 88.94 4 11275.00 90.07 89.40 8960.50 -5232.58 -740.09 5954105.83 663733.55 11.89 -2069.17 269.64 MWD 11300.00 90.07 86.40 8960.47 -5231.67 -715.11 5954107.29 663758.50 12.00 -2044.80 270.00 MWD 11325.00 90.07 83.40 8960.44 -5229.45 -690.21 5954110.06 663783.35 12.00 -2020.18 270.00 MWD 11350.00 90.07 80.40 8960.42 -5225.92 -665.47 5954114.12 663808.01 12.00 -1995.36 269.99 MWD 11375.00 90.07 77.40 8960.39 -5221.11 -640.94 5954119.46 663832.43 12.00 -1970.42 269.99 MWD 11400.00 90.07 74.40 8960.36 -5215.03 -616.69 5954126.08 663856.53 12.00 -1945.43 269.99 MWD 11425.00 90.06 71.40 8960.33 -5207.68 -592.80 5954133.95 663880.25 12.00 -1920.45 269.98 MWD 11450.00 90.06 68.40 8960.30 -5199.09 -569.33 5954143.05 663903.53 12.00 -1895.55 269.98 MWD 11475.00 90.06 65.40 8960.27 -5189.28 -546.33 5954153.36 663926.31 12.00 -1870.80 269.98 MWD 11500.00 90.06 62.40 8960.25 -5178.29 -523.88 5954164.84 663948.51 12.00 -1846.27 269.97 MWD 11525.00 90.06 59.40 8960.22 -5166.13 -502.04 5954177.47 663970.08 12.00 -1822.03 269.97 MWD 11550.00 90.06 56.40 8960.20 -5152.85 -480.86 5954191.21 663990.96 12.00 -1798.13 269.97 MWD 11575.00 90.05 53.40 8960.17 -5138.48 -460.41 5954206.02 664011.09 12.00 -1774.66 269.96 MWD 11600.00 90.05 50.40 8960.15 -5123.05 -440.74 5954221.87 664030.42 12.00 -1751.67 269.96 MWD 11620.00 90.05 48.00 8960.13 -5109.99 -425.60 5954235.26 664045.27 12.02 -1733.66 269.94 TD ') BOP-Tree ") it Well I C-28A I I. . ...... . .. .. u .:. .. . .. u',' Rig Floor KB Elevation I I ~n~ . .. '.'.' ,,'HI[' I, D '.'" Lubricator JD = 6.375' with 6" Otis Union' I : I ~:I KY.@~A.~'$t~..) 171/16" 5000 psi BO~'S. 10 = 7.06" I f:~~::mæi:B~í:::::::1 l ,:~.~~t;;:::.:~/ .' . u' .I }-: ... 11/4 Turn L T Valve I I I 1'.....1'..1..1.............1 . I. ..... 'r: ~7~'~~~~1:~. ... . u . J ... 111 ~. r', " " ""r ~~16" 5000 ps, RX.46 I . ~I~.~.;.:'I~ @ ill @ IT.. . À T 'i): 1;!:~!M!:e I ¡~l~:;~~j~~ l:i:~1~~n:o p:¡ ,RX-2! .' i ì 1 I 7 1/16" 5000 psi (RX-46) or F: .::.~::: -:: ::-~ J +-- 4 1/16" 5000 psi (RX-39) . iÎjr-~\,,".,...J ~g .t ':'.-:'~~~ ~~ -: '1rro:~.- :'f.lôw.:~"(eé. ::::7: ~':~O.:. :.. :.. ::.;,..:~~.~...?::..;.: :~r:: c:.~" ''',' . . g:AtMy. ..:: : --.. ,~'I!".i~"-¡~~,!_i~ili~"':' ~ ~ L..:.'" :....,,,.1.1111111.11111111111111110111111111.( J GP:,,:;-r ~-- ~::',:Ö.:..:'.;: I ssv I ..... . .:: ...:.: "i . "t."~" .-. ~ .;?~;; ~O~~ :);f;'~; I?~~~{.~W@~ rht&-1.f~!:~ ~:,,:"'~~'.~.,,~., ~..:~ I I ~,: ','~ ':".':1 . 171/16" 5000 p!ili, RX-~13 - / I Swab Valve I Tree Size I I I Master Valve I I tubing x 9-5/811 Annulus I . .... ........ .. .. "."......-..... .. .... .... I . ~<.'(Y:;::..;Y.'., . EfGrû'.... .-:..:. ....::.BJ . (' . :.;:::::}~~:':T~~::~~;~f~~..; '..1 . 19-5/811 X 13-3/811 Annulus I ~ . "":,-::",,,,,,,:,,,:"":""'.:-...:..", :.~ ;:':/ :~.:: :::. ~i: ~;' ~:'.;::: :.:.:.:::.:--:..:.:.:-:.:.:--:~:-:.:.:::,.:.:«.:..:.:.:.:. I Base FlanQe I Page 1 ) ) H 204447 DATE 01/17/02 CHECK NO. 00204447 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 011602 CK011602N PYMT COMMENTS: HANDLING INST: 100.00 Per~it to Drill Fee 8tH - Terrie HubJle X4628 ~1~8A RECEI\fED FE B 2 5 2002 Alaska Oil & Gas Cons. Commissíon Anchorage IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H2O 4 4 4 7 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 --¡.j2 00204447 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 r;¿~J~~~ 118 2 0 L, 1. L, ? 118 I: 0 1. ~ 2 0 :I 8 ~ 5 I: 0 0 8 1. L, ~ g 118 ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME f3¡J ~~Zý'/J ,J" CHECK 1 STANDARD LEITER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) DEVELOPMENT REDRILL ./ ~ PILOT HOLE (PH) EXPLORATION ANNULAR DISPOSAL // (,7 ANNULAR DISPOSAL INJECTION WELL L-) YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL. "CLUE" Tbe permit is for a new wel1bore segment of existing weD ------' Permit No, . API No. . ". Production sbould continue to be reported as a function of tbe original API number stated above. . In accordance with 2.° AAC 25.005(f), all r~ords, data and logs acquired for tbe pilot hole must be clearly . differentiated in botb 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 bas not been requested. . . Annular Disposal. of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L-) YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. Tbe permit is approved ,sùbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to the spacing exception tbat may occur. WELL PERMIT CHECKLIST COMPANY ;Px: WELL NAME ${ f'- ~ ZR' A- FIELD & POOL ~ '1/:; /<::1") INIT CLASS :l?r-==I/ I OJ I -- 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. . . . . . . . A~R DATE 12. Permit can be issued without administrative approval.. . . . . N }> Þ ¡. . 27- D 2- 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. .' . . . . . . . . . . . . . . . . . ¥-- -N N / A 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N 16. CMT vol adequate to circulate on conductor & surf csg. . . . ..¥--N-" 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥:--N- .' .' -L 18. CMT will cover all known productive horizons. . . . . . . . . . NJ N A'¿L'J UA t.e ~ C£C:7> > ~ l.. . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ~. N 0 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ~ N c..:r 0 U. 21. If a re-drill, has a 10-403 for abandonment been approved. . . éj) N Ay froV'ed -¿/24l(}z. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . @ N . 23. If diverter required, does it meet regulations. . . . . . . . . . ¥-N- (oJ/A 24. Drilling flUid. program schematic & equip list adequate. . . . . ~ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 26. BOPE press rating appropriate; testto 'šS CO psig. N sf-d, qU RofJ 6- kst. ,vi S p -::. 2.. ,-i./-'f r I (' . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . lÍl, N 28. Work will occur without operation shutdown. . . . . . . . . . . (J..J ~... 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (b!! 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y-@) 31. Data presented on potential overpressure zones. . . . . . . y.-N 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . ~. . " ~/Y N AP~ DATE 33. Seabed condition survey (If off-shore). . . . . . . . . '" Y N þU 2-.21.01- 34. Contact name/phone for weekly progress reports (exgl tory only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . '. . . (B) will not contaminate freshwater; or cause drilling waste. ., to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENG¡ERING: UIC/Annular: COMMISSION: RPC~. TEM 1"ìf);)I;).~ COT SFD WGA c:¡k' DTS oz./lJ/o '- ./ JMH dNH Z/Z8/02- APPR DA ~Ei WqÆ l/lfOl. jf~ ~l. (P-'¡f L ~ GEOLOGY APPR DATE G:\geology\templates\checklist.doc PROGRAM: Exp - Dev - Redrll ~~erv - Well bore seg - Ann. disposal para req - GEOL AREA BrtJ UNIT# (? / /0-Ç() ON/OFF SHORE ()/l .;Jþ.rí~c:.AL h~h~ ~ Api- c>2-&-"3os;-'/' 'í~ó ~~d ~i/~dr -r:):)..À\.. /fP{- ò z[f'3/0 . <: Y N Y N Ab ~k d{t,(W"",,- ( V"t¡,t.f~-kJ Comments/Instructions: ) Ì\ ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 20 17:26:06 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/20 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. ) Scientific Technical Services Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: mwd RUN 1 AK-MW-22051 C. ZAWADZKI WHITLOW/SARB # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD C-28A 500292086701 BPXA Sperry Sun 20-JAN-03 mwd RUN 2 AK-MW-22051 C. ZAWADZKI WHITLOW/SARB 19 UN 14E 1865 1033 72.60 72.60 .00 mwd RUN 3 AK-MW-22051 C. ZAWADZKI WHITLOW/SARB OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 10719.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS) . 3. WELL KICKED OFF FROM C-28 WITH TOP OF WHIPSTOCK SET dOd-OtlS 'I I ~<61 ) ) AT 10719' MD, 8759.6' TVDSS. 4. MWD RUN 1 WAS DIRECTIONAL WITH PRESSURE CASE GAMMA (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUNS 2-3 WERE DIRECTIONAL WITH GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 6. RESISTIVITY DATA FOR THE INTERVAL FROM 10724' MD / 8763' TVDSS TO 10965' MD / 8938.7' TVDSS WAS ACQUIRED ON WIPE PASS PERFORMED WHILE TRIPPING OUT OF HOLE PRIOR TO MWD RUN 2. 7. RESISTIVITY DATA FOR THE INTERVAL FROM 10951' MD / 8934' TVDSS TO 11678.5' MD / 8958' TVDSS WAS ACQUIRED ON MAD PASS PERFORMED WHILE TRIPPING OUT OF HOLE AFTER TO MWD RUN 3. 8. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER LOG OF 3/20/2002, PER THE 4/24/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG AND HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 1-3 REPRESENT WELL C-28A WITH API # 50-029-22259-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11708' MD / 89608670' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SGRD = SMOOTHED GAMMA SEXP = SMOOTHED PHASE SHALLOW SPACING) SESP = SMOOTHED PHASE SHALLOW SPACING) SEMP = SMOOTHED PHASE SPACING) SEDP = SMOOTHED PHASE SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING CURVES WITH "M" SUFFIX DENOTE MAD PASS DATA $ RAY - SCINTILLATION DETECTORS SHIFT DERIVED RESISTIVITY ( EXTRA SHIFT DERIVED RESISTIVITY ( SHIFT DERIVED RESISTIVITY ( MEDIUM SHIFT DERIVED RESISTIVITY ( DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS RPX FET RPM RPD Rap $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 10394.0 10723.0 10723.0 10723.0 10723.0 10723.0 10739.5 STOP DEPTH 11660.5 11679.0 11679.0 11679.0 11679.0 11679.0 11709.5 # ) ') BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 10411.0 10411.5 10727.5 10727.5 10799.0 10798.5 10844.5 10844.5 10874.0 10873.5 10922.0 10922.0 10975.0 10974.0 11046.5 11048.0 11145.0 11144.5 11157.0 11161.5 11185.0 11188.5 11224.5 11228.5 11583.0 11577.0 11623.0 11626.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 10394.5 10988.0 MWD 2 10988.5 10996.0 MWD 3 10996.5 11708.0 $ # 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 .1IN Max frames per record............ .Undefined Ab s en t val u e . . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/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 HRS 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10394 11709.5 11051.8 2632 10394 11709.5 Rap MWD FT/H 0.44 436.52 109.185 1941 10739.5 11709.5 GR MWD API 15.07 1125.04 31. 0007 1985 10394 11660.5 RPX MWD OHMM 2.32 1475.76 13.5266 1913 10723 11679 RPS MWD OHMM 2.76 2000 25.2305 1913 10723 11679 RPM MWD OHMM 2.99 2000 26.974 1913 10723 11679 RPD MWD OHMM 3.57 2000 32.5889 1913 10723 11679 FET MWD HRS 0.19 51.88 4.59716 1913 10723 11679 First Reading For Entire File......... .10394 Last Reading For Entire File.......... .11709.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 ) ) File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .03/01/20 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FI LE HEADER FI LE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RAT RPS FET RPM RPX RPD $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10923.0 10947.5 10950.0 10950.0 10950.0 10950.0 10950.0 STOP DEPTH 11665.0 11690.5 11680.0 11680.0 11680.0 11680.0 11680.0 # MERGED DATA SOURCE PBU TOOL CODE $ MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE # REMARKS: MERGED MAD 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 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 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10923 11690.5 11306.8 1536 10923 11690.5 RAT MAD FT/H 181.54 607.6 581.695 1487 10947.5 11690.5 GR MAD API 8.38 92.07 29.3574 1485 10923 11665 RPX MAD OHMM 2.53 18.4 9.309 1461 10950 11680 RPS MAD OHMM 2.81 20.56 11.7054 1461 10950 11680 RPM MAD OHMM 3.12 23.5 13.1314 1461 10950 11680 RPD MAD OHMM 5.22 22.22 14.8345 1461 10950 11680 FET MAD HR 0.32 36.41 10.2126 1461 10950 11680 ) First Reading For Entire File......... .10923 Last Reading For Entire File.......... .11690.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 File Type................ La Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR Rap $ 3 ) header data for each bit run in separate files. 1 .5000 START DEPTH 10394.5 10740.5 STOP DEPTH 10944.0 10988.0 # LOG HEADER DATA DATE LOGGED: 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # 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) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 18-MAR-02 Insite 4.3 Memory 10989.0 10740.0 10989.0 29.0 66.0 TOOL NUMBER 120378 3.750 10719.0 FloPro 8.63 62.0 8.6 11400 7.8 .000 .000 .000 .000 .0 140.0 .0 .0 ) # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit DEPT FT Rap MWD010 FT/H GR MWD010 API Min 10394.5 0.44 15.07 Max 10988 436.52 1125.04 Mean Nsam 10691.3 1188 50.113 496 35.5995 552 First Reading For Entire File......... .10394.5 Last Reading For Entire File.......... .10988 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS 4 ) First Reading 10394.5 10740.5 10394.5 Last Reading 10988 10988 10944 header data for each bit run in separate files. 2 .5000 START DEPTH 10724.0 10724.0 STOP DEPTH 10965.0 10965.0 ) RPM RPD FET GR ROP $ 10724.0 10724.0 10724.0 10944.5 10988.5 10965.0 10965.0 10965.0 10949.0 10996.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # 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) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................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 Ab s en t val u e. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 18-MAR-02 Insite 4.3 Memory 10996.0 10989.0 10996.0 .0 .0 TOOL NUMBER 120378 3.750 10719.0 FloPro 8.63 62.0 8.6 11400 8.0 .160 .085 .220 .200 70.0 138.2 70.0 70.0 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 HR 4 1 68 28 8 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10724 10996 10860 545 10724 10996 Rap MWD020 FT/H 10 184.65 101.477 16 10988.5 10996 GR MWD020 API 28.17 35.76 31.604 10 10944.5 10949 RPX MWD020 OHMM 2.32 1475.76 16.6924 483 10724 10965 RPS MWD020 OHMM 2.76 2000 59.1774 483 10724 10965 RPM MWD020 OHMM 2.99 2000 63.2968 483 10724 10965 RPD MWD020 OHMM 3.57 2000 82.805 483 10724 10965 FET MWD020 HR 10 51. 88 14.0825 483 10724 10965 First Reading For Entire File......... .10724 Last Reading For Entire File.......... .10996 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS Rap $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 10949.5 10965.5 10965.5 10965.5 10965.5 10965.5 10996.5 STOP DEPTH 11663.5 11677.5 11677.5 11677.5 11677.5 11677.5 11708.0 # LOG HEADER DATA DATE LOGGED: 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: 19-MAR-02 Insite 4.3 Memory 11708.0 10996.0 11708.0 77.2 95.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER 120378 ) ) # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10719.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FloPro 8.63 62.0 8.6 11400 8.0 .160 .078 .220 .200 70.0 150.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10949.5 11708 11328.8 1518 10949.5 11708 Rap MWD030 FT/H 0.45 347.58 129.604 1424 10996.5 11708 GR MWD030 API 16.31 94.94 29.5331 1429 10949.5 11663.5 RPX MWD030 OHMM 2.5 23.58 12.3994 1425 10965.5 11677.5 RPS MWD030 OHMM 2.87 24.55 13.706 1425 10965.5 11677.5 RPM MWD030 OHMM 3.22 24.59 14.6483 1425 10965.5 11677.5 RPD MWD030 OHMM 5.37 24.39 15.5809 1425 10965.5 11677.5 FET MWD030 HR 0.19 20.23 1.38606 1425 10965.5 11677.5 First Reading For Entire File......... .10949.5 Last Reading For Entire File.......... .11708 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/20 Maximum Physical Record..65535 ) ) File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/20 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File