The URL can be used to link to this page

Home My WebLink About204-094Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J 0 ~ - 0 fJ Y- Well History File Identifier Page Count from Scanned File: to 1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES a Date?; / dZ/ Db If NO in stage 1, page(s} discrepancies were found: YES Organizing (done) o Two-sided 111111111111111111I RESCAN ~Ior Items: o Greyscale Items: DIGITAL DATA \Ø'Öiskettes, No. , o Other, No/Type: o Poor Quality Originals: o Other: NOTES: Date Cf, I ~<ðJO to Date g; I i)J3/ D 0 ~ X 30 = t£J ô + Date: <3/ :J-$j 0 ft; BY: ~ Project Proofing BY: ~ (;¡.- Scanning Preparation BY: ~ Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mP 111111111111111111I vvlP &ó MP Isl Isl = TOTAL PAGES (Count does not include cover sheet) Isl 11111111I1111111111 NO Isl VltP NO Isl 1111111111111111111 1/11111111111111111 Isl Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 RECD./TV Mr. Tom Maunder MIG 1 1 2 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Almke Oil & Gea con. Gtimission Anchorage, Alaska 99501 r nc3nr>ge Subject: Corrosion Inhibitor Treatments of GPB C -Pad ao P '_ Cl if Dear Mr. Maunder, 1'1B Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C - 038 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -088 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMON ~IAY ~ 2 2~~~ REPORT OF SUNDRY WELL OPERATIONS ~~„~„ ~,;~ ~, ~,~ f~r,r5~_ I~ommissip 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ StimulateQ they ~ ~ , ~~f~ f g ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 204-0940 3. Address: P.O. Box 196612 Stratigraphic d° Service 6. API Number: Anchorage, AK 99519-6612 50-029-20439-02-00 7. KB Elevation (ft): 9. Well Name and Number: 61.7 KB PBU C-17B 8. Property Designation: 10. Field/Pool(s): ADLO-028304 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12770 feet Plugs (measured) 12215' true vertical 8944.05 feet Junk (measured) 12682' Effective Depth measured 12682 feet true vertical 8945.61 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2662 13-3/8" 72# L-80 Surface - 2662 Surface - 2662 5380 2670 Production 10498 9-5/8" 47# L-80 Surface - 9418 Surface - 7459 6870 4760 Liner 10348 7" 26# L-80 Surface - 10373 Surface - 8329 7240 5410 Liner 2547 4-1/2" 12.6# L-80 10222 - 12769 8183 - 8944 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 23 -10228 5-1/2" 17# L-80 8963 - 9418 Packers and SSSV (type and measured depth) 9-5/8" DV Packer 2584 7" Top Packer 9245 4-1/2" Baker SABL-3 Packer 10171 5" Baker ZXP Top Packer 10229 12. Stimulation or cement squeeze summary: Intervals treated (measured): Ali ~~~~~~~ ~tii ~' ~~11r~ Treatment descriptions including. volumes used and final pressure: .:.~ ~ ~UU~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 196 21148 2 767 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development r~ service r- Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature ~ ''' Phone 564-4944 Date 5/12/2009 Form 10-404 Revised 04/2006 ~', ~` ~ NAY ~ ~ ~D09 Submit Original Only ~~~~~ 6~~ ~%~6~ C-17B 204-094 PERF ATT,4CHMENT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-17B 7/19/04 PER 11,330. 11,515. 8,987.49 8,989.16 C-176 7/19/04 PER 11,680. 11,750. 8,985.41 8,982.07 C-17B 7/19/04 PER 11,770. 11,875. 8,981.11 8,976.95 C-17B 7/19/04 PER 12,010. 12,045. 8,974.68 8,975.22 C-17B 7/19/04 PER 12,390. 12,450. 8,965.83 8,967.19 C-17B 7/19/04 PER 12,465. 12,675. 8,959.97 8,945.84 C-17B 12/25/07 BPS 10,180. 11,330. 8,142.1 8,987.49 C-176 4/16/08 BPP 10,180. 11,330. 8,142.1 8,987.49 C-17B 4/27/09 APF 11,206. ~/ 11,231. 8,979.14 8,983.47 C-176 4/27/09 BPS 12,215. 12,220. 8,973.89 8,973.76 C-17B 4/28/09 APF 11,140. 11,150. 8,959.75 8,963.28 C-17B 4/29/09 APF 11,118. ~/" 11,128. 8,951.25 8,955.23 C-17B 4/29/09 APF 11,172. 11,182. 8,970.33 8,973.21 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r~ ~J C-17B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/26/2009,**WELL SI ON ARRIVAL*** (SET CIBP, PERFORATE) INITIAL T/I/0 = 2250/600/0. `LRS STABBED ON TO TREECAP TO KILL WELL WITH 290 BBLS ' 1 %KCL. ***CONTINUED ON 27-APRIL-2009*** 4/26/2009,T/I/0=2250/440/0 Assist E-line, Load Tbg (Profile Modification) Pumped 3 bbls neat followed by 200 bbls 1 %KCI down Tbg to load ;well. *""Continued on 4-27-09 WSR'`** 4/27/2009 "'"CONTINUE FROM 26-APRIL-2009"** 'WELL KILLED. 290 BBL 1%KCL AND 40 BBL CRUDE. WELL .BEGAN ON VAC, PRESSURE CLIMBS AS DAY CONTINUES. DRIFT ACROSS PLUG SETTING DEPTH WITH 3.70" CENTRALIZER TO 12350'. LOG JEWELRY LOG TO GLfvl #1 WHILE POOH. SET HES 4.5" EZ DRILL CIBP AT 12215' IN THE MIDDLE OF A FULL JT. LRS KILLS WELL AGAIN. 290 BBLS 1%KCL, 38 BBLS CRUDE. PERFORATE INTERVAL: 11206 - 11231 FT 6 SPF 3.375" PJ3406. ~"*"CONTINUE ON 28-APRIL-2009*** 4/27/20093T/1/0=1100/440/0 Assist E-line, Load & Kill (Profile Modification) Pumped 3 bbls meth, 290 bbls 1 %KCI and 38 bbls crude down Tbg. FWHP's=300/700/0. E-line in control of well upon departure. 4/27/2009. *"`Continued from 4/26/09 WSR*"* Assist E-line, Load Well (Profile Mod) Continued pumping down Tbg with 1 %KCI to load well. Pumped 103 bbls (303) total 1 %KCI and 40 bbls crude. Swab closed, Wing closed, SSV open, Master open, annulus valves open to gauges. Operator notified. _E-line ready to RU on_well. FW_HP's=0/660/0. 4/28/2009 ***REPORT CONTINUED FROM 27 APRIL 2009*"'" jTROUBLESHOOTING CONTINUED. ATTEMPT TO PERFORATE 'SECOND INTERVAL WITHOUT TRACTOR. TOOLSTRING SAT DOWN AT 11062', UNABLE TO REACH ZONES WITHOUT WITH 3 3/8" PJ 3406 HSD GUN. POOH WITH GUN. SURFACE 'CHECK INDICATED GUN FIRED. *""JOB IN PROGRESS AND CONTINUED ON 29 APRIL 2009 WSR*"* ~.~__~.__w.~_._-__-__ _...-.... .~~_.. ~ 4/29/2009 60/01 bbl /410/10. Temp = SI. T FL (E-Line call in). No AL. T FL @ """SLB on location and in control of wellhead valves*** I 1~ J 4/29/2009**"REPORT CONTINUED FROM 29 APRIL 2009""" ~ PERFORATE 11118- 11128 FT AND 11172'-11182' WITH 3 3/8" PJ ;3406 HSD GUN. 'FINAL T/I/O = 250/600/0 WELL LEFT SI. SWAB, WING, SSV CLOSED. MASTER OPEN. ALL CASING GUAGES OPEN TO TREE. "'**JOB COMPLETE""" FLUIDS PUMPED BBLS 870 1% KCL 503 1 % KCI 1373 Total OPERABLE: C-17B (PTD #2040940) Tubing Integrity Restored • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, June 06, 2008 12:11 PM '~~~ To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: C-17B (PTD #2040940) Tubing Integrity Restored Hi Jim, Page 1~ When the TIFL was initially conducted on C-17, the IA fluid level rose only 5$' and the IA pressure increased only 20 psi initially indicating a passing TIFL. Over the next couple of days the IA pressure was monitored an showed a continual increase. At this time it was determined to deem the original TIFL a fail and make notification to the Commission. It is our aim to notify the commission within the 3 days of identifying and confirming sustained casing pressure. Occasionally there are instances were bleeding the IA pressure clears solids from the gas lift valves allowing them to properly seat and restore integrity. The well was brought online on 4/18 with gas lift explaining the increase in IA pressure as seen on the TIO plot. Please let me know if you have any other questions. Thank you, Anna ~u6e, ~. E. Well Integrity Coordinator GPB Wells Graup Phone: {907} 659-5102 Pager: {907} 659-5100 x1154 ~~-NN~~ S~~ :~ ~ 2000 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, June 03, 2008 3:47 PM To: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: C-176 (PTD #2040940) Tubing Integrity Restored Thank you for the update. Looking at the pressure plot submitted to us 5/241008, !'m curious wh ~ oak so long to report SCP to the Commission, CO 492 says to no#ify the Commission within 3 day identifying sustained casing pressure exceeding 2000 psi, so perhaps the notification was delayed not reaching 2000 psi until late May (it is not possible to tail from the TIO plot submitted). There was ear failure point of the gas lift valve(s) in early to mid- April. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSU, AD ell Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thurs y, May 29, 2008 3:38 PM To: Reg ames B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GCi/3/FS3); GPB, GC3 OTL; GPB, GC3 Ipad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion 8/29/2008 OPERABLE: C-17B (PTD #2040940} Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, June 03, 2008 3:47 PM r~ ~I~j~ ~~ To: 'NSU, ADW Well Integrity Engineer' (~ Subject: RE: OPERABLE: C-17B (PTD #2040940) Tubing Integrity Restored Thank you for the update. Looking at the pressure plat submitted to us 5/24J008, B'm curious why it took so fang to report SCP to the Commission. CO 492 says to notify the Commission within 3 days of identifying sustained casing pressure exceeding 2000 psi, so perhaps the notification Was delayed by not reaching 2000 psi until late May (it is not possible to tell from the TIO plat submitted}. There was a clear failure paint of the gas lift valves} in early to mid- Aprii. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, May 29, 2008 3:38 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GCi/3/FS3); GPB, GC3 OTL; GPB, GC3 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: C-17B (PTD #2040940) Tubing Integrity Restored All, Well C-176 (PTD #2040940} passed an MITIA on 05/29/08 after dummying ofF the gas lift valves, thus praying tubing integrity has been restored. The well has been reclassified as Operable and may be brought on line When convenient for operations. Please call With any questions ar concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Saturday, May 24, 2008 8:22 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCi/3/FS3); GPB, GC3 OTL; GPB, GC3 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Dahlem, Jason E; Wellman, Taylor T; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION - C-17B (PTD #2040940) TxIA Communication 6/3/2008 OPERABLE: C-17B (PTD #2040940) Tubing Integrity Restored • Page 2 of 2 • All, Well C-17B (PTD #2040940) has been found to have TxIA communication evidenced by a failed TIFL on 05/20/08. After the TIFL, further monitoring was conducted and the TIOs reached 2140/2050/0 psi on 05/23/08. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward is as follows: 1. D: TIFL -FAILED 2. S: DGLVs 3. F: MITIA A wellbore schematic and TIO have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 6/3/2008 q,i1i~1 1,000 :;1112008 31~ ,?20~~c~ :,+15'200$ 91221200$ a+29i2008 415x'200$ ~,?121200$ ~11y%2008 X12612008 51:x,??00~; 5;~1111~'~~$~~ 5~7i,?~1$8 F?2~~20~ ~c TREE _ 41'8"'~am~' v^~,~tILHEAD F'1c:~ 0.C1iJ;'~,CR- C T ", K6 fv! t V - (~ 1 a' . _~__ f~F E1E:`v' _ . 3~i ~ I K~`f' :;JO'~1'I a • a~' !:;'+t k~it~- 229' ~.~.~ ~A~ 1h~2, , ~--s0, ID = 6.27s" i-- 2~'- ~~~:z ~-'~~~" ~~ ~P~ ~!€~PL~ -- - - 5-1t2' Tec ~;~ 1 ;c~--~9665'~- ! u0 i : tlf? I tt ~f? ~ _ 9056 ;_ { a r", ! .i~ ;(a , t !.. '- ~ x{3496'_-~ tRl•1f -.: ~ ]{~N ~,y UFVNVW R 4 REF t "JG. '.'.'-' '_''JD QN JtSLY 2CHi~'{ `fete: '~ ' 'r tG }'r vdu%tt:x, C:~E3 i er h~4t ,~'-_ ~tl perE t-1at~ ~r~ s~~- ~~ X71- ~ir~~~~:u~,l_- -~- - ~aF;rs ~~,,, ~ t t :~'~ - ~ ~ ~1 s :~ u ; ,, ~ro1t ~ I'8" 4 1180 - ~ 1750 i~ f??~ 18'04 ?'e" 4 117if1- 118 5 () Ck i ~ , 31(}4 ! ~~~ 4 121110 - 12045 €a o ~ ~ a~t '~ l!8" i 4 12390 ~ '12450 0 0l 'i ~,t04 2-it$" 4 12Q65 - 'P 275 £) 07115?C4 ?'" t_htR, 29 #, l-80, .0379 trpf, tD mm 6.184„ 2-7f8" LNR, 6.16f1, 1-80, .01058 bpf: ~1= 2.37'• 1 ' 1t~2, 1 a ems, 1~SC1, .01 s2 b¢f, ~ = s_s~ ~-{ ~ 27~i9' 92.1' j-9 6t8" K ?" BKP 1NR TC7P F'F;R 10064` 4-1l2" HES X NIP, ID = 3.813" ' 101,29 .._J~ E 1 ' F'E` a f gyn. k( 3 813- ^f~t159` ."x z 4 „' Uni<~ue C~~i ~~ .~__I It?'17`(' 7"X4-4,~ E~K(z S-;, F'~CR ~_, ~ ~I Q2~ 5' 4-1 ~' f-IF S :At+t tP, €El = :1,72"5"" 1{~:L:t"ta' ~# E ~,. °C~Pt" 1 >.frpt t:}_CR. [71 S bt~f I(J 3~9~8"4 '6f33i~'3' ? 1t+1P2, < . ~i C3~3 bpf, ic7 0 ~X~~ DATE REV sv ~ >.,.,,-~ T~ ~>.~V sv c ENTS Q5!10?8Q tPubUSt~laf. i~C)ft4PLL-Ttt!A[ C.-f '1i;J~ f'h~?':>\~` tv'f~LED(7UtKT~L (Ujl!15f)~) ~2tzzrs'; ~ 431561 j ~~TC1 BtCECRi~CK (C-17A) 07t2110~# DAVIKAK ~RJG SIDETRACK ~C-17B} Q4102148 Ri2ES F21rVt) vet E ~Oc~ ICjE3IPJC: i~1V Clt7 (04108I08} 4-1,'2" MI11ED QUIKDRILL {04116!08} f't3Tt3 PRlJDN41Et3.~Y ur~rr WE1L: G _I ~ B PFftr~~rr r`tn 'z%~aos~o R Fri t+l~. ~-029-20439-02 SEG 19, Tt 1 tat, ti1Al", 6' SNl & 1217'" 1fi~tEL ~ ExpttlraEion (Ataska~ SAF;1~Jz7TES: `•"4-112" CHRCiME (~""" 2'129' ~--f ~-; '>" H _.~ X iJi' aD= ~ £;13" 2330' ~ 5/8" Casing Patch w / ECP 2504' 7" BKRT3EBACK W!ES CEMENTER 2530' UStT 3/9!08 verified TOC 7" x 9 5!8" 2650' t,, r~~ci TO~C k~0huu~ 9-513" G ,. ' IFT ~ hdD12EC. ST fir'',! ND [3EV TYPE 1~'1`J LATt~ti F"J(~T f`N7f~ 4 _t ~~.. 9 KBG2 A )i )thr E; V\ tti ~ `; ~ , . 2 ;;^7a} E~? ^::` 4fi KBCa2 I"?tvff E3K ~~ i; .9 e ; ' 1 1f;0~c~ ~ ~?;?5 15 tCBf"a2 C~4'Il` SI< f3 4?3r°3'I14$ 923T 7" TIEBACK S1V Page 1 of 1 • Maunder, Thomas E (DOA) • From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, May 29, 2008 12:01 PM To: Maunder, Thomas E (DOA) Cc: Stewman, Sondra D Subject: FW: PBU C-17B (204-094) ~~~~~ JUN ~ 9 2008 Attachments: C-17B Well History.pdf Hi Tom, Here is the pre-rig summary for this well. It should have been included in the 10-404... apologies. :-) Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, May 25, 2008 4:21 PM To: Hubble, Terrie L Subject: PBU c-17B (204-094) Terrie, I am reviewing the 404 for the work completed on this well in March. Do you have the pre-rig work to set the BP and cut the tubing? Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 5/29/2008 STATE OF ALASKA ~~s~~ MAY 1 6 2008 `~. A~ OIL AND GAS CONSERVATION COM~SION ,y, i , ,~ REPORT OF SUNDRY WELL OPERATIONS=as~a GII ~` Gas Cons. Commission Anchorage 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Per it To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~ 204-094 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20439-02-00 7. KB Elevation (ft): \ 61 7' 9. Well Name and Number: ~ . PBU C-176 8. Property Designation: 10. Field Pool(s): ~ ~ ADL 028304 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12770 ~ feet true vertical 8944 ~ feet Plugs (measured) None Effective depth: measured 12682 feet Junk (measured) 12570' true vertical 8946 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2662' 13-3/8" 2662' 2662' 5380 2670 Intermediate 10498' 9-5/8" 9418' 7459' 6870 4760 Production 10348' 7" 10373' 8329' 7240 5410 Liner Liner 2547' 4-1/2" 10222' - 12769' 8183' - 8944' 8430 7500 Perforation Depth MD {ft): 11300' - 12675' Perforation Depth TVD (ft): 8987' - 8946' 4-1/2", 12.6# 13Cr80 10228' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packers 10095' & 10171' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 10156'. Cut and Puil 7" Casing from 2443" and pull 9-5/8" casing from 2328'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 168 bbls 'G' (943 cu ft / 813 sx). Run 7" (26#, L-80) . Cement w/ 85 bbls 'G' (477 cu ft / 108 sx). Clean out and run new Chrome tubing. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Jovy Roach, 564-4352 307-381 Printed Name Sondra Stewman Title Drilling Technologist -- ~15~ Prepared By Name/Number nature Phone 564-41~i Date b j ' ~~ "'~~Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 < ~j Submit Original Only,~ / ~G~NAL TREE _ • 4118" Cameron Vv~.1LHEA D = AGTUAT4~R- FMC. GTiS K. ELEV = 62.15` -~- BF. ELE1f = KOP = _~ tax Angle = 34 3` 3304' 95 ~ 12487 Datum MD = 10910` Datum ND ~ 8840` SS 9-518" DV IBC 13-3!$" CSC, 72~t, L~BQ, ID =12.347' I z2~s• 1 [7"' SCAB LNR, 26#, L-84, ID = 6.278" I M~n~murn 113 = 3.725" ~ 10295' ~-~{~~' HES ~~ N~PP'LE C-17B 7" TIEBACK SLV 9-5/8" X T' BKR LNR TOP PKR 10064' -14-1/2" HES X NIP, ID = 3.813" MILLOUT W+1DOW 9418` - 9434' CIBP --~ 946' 5-112" TBG, 17# L 8{3 9666' 7" 13(}7 LNR HGR •-956 ~--- 9-518" GSG, 47#1, L-84, ID = 8.681'• - '10496 PERFORATION SUMMARY REF LOG. MWD / LWD t3N JULY 2444 ANGLE AT TOP PERF: 89 ~ 11344' Note: Refer to Production DB for historical pert data SSE SPF INTERVAL C)pnf5gz DATE 2-718" 4 11304 - 11515 G p711 f3/44 2-',r'8" 4 11684 - 11754 O 47~18i44 2-7(8" 4 11770 - 11875 ~? 47(18144 2-718" 4 12(310 - 1 2045 Cl 07f18l44 2-718" 4 1239Q - 12454 O 47f18144 2-718'" 4 12465 - 12675 O 07f18144 ~7" LNR, 29 #, L}84, .(3371 bpf, iD = fi.184" ~-~ 1'1704•' 2-718" LNR,:. 6.16#, L-80, .0058 bpf, [D = 2.37" '12760° 4-112" LNR, 12.:6#, L-80, .t}152 bpf, ID = s . Rx~~-112'" eHROME•x 21 Z9, ~- 2330' -j4-1 /2" NES X NIP ID 3.813" 9 5/8" Casing Patch w/ ECP 2504' 7" BKR TIEBACK W/ES CEMENTER 2530' USIT 3/9/08 verified TOC 7" x 9 5/8" 2650' U81T 7!5144 verified TOG behsnd 9-518" GA S LIFT MA NDRLS ST MD TVD DEV TYPE 1/LV LATCH P(7RT DATE 4 3266... 3263 9 KBG2 Dt7ME BK 16 04f08/48' 3 6962 5859 53 KBG2 50 BK 20 04f48/0$' 2 83711 67A2 46 KBG2 DMY' BK 4 43/31/08' 1 1002$ 7995 15 KBG2 t)AAl` BK 0 03131/081 DATE...... .. REV 6Y CONir~tENTS_ DATE REV BY COruWtFl~TS 05114180 OF~GiNAL COhAPLETIf3N 44126148 RNVSV MILLED QUlKDRILL (44115J48j Q2J22185 f21N+J 03/15198 CTD SIDETRACK (C-17Aj 07/21104 DAV/KA R1G SIDEI'RAGK (G-17B} 04/02!88 N2ES RWfl 44115108' K5BIPJC GLV CfO (44108148} 10095• ~X 4-1 /2 BKR S-3 PKF2 10129' 4112" NES X NiR, (t] 3.$13" 10159' 7° x 4112" unique os 10171' ~7" X 4-112"' OKR 3-3 i~CR '10'[94' 4-1 f2" HES X N[P,_ID = 3.81.3" 10215' _ 4-1/2" HES XN NIR, ~1= 9.725'" 1022$ 4-1 f2" TBG, 12.6#, 13-GR .4152 bpf, 1D = 3.958" 10228. -~"-~,2,. yuL1=~, ID = a saa"~ 10229' 7" X 5" 8KR L~1R'TOP PKRR~ 10373' 7" LNR, 26#, L-84, .03$•••3 bpf, ID = 5.276,• 12570' -i4-1/2" MILLED QUIKDRILI (04/15/08) 12682' PBTD FRUDHOE BAY tlN1T WELL: G176 PERMIT No: ~`204094fl A P( N4: 50-429-20439-42 SEC 19, 711 N, R14E, 6' SNL & 1217" WE1.. BP Fxpldratian {Alaska) • • C-17B Well History (Pre RW4} pats sutYtrt~a~y 12/14/2007 WELL S/1 ON ARRIVAL. DRIFTED W/ 3.70" CENT & S-BAILER TO i 1,202' SLM, STOPPED DUE TO DEVIATION. RAN 3.66 CENT & PETREDAT GAUGES AS PER PROGRAM, RECEIVED GOOD DATA. WELL LEF S UT IN. 12/22/2007 TlIA/OA/OOA= SSV/640IO/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 1000 psi io 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ i5 minutes, 5000130 minutes. Bleed void tv 0 psi, RD test equipment. Cycle and torque LDS "ET style" all functioned no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute #est, 34001 15 minutes, 3400130 minutes. Bleed IC void to 0 psi, RD test equipment. Cycle and torque LDS "Standard style" no bent pins, re-installed Alemite caps. 12/25/2007 T/I/0=22501500/0/0 Load & Kill TBG, M1T TBG to 3000 psi. (Pre RWO} Pumped 5 bbls 60/40 meth followed by 230 bbls crude down TBG fvr E-Line. Tested Quikdrill plug to 3000 psi w. 11.5 bbis Crude. TBG lost 104 psi in i5 min and 40 psi in second 15 min for a Iota( 140 psi loss over 30 min. PASS• Bted TBGP to i 400 psi. Bleed gas off of €A. 12/25!2007 INITIAL WHP T/I/O = 0/0/0. SET BAKER QUICK DRILL COMPOSITE FRAC PLUG 1N 4-i/2" TUBINCa AT 10180' (MID ELEMENT). SOP OF PLUG AT 10179.5'. LRS MIT-TUBING TO 2500 P IPA CURRENTL PERFORMING MIT-IA THEN CMIT-TxIA. 12/26/2007 MIT IA to 3000 psi "'PASS***/CMIT TxIA to 3000 psi *'*PASS*** {Pre RWO) Pressured up iA to 3000 psi w/7.6 bbls crude. IA lost 60 psi in 1st 15 min and 20 psi in 2nd i 5 min, for a total loss of 80 psi in 30 min. Pass, Equalize pressure between TBG & IA. Pressured up TBG & lA w/1.3 bbls crude. TBG lost 40 psi & IA lost 0 psi in 1st 15 min. TBG lost 40 psi & IA lost 0 psi i 2nd 15 min. TBG lost 20 psi & IA lost i0 psi in 30 min. Pass. Bled WHP's {IA & OA valves checked for position upon departure and tag hung) F4VP's=250/400/0!0 12/26/2007 LRS MIT, MtTIA, COMBO MITXIA TO 3000 PSI PASSED. JET CUT 4-1/2" TUBING AT 10152' W! SLB 3.65" POWER CUTTER. WELL SHUT IN AND HANDED OVER TO DSO. 12/28/2007 T/I/0= 300120010!0. Circ Out (PRE RWO) Pumped 5 bbls meth, 523 bbls 1 %KCL, and 80 bbls heated diesel into ih< TBG. Take lA returns through a loop to the ffowline. U-Tube the Tx IA. Freeze protect the IA loop with 3 bbls mech. 12!29/2007 Circ Out (RWO prep) Freeze protected the fiowline with the WOA recipe. Line runs ail the way to GC3 so pumped 8 bbls neat and 523 bbls of crude. Bled back for final WHP = 0/0/OJO. Annulus casing valves are open to gauges. 12/30/2007 T/I/0=0/0/VAC. SI. Monitor WHPs (eval for ceikar liner). Well is centered to the right of the cellar 30" from the wall. It is 32" to the top of the flutes and another 10" to the cellar gravel. There is a little snow that is being melted by a heater. 30" is the closest wall. 12/31/2007 T/I/O/00=VaclVac/Vac/Vac. Temp=S1. lnstali ce(tar containment & assist FB (w/CMIT-TxIA & MITOA). stalled cellar containment below flutes. Staged Vac truck to evacuate possible surface release. Maintained an open OOAP bleed during CMIT-TxIA & MITOA. Ito surface activity noted during M1T's. Final T/UO/OO=01010/0. 12/3t/2007 Tll/O/OOA=p/0/O/0 temp=s/i CMIT TxIA 3500 psi PASSED; MIT OA 2000 psi PASSED {RWO} Pump 4.8 bbls diesel down ibg to pressure up TxIA to 3500 psi. T11A Lost 20/40 psi 1st 15 min, 0/0 2nd i 5 min. Pumped 1.8 obis crude down OA to reach 2000 psi. OAP loss 100 psi 1st 15 min, 0 psi 2nd i5 min, I°WHP's=01010/0 Casing vahres open io gauges & tagged w! MIT info. Pad Op notified upon departure. 1/1/2008 T=O. Set 4-1/16" CIW "H" BPV. {Pre 2-ES . Set 4-1/16" CIW "H" BPV thru tree with 1 - 2' ext ~ 102". No problems. C~'U'~' 3/3/2008 T/t1O= BPV/ 4 / 0 Temp=S/I MtT IA PASSED to 3000 psi {RWO} Pressured to to 3000 psi with 4.5 bbls of diesel. IA lost i 0 psi in the 1st 15 min and 10 psi in the 2nd 15 min for a total foss of 20 psi in 30 min Pest (2nd test) Bled IA tc 0 psi. 3!4!2008 MIT OA (PASSED} to 2000 psi (RWO) Pressured OA to 2000 psi with one 1 bbl crude. OA lost 60 psi in the 1st i 5 rnin and 20 psi in the 2n 1 min for a total lass of 80 psi in 30 rnin test. Bled OA to 0 psi {0.7 obis) FWHPs = BPV/aio. 3/6/2008 Pulled 4" CIW BPV through tree,tagged ~ 102". • • BP EXPLORATION Page 1 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABORS 2ES Rig Number: 2ES i Date ~ From - To Hours I Task Code NPT Phase Description of Operations 3/5/2008 00:00 - 02:30 2.501 RIGD P PRE Rig Down and prepare pits for move. 02:30 - 04:00 1.50 RIGD P 04:00 - 07:00 3.00 RIGD P 07:00 - 08:30 1.50 MOB P 08:30 - 16:30 8.00 MOB P 16:30 - 00:00 7.50 RIGU P 3/6/2008 ~ 00:00 - 03:00 ~ 3.00 ~ WHSUR ~ P 03:00 - 03:30 0.50 WHSUR P 03:30 - 05:00 1.50 WHSUR P 05:00 - 06:00 1.00 WHSUR P 06:00 - 08:00 2.00 WHSUR P 08:00 - 11:30 I 3.501 WHSUR I P 11:30 - 13:30 I 2.00 I W HSUR I P 13:30 - 16:00 2.50 WHSUR P 16:00 - 19:00 3.00 BOPSU P 19:00 - 20:00 1.00 BOPSU P 20:00 - 00:00 4.00 BOPSU P 3/7/2008 100:00 - 12:00 I 12.001 BOPSUFi P -Unplug and install jeep -Prep cellar -Remove cuttings tank and bermings PRE Load pits, shop, and camp. -Begin move from P2-58 to C-Pad at 04:00 hrs. PRE PJSM. Bridle up and remove service loops and torque tube pins. -Remove derrick pins and lower cattle shute -Tie back service loops and hoses -Lay over derrick PRE Raise rig and move off P2-58. PRE PJSM. Move sub from P2 to C-Pad. PRE PJSM. Lay herculite then spot sub, pits, camp, and shop. -Raise derrick and cattle shute -Hook up service loops DECOMP Finish berming up and bridle down. Prepare cellar. Take on clean seawater in pits. DECOMP Hold Pre-spud meeting in Doghouse. DECOMP Ri U DSM and test lubricator to 500 psi. Pull BPV. Rig down DSM. DECOMP Install annulus valves and fittings on wellhead. DECOMP Test TxIA to 3500 si for 30 minutes -good test. -Test OA (7"x9-5/8") to 2000 psi for 30 m_ in -good test. DECOMP Rig up circulation lines to tree. -Displace diesel from tbg ~ 3 bpm, 350 psi. -Swap hoses and displace diesel from ann C~ 3 bpm, 150 psi. -Circulate wellbore with clean 90 deg seawater @ 6 bpm, 850 psi. -Blow down and rig down lines from tree. DECOMP Install TWC and test from above for 3500 psi for 5 min and from below to 1000 si for 10 min. -Rig down test equipment DECOMP PJSM. Nipple down tree and adapter flange. -Remove from cellar. DECOMP PJSM. Nipple up BOPE. DECOMP Chan a out to rams from 3-1/2"x6" variables to 4-1/2" x 7" variables. DECOMP Riq up BOPE testing equipment and 7" test joint. -Begin testing top rams and bag to 250 psi low. -Witness of test waived by AOGCC rep John Crisp. -Test witnessed by BPWSL Mark Staudinger and NTP Bruce Simonson. DECOMP Continue BOPE test with 7", 4-1/2", and 4" test joints. -Test rams to 3500 psi high / 250 psi low. -Test annular to 2500 psi high / 250 psi low. -Witness of test waived by AOGCC rep John Crisp. -Test witnessed by BPWSL Mark Staudinger and NTP Bruce Simonson -Choke valve #9 failed. Re-grease and tested -good. -Change out seal ring on choke cushion block and test -good. Printed: 4/11/2008 12:30:23 PM • BP EXPLORATION Page 2 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-176 Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours ~~ Task Code NPT Phase I'~ Description of Operations 3/7/2008 00:00 - 12:00 12.00 BOPSU P DECOMP -Blow down surface equipment. 12:00 - 12:30 0.50 BOPSU P DECOMP Rig down test equipment. 12:30 - 13:30 1.00 PULL P 13:30 - 15:00 1.50 PULL P 3/8/2008 15:00 - 16:00 ~ 1.00 ~ PULL ~ P 16:00 - 16:30 0.50 PULL P 16:30 - 17:30 1.00 PULL P 17:30 - 00:00 6.50 PULL P 00:00 - 10:00 10.00 PULL P 10:00 - 12:30 2.50 PULL P I ~~ 12:30 - 14:00 1.50 BOPSU P 14:00 - 16:30 2.50 CLEAN P 16:30 - 00:00 7.50 CLEAN P 3/9/2008 00:00 - 02:30 2.50 CLEAN P 02:30 - 03:00 I 0.501 CLEAN I P 03:00 - 04:00 1.00 CLEAN P 04:00 - 07:30 3.50 CLEAN P 07:30 - 09:00 1.50 CLEAN P 09:00 - 09:30 0.50 CLEAN P 09:30 - 11:30 2.00 EVAL P 11:30 - 14:00 2.50 EVAL P 14:00 - 17:00 3.00 EVAL P 17:00 - 20:00 3.00 PULL P -Clean and clear rig floor -Service blocks DECOMP Change out to long bails. DECOMP Install lubricator extension. Rig up DSM and test to 500 psi - good. -Pull TWC and ri down DSM lubricator and extension. DECOMP Make up landing joint and make up to hanger. -Back out LDS -Pull han er to ri floor - 125k to unseat. 120k Up Wt. DECOMP Break and lay down hanger and landing joint. DECOMP Rig up torque turn equipment, compensator, and handling equipment. DECOMP Lay down 4-1/2" 12.6# 13Cr-80 Vam Top Tubing from 10152' to 5276'. DECOMP Continue to lay down 4-1/2" 12.6# 13Cr-80 Vam Top Tubing from 5276'. Recovered 238 full jts, 3 space out pups, 4 GLM's, 2 X-nipples, and cut pup below bottom x-nipple. -Tubing cut was approx. 1 inch from collar -Clean cut DECOMP R/D compensator and tubing equipment. Change out bales and clean and clear floor. DECOMP R/U test equipment and install test plug -Test bottom pipe rams to 250 psi / 3500 psi. good test -Pull test plug and install wear ring -R/D test equipment DECOMP P/U Baker Tools and make up 4.5" tubing stub dress off / 7" sera er BHA to 322' DECOMP P/U Drill Pipe from 322' to 9004' -Fill pipe ~ 3127' / 6000' / 8726' DECOMP Continue to single in hole from 9004' to 10156' -Ta ed 4 1/2 tubin stub at 10156' -Up Wt. 175k /Down Wt. 137k /ROT Wt. 155k -Torque 6k C~3 8 rpm -250 gpm C~3 1045 psi -Lose 1 hour due to Daylight Savings Time. DECOMP Dress and swallow 4-1/2" tubing stub. -250 gpm @ 1200 psi -80 rpm -WOB 8k DECOMP Pump 40 bbl Hi-Vis sweep surface to surface -Cup of scale and very little metal shavings detected DECOMP Pump Dry Job, POH from 10156' to 322', racking back DP. DECOMP Stand back Drill Collars, lay down BHA. DECOMP Clean and Clear Rig Floor. DECOMP PJSM. Spot and rig up SLB Wireline Services and USIT logging tools. DECOMP RIH with USIT and log up from 5000' to surface in 7" casing. -Found TOC ~ 2530' DECOMP Rig down USIT tools and Make Up 3 Stand String Shot assembly. DECOMP RIH w/ String Shot, fire across connection ~ 2450'. -POH and Rig down SWS Printetl: 4/11/2008 12:30:'L3 PM .7 • BP EXPLORATION Page 3 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date I From - To Hours Task Code NPT Phase Description of Operations 3/9/2008 20:00 - 22:00 2.00 DHB P DECOMP Make up HES 7" RBP and RIH w/4" DP to 3219'. -Pick up 10' and set R P -To of RBP ~ 3201' element Q 3205' 22:00 - 22:30 0.50 DHB P DECOMP Rack back 1 stand and circulate ~ 6 bpm, 260 psi (due to U-tubing fluid) -Observe well -static -Blow down Top Drive 22:30 - 00:00 1.50 DHB P DECOMP Spot 50' (25 sacks) of 20/40 sand down DP on to of RBP. 3/10/2008 00:00 - 01:30 1.50 DHB P DECOMP Continue dumping sand on RBP -Allow to settle -RIH and tag Cud 3174' 01:30 - 02:30 1.00 DHB P DECOMP POH, lay down running tool 02:30 - 03:30 1.00 DHB P DECOMP Test casin to 3500 i an I -Bleed off and blow down 03:30 - 05:00 1.50 FISH P DECOMP Pick up Baker multi-string cutter and stabilizer -RIH to locate collar 05:00 - 05:30 0.50 FISH P DECOMP Located collar C~? 2463' -Pulled uo to 2443' and cut casino C~3 60 rpm, Max TO = 1200 tt-Ibs 05:30 - 06:30 1.00 FISH P DECOMP Close bag, line up 7" x 9-5/8" annulus to cuttings tank & displace out diesel/crude with hot seawater C~3 4 bpm, 250 psi. -Increase rate to 6 bpm, 420 psi until hot seawater returned. -Close O.A., open bag, and displace I.A. to hot seawater. 06:30 - 08:00 1.50 FISH P DECOMP POH, stand back DC's, and Lay Down BHA. -Clean and clear rig floor. 08:00 - 09:00 1.00 FISH P DECOMP PJSM. Pull mouse hole, pull wear ring, bleed void. -Split stack and tbg spool. -Stand back BOP stack. 09:00 - 10:30 1.50 FISH P DECOMP Pull tubing spool and primary 7" packoff and remove from cellar. 10:30 - 12:00 1.50 FISH P DECOMP PJSM. PU and MU spear, XO, & single -Spear casing and pull free Q 60k up wt. -Pull to collar and remove 12:00 - 14:00 2.00 FISH P DECOMP N/U BOP's and install secondary annulus valve on 7 X 9 5/8 spool 14:00 - 14:30 0.50 FISH P DECOMP Test BOP X Casing spool -250 psi low / 2000 psi high 14:30 - 15:00 0.50 FISH P DECOMP R/U 7" casing equipment 15:00 - 16:00 1.00 FISH P DECOMP Engage spear & pull 7" casing to floor from 2443' -UD spear -Cut joint 36.79' -C/O elevators -75k Up and Down wt. 16:00 - 19:30 3.50 FISH P DECOMP UD 7" casing from 2407' - 36.79' cut jt. -57 full jts. -22.80' cut jt. 19:30 - 21:00 1.50 FISH P DECOMP R/D 7" casing equipment -Clean and clear floor 21:00 - 22:00 1.00 BOPSU P DECOMP C/O to set of i e rams to 9 5/8" Printed: 4/11/2008 12:30:23 PM • • BP EXPLORATION Page 4 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2008 /11/2008 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 01:00 01:00 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 07:00 07:00 - 08:00 08:00 - 13:30 0.50 1.00 0.50 1.00 1.00 0.50 1.00 0.50 3.00 1.00 5.50 BOPSU BOPSU BOPSU CLEAN CLEAN CLEAN CLEAN CLEAN DHB DHB DHB P P P P P P P P P P P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP M/U 9 5/8" Test Jt. -Install test plug Test 9 5/8" rams -BOP X Casing spool flange -250 psi low / 3500 psi high Hydril 2500 psi Pull test plug -R/D test equipment PU jars and bumper sub. Make up 9-5/8" scraper BHA to 304'. RIH from 304' to 2440'. Pump Hi-Vis Sweep ~ 500 gpm, 1170 psi. POH to 304'. Break and Lay Down scraper BHA. -Clear and clean floor Make Up 9,-5/8" HES RBP and RIH to 2414'. Set RBP. Stand back 2 stands. Test RBP and casing to 2000 si for 30 minutes - OK. Pour 2200 Ibs of sand down drill pipe onto RBP. Let sand settle for 1 hour. Run in and tag top of sand at 2362'_. 13:30 - 15:00 1.50 DHB P DECOMP POOH laying down drill pipe. 15:00 - 15:30 0.50 DHB P DECOMP Lay down RBP running tool. 15:30 - 16:30 1.00 CASE P DECOMP Pick up and make up 9-5/8" casing cutter assembly to 102'. Change out handling equipment. 16:30 - 18:30 2.00 CASE P DECOMP RIH to 2249'. Hook up blower hose. Up and down weight 65k. Locate top collar at 2311'. Space out drill pipe. Locate bottom collar at 2350'. 18:30 - 19:30 1.00 CASE P DECOMP Displace well to 9.8 ppg brine at 210 gpm with 970 psi. 19:30 - 20:30 1.00 CASE P DECOMP PJSM. Cut 9-5/8" casing at 2326'. Rotate at 60 rpm, pump at 110 gpm with 300 psi. Finish cut. Close Hydril and open annulus to cuttings tank. Fluid not moving either way. Pressure up to 1150 psi and hold for 5 minutes. No fluid movement with pressure dropping to 900 psi. Pressure up to 1100 psi again and fluid starting to move. Shut down. Blow down top drive and rig up head pin. 20:30 - 00:00 3.50 CASE P DECOMP Pump remaining 9.8 ppg brine at 84 gpm with 1150 psi to start then dropping to 250 psi. Thick arctic pac back for first 30 bbls then water/diesel mixture for the rest of the um in rocess. Switch to Little Red and test lines to 2000 psi. Pump 140 bbls of 120 degree diesel at 2 bpm. Chase with 24 bbl soap pill. No more arctic pack back. Shut down and let soak for 1 hour. 3/12/2008 00:00 - 02:30 2.50 CASE P DECOMP Pump remaining soap pill followed by 60 bbls of 120 degree diesel. Pump a 30 bbl hi-vis sweep. Displace annulus with hot seawater. Shut in annulus, open Hydril and displace wellbore with hot seawater. 02:30 - 03:30 1.00 CASE P DECOMP Remove blower hose. Blow down. POOH to 102'. 03:30 - 04:00 0.50 CASE P DECOMP Break and LD cutter, stabilizer and XO's. 04:00 - 05:00 1.00 CASE P DECOMP Lay tools down beaver slide. PU casing equipment. 05:00 - 06:00 1.00 CASE P DECOMP PJSM. Rig up to pull 9-5/8" casing. MU spear on drill pipe single. 06:00 - 11:00 5.00 CASE P DECOMP Engage spear and back out lock down screws. Pull and work han er with 300k u .Will not ull free. Disengage and lay down spear. Drain stack. Make up packoff pulling tool. Pull packoff. Lay down tool. PU and re-engage spear. Pull 300k - no go. Release spear. Make up bull nose packoff on spear, stab Printed: 4/11/2008 12:30:23 PM • • BP EXPLORATION Page 5 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date 'From - To Hours Task Code NPT Phase Description of Operations 3/12/2008 06:00 - 11:00 5.00 CASE P DECOMP back in. Break circulation at 270 gpm with 200 psi increase to 450 gpm with 380 psi. Pull 300k to 350k still no go. Release and lay down spear assembly. Blow down top drive. Rig down casing equipment. 11:00 - 11:30 0.50 CASE P DECOMP Pick up and make up casing cutter assembly. 11:30 - 12:45 1.25 CASE P DECOMP RIH to 1223'. Hook up blower hose. Circulate at 185 gpm with 280 psi. Open cutters, locate collar at 1232'. 12:45 - 13:00 0.25 CASE P DECOMP PU to 1222' and cut 9-5/8" casing. 13:00 - 13:30 0.50 CASE P DECOMP POOH to 10'. 13:30 - 14:00 0.50 CASE P DECOMP Break out and lay down cutter assembly. 14:00 - 15:30 1.50 CASE P DECOMP Rig up false bowl. PU spear and engage casing. Pull hanger to rig floor with 75k u wei ht. Lay down spear and hanger. Change out handling equipment. 15:30 - 21:30 6.00 CASE P DECOMP La down 9-5/8" casin from 1222'. Steam and hammer each connection. Clear and clean floor. Lay down a total of 30 full joints and 1 cut joint at 27.98'. 21:30 - 23:00 1.50 CASE P DECOMP PU and MU spear assembly to 231'. Change out handling equipment. 23:00 - 23:30 0.50 CASE P DECOMP RIH to 1222'. Up weight 65k, down 68k. Engage 9-5/8" casing. 23:30 - 00:00 0.50 CASE P DECOMP Circulate at 340 gpm with 360 psi. Jar at 150k, pull to 225k. Attem t to ull casin free. 3/13/2008 00:00 - 02:00 2.00 CASE P DECOMP Continue to jar on casing. Jar up at 225k, pull at 325k. First 30 minutes no gain. Next 30 minutes gain 3" to 6" each jar, with a gain of 1' to 3' on several pulls.-Gain 37' total in first hour, then sto with no further ro ress over the next 1-1/2 hours. Release spear. Blow down top drive. 02:00 - 04:30 2.50 CASE P DECOMP Perform post jarring inspection of derrick and top drive. 04:30 - 05:30 1.00 CASE P DECOMP POOH. Lay down accelerator. Rack back drill collars. Lay down jar and spear. 05:30 - 06:30 1.00 CASE P DECOMP Make up casing cutter assembly. Chg out cutter blades. 06:30 - 08:30 2.00 CASE P DECOMP RIH and enter TOF at 1185' DPM. RIH to 2250' - no obstructions. Pull u to 1971'. 08:30 - 09:00 0.50 CASE P DECOMP Come up hole and tag coupling at 2008'. Pull un and cut casing at 2006'. 09:00 - 10:00 1.00 CASE P DECOMP POH to BHA. 10:00 - 11:00 1.00 CASE P DECOMP LD casing cutter assembly. MU spear and jar assembly. 11:00 - 12:00 1.00 CASE P DECOMP RIH and engage TOF with spear. 12:00 - 14:30 2.50 CASE P DECOMP Commence jarring initially at 150 klbs hookload and pulling to 200 klbs. 425 gpm/450 psi. Work up to 250 klbs hookload jarring and pulling up to 300 klbs. Pump pressure increased to 725 psi and pipe made -3' upward progress. Observed small feces of cement in returns. Continue jarring at 250 klbs pulling up to 325 klbs. No further progress but getting larger (1 x.5 x .5 inch) pieces of cement at shakers. Pump pressure came down to 575 psi. Shut down jarring operations. Rack back 1 stand. Blow down top drive. 14:30 - 16:30 2.00 CASE P DECOMP PJSM. Inspect derrick, top drive and draw works. Service top drive and adjust brakes. 16:30 - 17:00 0.50 CASE P DECOMP PJSM. POOH to 231'. 17:00 - 17:30 0.50 CASE P DECOMP Change out handling equipment. POOH and lay down spear BHA. 17:30 - 18:30 1.00 CASE P DECOMP PU and MU 9-5/8" cutter BHA. 18:30 - 19:00 0.50 CASE P DECOMP RIH to 1550'. Up and down weight 50k. Printed: 4/11/2008 12:30:23 PM BP EXPLORATION Page 6 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code' NPT Phase Description of Operations 3/13/2008 19:00 - 19:30 0.50 CASE P DECOMP Locate collar at 1586'. Pull up 3' and cut 9-5/8" casing at 1583'. Pump at 190 gpm with 400 psi. Rotate at 60 rpm. 19:30 - 20:00 0.50 CASE P DECOMP POOH to cutter assembly. 20:00 - 20:30 0.50 CASE P DECOMP Service break and lay down cutter assembly. 20:30 - 21:30 1.00 CASE P DECOMP PJSM. Change out intensifier. Make up spear BHA to 231'. Change out handling equipment. 21:30 - 22:00 0.50 CASE P DECOMP RIH to 1187'. Up and down weight 55k. 22:00 - 23:00 1.00 CASE P DECOMP Engage 9-5/8" casing with spear. Pull up weight to 70k. Fish ree. POOH to 231'. 23:00 - 23:30 0.50 CASE P DECOMP POOH and lay down BHA to 9-5/8" casing fish. 23:30 - 00:00 0.50 CASE P DECOMP Rig up false bowl. Lay down jars and bumper sub. Rig up 9-5/8" casing equipment. 3/14/2008 00:00 - 04:00 4.00 CASE P DECOMP POH laying down 9 5/8" casing from cut at 1583'. Recovered 9 'ts + cut 'oint at 34.55'. 04:00 - 04:45 0.75 CASE P DECOMP PU & MU spear assembly with bumper sub, jars and accelerator. 04:45 - 05:15 0.50 CASE P DECOMP .RIH and en a e s ear in TOF at 1583' - OK. 05:15 - 07:00 1.75 CASE P DECOMP Commence jarring on 9 5/8"casing. Have made -1.5' progress as of report time. Pump pressure is staying constant but seeing pieces of cement at shakers. Release spear. Rack back 1 stand of drill pipe. Blow down top drive. 07:00 - 09:30 2.50 CASE P DECOMP PJSM. Perform derrick, top drive and draworks inspection. 09:30 - 10:00 0.50 CASE N SFAL DECOMP Trouble shoot and tighten leaking solenoid valve on top drive. 10:00 - 11:00 1.00 CASE P DECOMP POOH to 323'. Change out handling equipment. 11:00 - 11:30 0.50 CASE P DECOMP POOH and lay down spear assembly. 11:30 - 12:00 0.50 CASE P DECOMP Pick up and.make up cutter assembly. 12:00 - 13:00 1.00 CASE P DECOMP RIH to 1691'. Hook up blower hose. Run in to 1770'. MU top drive. 13:00 - 14:00 1.00 CASE P DECOMP Circulate at 170 gpm with 250 psi. Locate collar at 1775'. Pick up 2' and make cut at 1773'. Rack back 1 stand. Blow down top drive. Remove blower hose. 14:00 - 14:30 0.50 CASE P DECOMP Service top drive. 14:30 - 16:00 1.50 CASE P DECOMP PJSM. Cut and slip 96' of drilling line. Inspect brakes and chain. Lube Elmago Splines and bearings. Pump up weight indicator load cell. 16:00 - 16:30 0.50 CASE P DECOMP POOH to cutter assembly. 16:30 - 17:00 0.50 CASE P DECOMP Lay down casing cutter. Clear and clean floor. 17:00 - 00:00 7.00 BOPSU P DECOMP .PJSM. Install test plug. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi ow, 2500 psi ig as per Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. 3/15/2008 00:00 - 02:00 2.00 BOPSU P DECOMP PJSM. Finish testing BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. 02:00 - 03:00 1.00 CASE P DECOMP Clear and clean floor. 03:00 - 04:30 1.50 CASE P DECOMP PU and MU spear assembly to 323'. 04:30 - 05:00 0.50 CASE P DECOMP RIH to 1530'. Up weight 70k, down 75k. 05:00 - 05:15 0.25 CASE P DECOMP En a e s ear. Pull up free with 76k. 05:15 - 06:30 1.25 CASE P DECOMP POOH to BHA at 323'. Change out an ing equipment. 06:30 - 07:00 0.50 CASE P DECOMP PJSM. POOH and lay down spear assembly. 07:00 - 08:30 1.50 CASE P DECOMP PJSM. Rig up casing handling equipment. Pull 9-5/8" casing. Printed: 4/11/2008 12:30:23 PM • B'P EXPLORATION Page 7 of 20 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To C-17B C-17B WORKOVER NABOBS ALASKA DRILLING I NABOBS 2ES Hours ~ Task Code NPT Spud Date: 3/6/2008 Start: 3/5/2008 End: 4/2/2008 Rig Release: 4/2/2008 Rig Number: 2ES Phase Description of Operations 3/15/2008 107:00 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 11:00 11:00 - 12:00 1.501 CASE P 1.00 CASE P 0.50 CASE P 1.00 CASE P 1.00 CASE P 12:00 - 12:45 0.75 CASE P 12:45 - 13:00 0.25 CASE P 13:00 - 13:30 0.50 CASE P 13:30 - 14:30 1.00 CASE P 14:30 - 15:15 0.75 CASE P 15:15 - 15:30 0.25 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 18:00 1.50 CASE P 18:00 - 19:00 1.00 CASE P 19:00 - 19:30 0.50 CASE P 19:30 - 21:30 2.00 CASE P 21:30 - 23:00 ~ 1.501 CASE ~ P 23:00 - 23:30 I 0.501 CASE I P 23:30 - 00:00 0.50 CASE P 3/16/2008 00:00 - 02:00 2.00 CASE P 02:00 - 03:30 ~ 1.501 CASE ~ P 03:30 - 04:00 0.50 CASE P 04:00 - 05:30 1.50 CASE P DECOMP Recover 4 full joints and 2 cut'oints at 2.38' and 37.88'. Rig down casing equipment. DECOMP Clear and clean floor. DECOMP PJSM. PU and RIH with cutter assembly. DECOMP PJSM. RIH to 1691'. Hook up blower hose. Run in to 1890'. Make up top drive. Up, down and RT weight 60k. Locate collar at 1888', pull up 2' to 1886'. DECOMP Pump at 230 gpm with 860 psi. Rotate at 70 rpm with 2-7k torque and make cut in 9-5/8" casing at 1886'. DECOMP POOH to cutter BHA. DECOMP Lay down cutter assembly. DECOMP Perform rig evacuation drill with safety standdown. Hold PJSM. DECOMP Pick up spear assembly. Change out grapples. PU drill collars and intensifier to 323'. DECOMP RIH to 1784'. Up weight 65k, down 70k. DECOMP Engage fish at 1784. Pick up free with 20k drag. DECOMP POOH to 323'. DECOMP POOH and lay down spear assembly. DECOMP PJSM. Rig up casing equipment. Release and LD spear. Pull and lay down 9-5/8" casing. Recover 2 full joints and cut joint of 25'. Rig down casing equipment. DECOMP PU and MU spear assem y o 23'. DECOMP RIH and to 4' above fish at 1882'. DECOMP Attempt to engage fish with spear. Rotate at 15 rpm while pumping at 130 gpm. Packing off intermittantly. Torque to 7k. Break through tight spots from 1882' to no go at 1897., Engage fish with spear. Jar at 250k, pull at 325k making head way each jar run. Pump at 130 gpm with 240 psi, packing off to 1300 psi and injecting fluid with no returns. Shut pumps off and regain returns at 400 psi. Sometimes loosing returns while pumping sometimes not during jarring operations. Pull pipe to connection at 1816', rack back stand. DECOMP Shut down and inspect loose electrical box on top drive. Electrician went over box, tighten 1 connection. Everything checked out. Pump at 130 gpm with 60 psi with no packing off during inspection. DECOMP Continue jarring operation. Pulling tight. Pull 2 stands without setting off jars, last stand without pumps. Pull to 1536' with 125k up. DECOMP PJSM. Begin post jarring inspection of top drive and derrick. DECOMP PJSM. Perform post jarring inspection of top drive, derrick and draworks. DECOMP PJSM. POOH to 323'. Change out handling equipment. Pulling 40-60k over all the way out. DECOMP PJSM. Stand back collars. LD spear assembly to fish. DECOMP PJSM. Rig up casing equipment. Set false bowl. Release grapple. Try to pull 9-5/8" casing. Overpulls of 100k to 150k. Shut down hold PJSM/HACL. Continue to pull first joint of 9-5/8" casing. Dragging and hanging up with pulls of 200k to 250k and no down movement. Pipe came free on second joint. Pull 2 full joints and 2 cut sections of 1.2' and 36.90'. Lower ram cavity full of large pieces of cement off pipe. Funtion Inds and upper rams an c ear more cemen m o we ore. Cement Printed: 4/11/2()08 12:30:23 F'M C • BP EXPLORATION Page 8 of 20 Operations Summary Report Legal Well Name: C-176 Common Well Name: C-176 Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ~ Hours I Task I!, Code i NPT ' Phase Description of Operations 3/16/2008 04:00 - 05:30 1.50 CASE P DECOMP hanging up on lower ram cavity. 05:30 - 06:30 1.00 CASE P DECOMP Rig down casing equipment. Clear and clean floor. 06:30 - 08:00 1.50 CASE P DECOMP Pick bit and scrapers up beaver slide. 08:00 - 09:00 1.00 CASE P DECOMP PJSM. Rig up Supersucker and remove small slabs of cement from wellhead. Close rams to break up larger slabs and push downhole. 09:00 - 10:30 1.50 CASE P DECOMP PJSM. Make up bit and scraper assembly to 305'. Change out handling equipment. 10:30 - 14:00 3.50 CASE P DECOMP RIH to 1987'. Hook up blower hose. Make up top drive. Circulate at 155 gpm with 300 psi. Rotate at 60 rpm with 2-4k torque. Up weight 85k, down and RT 75k. Wash and ream to 14:00 - 14:30 ~ 0.50 ~ CASE ~ P 14:30 - 15:00 0.50 CASE P 15:00 - 17:30 2.50 CASE P 17:30 - 19:30 2.00 CASE P 19:30 - 20:30 1.00 CASE P 20:30 - 22:00 1.50 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 00:00 1.00 CASE P 3/17/2008 100:00 - 01:00 I 1.001 CASE I P 01:00 - 04:00 3.00 CASE P 04:00 - 04:30 0.50 CASE P 04:30 - 05:00 0.50 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 07:00 1.50 CASE P 07:00 - 07:30 ~ 0.50 ~ CASE ~ P 07:30 - 08:30 1.00 CASE P 08:30 - 09:00 0.50 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 10:30 1.00 CASE P 10:30 - 11:30 1.00 CASE P 11:30 - 16:00 4.50 CASE P 16:00 - 17:00 1.00 CASE P 17:00 - 17:30 0.50 CASE P 17:30 - 21:00 3.50 CASE P DECOMP Pump hi-vis sweep surface to surface at 575 gpm with 1500 psi. DECOMP POOH to 305'. DECOMP Break and lay down scraper assembly. PU 8-1/2" bit for 9-5/8" casing clean out run. Make up and RIH to 301'. DECOMP RIH to 2006'. Hook up blower hose. Break circulation at 130 gpm with 90 psi. ~lyash from 2006' to 2270'. Tag up at 2270', rotate at 20 rpm with 3k torque to 2288'. Blow down top drive. Disconnect blower hose. DECOMP POOH to 301'. Drag of 180k at 2190' to 2090'. DECOMP Break and lay down clean out assembly. PU and MU spear assembly to 323'. DECOMP RIH to 2006'. DECOMP Engage fish at 2006'. Jar and pull to 1966'. Jar at 250k, pull to 325k. Attempt to circulate but packing off. Continue jarring with no movement. DECOMP PJSM. Continue to jar with no upward movement. Jarring at 250k, pulling to 325k. Release spear. Rack 1 stands back. DECOMP PJSM. Inspect derrick, top drive and drawworks. DECOMP POOH to 323'. DECOMP PJSM. Lay down spear assembly. DECOMP PJSM. Pick up cutter assembly. Redress cutter. DECOMP RIH to 1877'. Hook up blower hose. Run in to 2090' and MU top drive. Establish circulation at 210 gpm with 250 psi. Slack off. Locate collar at 2118'. PU to 2116'. Up weight 60k down 65k. DECOMP Pump at 220 gpm with 260 psi. Rotate at 60 rpm with 1-3k torque. Cut casing at 2116'. Rig down blower hose. Blow down top drive. DECOMP PJSM. POOH to cutter assembly. DECOMP PJSM. Lay down cutter assembly. Clear and clean floor. DECOMP PJSM. PU and MU spear assembly to 231'. Change out handling equipment. DECOMP RIH to 1966'. Up weight 70k. Engage grapple. Attempt circulation. Packing off. Break out top drive and blow down. DECOMP PJSM. Jar to 275k, pull to 325k. No movement. DECOMP Release spear. Rack back one stand. Perform inspection on top drive, draworks and derrick. DECOMP POOH to spear assembly at 231'. DECOMP PJSM. Lay down spear assembly. DECOMP Repair leaks found during post jarring inspection. Replace worn Printed: 4/11/2008 12:30:23 PM • • BP EXPLORATION Page 9 of 20 ~ Legal Well Name: C-176 Operations Summary Report Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date I' From - To ,Hours Task Code'. NPT I Phase Description of Operations 3/17/2008 17:30 - 21:00 3.50 CASE P DECOMP bolts on grabber foot. Tighten electrical conduit nuts. 21:00 - 21:30 0.50 CASE P DECOMP Make up cutter assembly. 21:30 - 22:30 1.00 CASE P DECOMP RIH to 1877'. Hook up blower hose. 22:30 - 23:30 1.00 CASE P DECOMP RIH to 2175'. Break circulation at 210 gpm with 230 psi. Locate collars at 2196' and 2156'. Cut casing at 2193'. Pull 2 stands. Locate collar at 2034'. Cut casing again at 2032'. Both cuts at 300 gpm with 500-650 psi. Rotate at 50-100 rpm with 1-3k torque. TOD of fish at 1963'. Cut at Cut at fish at 2251'. 58' on bottom 77' next up hole 84' next up hole 68' section at top 23:30 - 00:00 0.50 CASE P DECOMP Blow down top drive. Remove blower hose. POOH to 1036'. 3/18/2008 00:00 - 01:00 1.00 CASE P DECOMP PJSM. POOH to cutter assembly. 01:00 - 01:30 0.50 CASE P DECOMP PJSM. POOH and lay down cutter assembly. 01:30 - 03:00 1.50 CASE P DECOMP PJSM. Pick washpipe tools up beaver slide. Change out handling equipment. Rig up to run washpipe. 03:00 - 06:00 3.00 CASE P DECOMP PJSM. Make up and RIH with 11-3/4" washpipe assembly to 395'. 06:00 - 07:00 1.00 CASE P DECOMP PJSM. RIH to 1944'. Lay down drill pipe single. Hook up blower hose. RiH to top of fish at 1963'. Up, down and RT weight 80k. 07:00 - 16:00 9.00 CASE P DECOMP Wash over 9-5/8" casin to 2030'. Pump at 255 gpm with 200 psi. Rotate at 80 to 90 rpm with 4-12k torque. WOB 3-5k. Cement and metal over shakers. Continue to wash. Pump sweep surface to surface at 480 gpm with 700 psi. 16:00 - 17:00 1.00 CASE P DECOMP POOH to 395'. Blow down top drive .Remove blower hose. 17:00 - 22:30 5.50 CASE P DECOMP Stand back drill collars. Rig up to handle washpipe. Lay down jars and bumper sub assembly. Empty boot baskets, full of cement and metal shavings. Break and lay down washpipe assembly. Rig down handling equipment. Clear and clean floor. Heaw wear on washoioe with call rings at several places. The mule shoe was cracked in several places with belled flutes. The box on the 2nd joint also was belled with some metal shaved off. 22:30 - 23:30 1.00 CASE P DECOMP PJSM. PU and MU spear assembly to 232'. 23:30 - 00:00 0.50 CASE P DECOMP RIH with spear assembly to 600'. 3/19/2008 00:00 - 00:30 0.50 CASE P DECOMP PJSM. of fish at 1963'. MU top drive. _. 00:30 - 00:45 0.25 CASE P DECOMP En age fish. Jar up 1 time at 200k. Pipe free. 00:45 - 01:15 0.50 CASE P DECOMP POOH to spear assem y at 3 01:15 - 02:00 0.75 CASE P DECOMP PJSM. Release and lay down spear. Change out handling equipment. Rig up to pull 9-5/8" casing. 02:00 - 03:00 1.00 CASE P DECOMP PJSM. LD 9-5/8" casing. LD 1 full joint and 2 cut joints at 1.25' and 38.13'. 03:00 - 04:00 1.00 CASE P DECOMP Change out handling equipment. Clear and clean floor. 04:00 - 05:00 1.00 CASE P DECOMP PJSM. PU and make up spear assembly to 323'. Printed: 4/11/2008 12:30:23 PM BP EXPLORATION Page 10 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours ' Task Code NPT Phase Description of Operations 3/19/2008 05:00 - 05:30 0.50 CASE P DECOMP RIH with s ear assembl to 2116'. Works ear into to of fish. 05:30 - 07:00 1.50 CASE P DECOMP Engage fish. Jar up one time ~ 270K. Pull and jar to 1900' with 07:00 - 08:00 08:00 - 10:00 10:00 - 10:30 10:30 - 11:00 11:00 - 13:30 3:30 - 14:30 1.00 2.00 0.50 0.50 2.50 .00 CASE CASE CASE CASE CASE ASE P P P P P P DECOMP DECOMP DECOMP DECOMP DECOMP ECOMP 150-250k pull. Fish came free, pulling at 80k. POOH to 231'. Change out handling equipment. PJSM. Lay down spear assembly to fish. Release grapple. Lay down spear. Clear floor and rig up casing equipment. Lay down 1 full joint of 9-5/8" casing and 2 cut joints at 1.35' and 37.30'. Inspect top drive. PJSM. PU and MU spear assembly to 231'. RIH to 2077', to cement. MU top drive. Establish circulation at 350 gpm with 300 psi. Rotate at 70 rpm with 1-3k torque. Wash and ream to 2112'. Increase pump rate to 460 gpm with 660 psi and rotation to 90 rpm with 3-4k torque. Wash and ream to 2119'. Pressure increasing as packoff entered top of fish. Pull back and pump hi-vis sweep at 585 gpm with 835 psi. Attempt to engage fish, no go. Last pick up had 10k extra. 14:30 - 15:30 1.00 CASE P DECOMP Blown down top drive. Remove blower hose. POOH to spear assembly. Overpull of 75k from 2090' to 1940' then dropping off to normal. 15:30 - 17:00 1.50 CASE P DECOMP Pull spear to floor, no fish. Found grapple on extention sub. Break and lay down spear assembly. 17:00 - 20:00 3.00 CASE N RREP DECOMP Engines went down. Fuel pump or motor seizure. Swap to secondary fuel pump. 20:00 - 21:00 1.00 CASE P DECOMP PJSM. PU and MU VAC'S tool assembly to 262'. Change out handling equipment. 21:00 - 22:00 1.00 CASE P DECOMP RIH to 2037'. Hook up blower hose. Up and down weight 75k. 22:00 - 23:00 1.00 CASE P DECOMP Break circulation at 340 gpm with 850 psi. Viscosified brine to 50+vis. Wash from 2037' to 2249'. No tag or drag. Very little material to surface. Circulate bottoms up at 550 gpm with 2200 psi. 23:00 - 00:00 1.00 CASE P DECOMP Shut down. Blow down top drive. Remove blower hose. POOH to 1007'. 3/20/2008 00:00 - 01:00 1.00 CASE P DECOMP PJSM. POOH to 262'. Change out handling equipment. 01:00 - 02:00 1.00 CASE P DECOMP PJSM. Lay down mill and VACS tool assembly. Recover 2-4 cups cement in VACS Tool. Replace Jars and bumper sub. 02:00 - 03:30 1.50 CASE P DECOMP PJSM. Lay VACS tools down beaver slide. PU tools for spear assembly. 03:30 - 05:00 1.50 CASE P DECOMP PJSM. Make up new spear assembly with new jars and bumper sub to 233'. 05:00 - 05:30 0.50 CASE P DECOMP RIH to 2037'. 05:30 - 05:45 0.25 CASE P DECOMP 0-175k. 05:45 - 07:00 1.25 CASE P DECOMP POOH with spear assembly and fish. Pulling with 50-125k overpull. Pulling tight at 1520' to 1444'. Jar 250k, pull 325k. Break free, POOH to 233'. 07:00 - 07:30 0.50 CASE P DECOMP PJSM. LD spear assembly to fish. Release grapple. Lay down. 07:30 - 08:30 1.00 CASE P DECOMP PJSM. RU casing equipment. Pull land lay down 1 full joint of 9-5/8" casin and 2 cut'oints at 1.36' and 38.65'. Rig down casing equipment. Clear and clean floor. 08:30 - 10:00 1.50 CASE P DECOMP PJSM. Make up spear assembly to 223'. Change out handling equipment. 10:00 - 12:00 2.00 CASE P DECOMP PJSM. RIH to 1488'. Tag up. Make up top drive. Attempt to wash down at 425 gpm. Packing off. Break out and blow down Printed: 4/11/2008 12:30:23 PM BP EXPLORATION Page 11 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To !Hours Task Code i 3/20/2008 10:00 - 12:00 ( 2.00 CASE P 12:00 - 16:00 4.00 CASE ~ P 16:00 - 17:00 I 1.001 CASE I P 17:00 - 20:30 I 3.501 CASE I P 20:30 - 21:00 0.50 CASE P 21:00 - 00:00 3.00 CASE P 3/21/2008 100:00 - 01:00 I 1.001 CASE I P 01:00 - 02:00 I 1.001 CASE I P 02:00 - 02:30 I 0.501 CASE I P 02:30 - 03:30 I 1.001 CASE I P Spud Date: 3/6/2008 Start: 3/5/2008 End: 4/2/2008 I Rig Release: 4/2/2008 Rig Number: 2ES i Phase ', Description of Operations DECOMP I top drive. Pull 175k up, appear to be pulling fish. Come free at 1364'. POOH to shear. No fish. DECOMP PJSM. LD spear assembly. PU and MU Junk Mill/String Mill/Scraper assembly to 278'. DECOMP RIH to 1398'. Hook up blower hose. RIH and ta4 up at 1459'. Up weight 65k, down 60k. DECOMP MU top drive. Wash and ream from 1459'. Pump at 330 gpm with 180 psi. Rotate at 20 rpm with 1 k torque. Experience pack off. Increase rpm to 80k. Ream through cement from 1459' to 1505'. Reaming with 3-5k torque at 5-10k WOB. High torque, stalling and packing off encountered. Continue milling to 1531'. Metal shavings in returns. Shut down pumps. Set down 35k, no movement. Shut down, blow down top drive and remove blower hose. DECOMP PJSM. POOH to 278'. DECOMP PJSM. Lay down mill clean out assembly. Ring wear on bottom of string mill indicating milling on top of 9-5/8" casing fish. Break and clean out junk baskets. Recover cement and metal. PU and MU spear assembly to 227'. DECOMP PJSM. RIH to 1441' with spear assembly. Make up top drive. Slack off and tag top of fish at 1531'. Slack off and engage fish. PU 85k ull free. Pull to 200k with 150k drag. DECOMP PJSM. POOH to 1161'. Drag dropped from 175k to 60k. Continue to POOH to 227'. Change out handling equipment. DECOMP PJSM. Lay down spear assembly to fish. Install false bowel. Release grapple. DECOMP PJSM. Rig up casing equipment. Pull 9-5/8" casing. Recover 1 full joint and 2 cut joints at .7' and 15.70'. Also recovere one 03:30 - 04:30 1.00 CASE P DECOMP Clear and clean floor. 04:30 - 05:15 0.75 CASE P DECOMP PJSM. PU and MU junk mill assembly to 278'. 05:15 - 07:30 2.25 CASE P DECOMP RIH with junk mill assembly to 1959'. Hook up blower hose. 07:30 - 14:00 6.50 CASE P DECOMP Pump at 300 gpm with 190 psi. Rotate at 60 rpm with 1-7k torque. Wash and ream to 2255'. Tag fill. Continue to ream to 2280'. Hard from 2280' to 2290'. Packing off at times. Pump sweep at 2324, pumping at 585 gpm with 950 psi. Continue to ream to 2363'. Bottom out on stub at 2326' with funk mill at 2363'. 14:00 - 15:00 1.00 CASE P DECOMP Circulate sweep at 590 gpm with 780 psi until clean as per Mud Engineer. Rack back stand. Blow down top drive. Remove blower hose. 15:00 - 15:30 0.50 CASE P DECOMP PJSM. POOH to 278'. 15:30 - 17:00 1.50 CASE P DECOMP PJSM. Lay down junk mill assembly. 17:00 - 18:30 1.50 CASE P DECOMP PJSM. Lay BHA tools down beaver slide. Pick washpipe tools and assembly up beaver slide. Change out handling equipment. 18:30 - 21:30 3.00 CASE P DECOMP PJSM. PU and MU washpipe assembly to 383'. Change out handling equipment. 21:30 - 22:30 1.00 CASE P DECOMP PJSM. RIH to 2251'. MU top drive. Hook up blower hose. RIH tag top of 9-5/8" stub at 2326'. Lay down drill pipe single. PU stand, MU top drive and fill pipe. Up and down weight 85k, RT 90k. 22:30 - 23:30 1.00 CASE P DECOMP Wash over 9-5/8" casing stub. at 250 gpm with 170 psi. Rotate Printed: 4/11/2008 12:30:23 PM I • BP EXPLORATION Page 12 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-176 Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 3/21/2008 22:30 - 23:30 1.00 CASE P DECOMP at 50 rpm with 2-4k torque. WOB 5-10k. Wash over collar at 2352' with no roblems. Continue to wash to 2366'. Pull up, slack off with no rotary - no problems. 23:30 - 00:00 0.50 CASE P DECOMP Pump hi-vis sweep at 245 gpm with 180 psi. Reciprocate and rotate. Pick up off stub then bring rate up to 540 gpm with 525 psi. No increase in cement cuttings to surface. 3/22/2008 00:00 - 01:00 1.00 CASE P DECOMP PJSM. Finish circulating sweep out of hole. No increase in cuttings to surface. Blow down top drive. Adjust brakes. Remove blower hose. 01:00 - 02:00 1.00 CASE P DECOMP POOH with wash i e assembl to 283'. 02:00 - 06:30 4.50 CASE P DECOMP PJSM. POOH and lay down washpipe BHA. Clean out boot baskets. Recover mostly cement with a handful) of small pieces of metal. Clear and clean floor. 06:30 - 08:00 1.50 CASE P DECOMP PJSM. MU and run in with dressoff assembly to 336'. Change out handling equipment. 08:00 - 09:00 1.00 CASE P DECOMP PJSM. RIH to 2298'. 09:00 - 09:30 0.50 CASE P DECOMP Wash and ream to 2326'. Polish to 2328' and milled 1' off stub. Up weight 85k, down SOk, RT 85k. Rotate at 60 rpm with 3-4k torque. 09:30 - 11:00 1.50 CASE P DECOMP Pump hi-vis sweep S-S at 525 gpm with 480 psi. Shut down, blow down top drive. Monitor well - OK. Remove blower hose. 11:00 - 12:00 1.00 CASE P DECOMP PJSM. POOH to 336'. Change out handling equipment. 12:00 - 13:00 1.00 CASE P DECOMP PJSM. POOH and lay down dressoff assembly. 13:00 - 15:00 2.00 CASE P DECOMP Lay tools down beaver slide. Clear and clean floor. PU cement and casing equipment. 15:00 - 22:00 7.00 BOPSU P DECOMP PJSM. PU test joint. MU TIW and dart to 4" test joint. Suck out stack. Run in test plug. Fill stack and check for leaks - OK. Test BOPE to 250 si low, 3500 psi high and Hydril to 250 psi low and 3500 psi high as per AOGCC. Test witness waived by Lou Grimaldi with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. Test 4" and 9-5/8" test joints. Bleed off and blow down. Pull test plug. 22:00 - 00:00 2.00 CASE P DECOMP PJSM. Clear and clean floor. Rig up to run 9-5/8" casing. Bring up pup joints. Rig up cellar for squeeze job. Change out bails. Rig up torque turn computer. 3/23/2008 00:00 - 01:30 1.50 CASE P DECOMP PJSM. Rig up to run 9-5/8", 47#, L-80, Hyd 563 casing. 01:30 - 07:00 5.50 CASE P DECOMP PJSM. Pick up and run in with casing patch, landing collar, ECP, ES Cementer and XO to Hyd 563. Bakerloc connections below ES Cementer and XO joint on top of cementer. Continue to RIH with 9-5/8" casing as per running order. 07:00 - 08:00 1.00 CASE P DECOMP At 2041' start to take 5-10k weight running in with no returns. Fluid flowing over top of casing. Shut down. Circulate bottoms up times two at 500 gpm with 210 psi. Cement and sand to surface. 08:00 - 10:30 2.50 CASE P DECOMP Continue to RIH with casing to 2326'. Up weight 170k, down 85k. Wash down to top of stub. Rotate over stub at 2326' to 2329'. Rotate at 20 rpm with 12k torque. Pick up to 250k and hold weight. Pressure up on 9-5/8" casing and casing patch to 500 psi for 5 minutes - OK. Bump up to 1000 psi for 15 minutes - OK. Continue to pressure up to 2000 psi and set ECP. Pressure bled off to 1850 psi, pressured back up to 2000 psi with 3 strokes, pressure held, set verified. Bleed off pressure. Pressure back u to 2800 si and o en ES Cementer. Keep Printed: 4/11/2008 12:30:23 PM ~~ • BP EXPLORATION Page 13 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-176 Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES .Date From - To Hours ~ Task Code NPT Phase Description of Operations ~_- - - 3/23/2008 08:00 - 10:30 2.50 - CASE P - DECOMP 260k up weight on 9-5/8". 10:30 - 12:00 1.50 CASE P DECOMP Circulate hot 120 degree seawater to warm up well prior to pumping cement. Pump at 430 gpm with 130 psi. 12:00 - 14:00 2.00 CASE P DECOMP PJSM. Break out top drive. Make up cement head. Rig up cementing equipment. Establish circulation at 420 gpm with 600 psi. Continue to pull 260k on casing string. 14:00 - 15:00 1.00 CASE N SFAL DECOMP Pump 5 bbls water. Attempt to pressure test lines. Cement head leaking at valves. Thighten and test again with no success. Go through valves again and test, passed. 15:00 - 17:00 2.00 CASE P DECOMP After 5 bbls water pumped and lines tested to 4000 psi, pump 15 bbl water spacer with red dye. Pump 168 bbls of 15.8 ppg Class G tail slurry at 5 bpm. Follow with 5 bbls of water to flush cement lines and kick out closing plug. Shut down and switch over to rig pumps. Displace with 163 bbls of seawater. Showing good lift around corner. Red dye to surface at 100 bbls. Shut down. Shut Hydril and divert returns to cuttings tank. Continue to pump at 2 bpm with cement to surface at 133 bbls away. Pinch back on annular valve to cuttings tank. Begin to see cements ueezin to formation at 800 si. Pressure started to drop off, pinch back more on annular valve and bring pressure up to 1890 psi. Again cement being squeezed away with pressure dropping to 1320 psi. With 15 bbls of cement squeezed away shut down for 20 minutes. Bring pumps back on line and attempt to squeeze more cement. No more cement squeezed away. Continue to pump, bumping plug with 163 bbls away. Pressure up to 2800 psi and close cementer. Bleed off and check for flow. No flow. Pump retarder pill to flush lines. Shut down. CIP at 1700 hours. 17:00 - 20:00 3.00 CASE P DECOMP PJSM. Set slips. Break out and lay down cement head. Rig down cellar lines. Blow down all lines. Lay tools down beaver slide. 20:00 - 22:00 2.00 WHSUR P DECOMP PJSM. ND BOP stack and tubing spool. Remove mouse hole and turn buckles. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM. Suck out 9-5/8" casing. Remove secondary annulus valve. Prepare cellar for removal of casing head and tubing spool, then installation of Slip-Loc casing head and new tubing spool. Perform rig maintenace. Check 13-3/8" x 20" annulus for cement. Found material 8" from too. Process 4-1/2" completion tubing in pipe shed. 3/24/2008 00:00 - 06:00 6.00 WHSUR P DECOMP PJSM. Continue to prepare for wellhead work. Stage casing head in shop to keep warm. Clean flanges and seal ring seats. Stage tubing head as well. Continue to process 4-1/2" tubing in pipe shed. Change out upper rams to 4-1/2" x 7". Perform general maintenance and rig inspections. 06:00 - 12:00 6.00 WHSUR P DECOMP PJSM. Split BOP stack. Cut 9-5/8" casing and remove cut joint at 32.78'. Set BOP stac back. Remove tubing spool. Cut 13-3/8" casing at lowest point. Remove casing head and 13-3/8" stub. 12:00 - 15:00 3.00 WHSUR N HMAN DECOMP Attempt to make final cut on 13-3/8" casing with WACHS cutter upside down. Unable to make cut. Rig welder finished cut with grinder cutting disks. Remove cut 13-3/8". PriMetl: 4/112UUt3 1L:3U:L3 PM BP EXPLORATION Page 14 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date From - To Hours Task -.Code NPT 3/24/2008 15:00 - 19:30 4.501 WHSUR P 19:30 - 22:30 3.00 ~ W HSU R A N 22:30 - 00:00 I 1.501 WHSUR I P 3/25/2008 00:00 - 02:30 02:30 - 05:00 05:00 - 06:00 06:00 - 10:00 2.50 WHSUR P 2.50 BOPSU P 1.00 BOPSU P 4.00 BOPSU N Start: 3/5/2008 Rig Release: 4/2/2008 Rig Number: 2ES DECOMP Phase HMAN I DECOMP Spud Date: 3/6/2008 End: 4/2/2008 Description of Operations Rig up and cut 9-5/8" casing with WACHS cutter and remove cu sec ion o rap, recu and remove cut section of .43'. Attempt to install new Slip-Loc casing head. Head will not go over 9-5/8" stump. Loosen slip segments and steam head. Still will not slip on stump. Remove casing head and caliper 9-5/8" at 9-11/16", well within tolerances. Disassemble slip section of casing head. Remove metal seal and calliper. Seal slightlly smaller ID than casing OD even though part number correct. Bring in new casing head and steam off. Slip over stump with DECOMP PJSM. Metal seal visably smaller than previous seal. Make up casing head in proper orientation. Drill site operator waived witness of installation of casing head. Test seals to 1400 psi. Test good. DECOMP PJSM. Finish testing seals on casing head. Install tubing spool and double studded adapter flange. DECOMP PJSM. NU BOBE. Set riser. Hook up flow line and turnbuckles. DECOMP PJSM. Rig up to test BOPE. Test body breaks and rams. Test 4-1/2" to 250 psi low, 3500 psi high as per AOGCC. -Test witnessed waived by Lou Grimaldi with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Jon Castle. SFAL DECOMP -Could not get 4-1/2" x 7" rams to test w/7" test jt. Added XO to change position of jt -still no test. 10:00 - 11:00 1.00 BOPSU P DECOMP Test top 7" rams to 250 psi low, 3500 psi high. Good test. -Rig down and blow down testing equip. Install wear ring. 11:00 - 11:30 0.50 BOPSU P DECOMP PJSM. Bring Baker Tools up beaver slide to floor. 11:30 - 13:00 1.50 CLEAN P DECOMP PJSM. Make up 9-5/8" clean out BHA to 306'. Change out handling equipment. 13:00 - 13:30 0.50 CLEAN P DECOMP PJSM. RIH to 2174'. Install blower hose. 13:30 - 19:30 -Up Wt 75k, Dn Wt 80k, ROT 82k ~ 40 rpm w/1 k free Torque 6.00 CLEAN P DECOMP Drill cement C~ 90 rpm, TO on = 2-3k ft-Ibs w/5-10k WOB -Circulate C~? 553 gpm, 1192 psi. -Drill ES cementer C~3 2283'. Plug rubber & cmt returns across -Pump sweep when through cementer. -Continue drilling cmt to Insert Landing Collar. -Control drill w/10k WOB ~ 357 gpm, 517 psi. -RIH to top of sand ~ 2362'. -Drill to 2368' C~3 65 gpm -sand and debris across shakers. -Bring pumps up to 600 gpm, PU to 2362'. -Pump his-vis sweep w/sand returns across shakers. 19:30 - 20:00 0.50 CLEAN P DECOMP PJSM. Test 9-5/8" casing to 3500 psi for 30 minutes -good test. -Test witnessed by WSL Mark Staudinger and NTP Jon Castle 20:00 - 20:30 0.50 CLEAN P DECOMP PJSM. POH from 2318 to 306'. Change out handling equipment. 20:30 - 21:30 1.00 CLEAN P DECOMP PJSM. Rack back DC and LD BHA. Clean and clear rig floor. 21:30 - 22:30 1.00 CLEAN P DECOMP MU Reverse Circ Junk Basket BHA to 313'. 22:30 - 23:30 1.00 CLEAN P DECOMP RIH from 313' to 2181'. Install blower hose. -Up Wt 80k, Dn Wt 85k, Rot 80k Printed: 4/11/2008 12:30:23 PM • BP EXPLORATION Page 15 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date ~L From. - To Hours ', Task Code NPT Start: 3/5/2008 Rig Release: 4/2/2008 Rig Number: 2ES Spud Date: 3/6/2008 End: 4/2/2008 3/25/2008 122:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 I 0.501 CLEAN I P 3/26/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:30 1.50 CLEAN P 02:30 - 03:00 0.50 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 05:30 0.50 P 05:30 - 06:30 1.00 CLEAN P 06:30 - 07:00 0.50 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 09:00 1.00 CLEAN P Phase Description of Operations DECOMP -Drop ball and circ ~ 340 gpm, 2100 psi -Wash to 2384'. PU and retag -unable to continue. DECOMP Circulate BU C~ 367 gpm, 3083 psi. -Rack back stand and blow down top drive. DECOMP PJSM. POH from 2384'to 313'. DECOMP POH and empty boot baskets, jet baskets, and clean floor. -Recovered shavin s of 13-3/8" cs and other small debris DECOMP MU Reverse Circulating Junk Basket BHA to 313'. DECOMP RIH from 313' to 2384'. DECOMP Drop ball. Wash and ream down through sand from 2384' 1 2404' @ 320 gpm, 2280 psi. 60 rpm C~3 1-2k ft-Ibs TO. DECOMP CBU C~ 320 gpm, 2280 psi. -Blow down top drive and remove blower hose. -Rack back 2 stands to 2274'. DECOMP PJSM. Cut and slip 75' of drilling line. Service drawworks. DECOMP PJSM. Service crown and top drive. DECOMP POH from 2274' to 313'. DECOMP Lay down Reverse Circ Junk Basket BHA. Clean rig floor. -Recovered several large pieces of insert collar and smalle 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM. Make up RBP retrieving tool and RIH to 2404'. -Set down 10k C~3 2328' 10:00 - 11:30 1.50 CLEAN P DECOMP Wash down to 2412' ~ 500 gpm, 630 psi. Could not get over RBP. -Pump hi-vis sweep around. -Attem t to latch u to RBP. Rotate 1/4 turn and set down 20k. No success. -Could not get past 2412'. -Blow down top drive and remove blower hose. 11:30 - 13:00 1.50 CLEAN P DECOMP POH from 2412' and lay down RBP retrieving tool. Clean and clear rig floor. 13:00 - 14:30 1.50 CLEAN P DECOMP Pick up_and_make up Reverse Circ Junk Basket BHA with 14:30 - 16:00 1.50 CLEAN P DECOMP RIH to 2372'. Drop ball and establish circulation. -RIH to 2412' and pump ~ 460 gpm, 3870 psi. -Wash and work pipe over RBP several times and pump sweep around. Aluminum and sand over shakers. -Blow down TD and remove blower hose. 16:00 - 16:30 0.50 CLEAN P DECOMP POH from 2372' to 317'. 16:30 - 17:30 1.00 CLEAN P DECOMP Lay down BHA. Clean out boot baskets and jet baskets. -V~ large piece of aluminum insert collar wedged in bottom of extension below RCJB. 17:30 - 18:30 1.00 CLEAN P DECOMP Make up RBP retrieva ool and RIH to 2414'. -En a e RBP. PU to 5k over. -Rotate right 1 turn to release RBP. 18:30 - 20:00 1.50 CLEAN P DECOMP POH with 9-5/8" RBP from 2414' C~3 1 stand per minute. -LD retrieval tool and RBP 20:00 - 21:30 1.50 CLEAN P DECOMP Pick up Wash Pipe BHA and MU to 347' 21:30 - 22:00 0.50 CLEAN P DECOMP RIH from 347' to top of 7" csg stub C~? 2443' 22:00 - 23:00 1.00 CLEAN P DECOMP Wash down from 2443' to 2463' C 240 gpm, 210 psi. RPM = 45, TO = 1 k ft-Ibs. -Pump hi-vis sweep around ~ 600 gpm, 1610 psi. -Blow down Top Drive and remove blower hose. Printed: 4/11/2008 12:30:23 PM • BP EXPLORATION Page 16 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-176 Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 3/26/2008 23:00 - 00:00 1.00 CLEAN P DECOMP POH from 2463' to 347'. -Change out handling equipment and lay down BHA to 162'. 3/27/2008 00:00 - 01:30 1.50 CLEAN P DECOMP PJSM. L/D Washpipe BHA. Cleanout boot baskets -empty. 01:30 - 02:30 1.00 CLEAN P DECOMP Clear & clean rig floor. 02:30 - 03:00 0.50 CLEAN P DECOMP Pick up Backoff assembly to floor. 03:00 - 06:00 3.00 CLEAN P DECOMP PJSM. Make up 7" backoff assembly. -RIH to 515' and fill pipe with diesel. 06:00 - 08:00 2.00 CLEAN P DECOMP RIH from 515' to 2844', filling every stand with seawater on the fly. -Rig up pump-in sub and test pump. 08:00 - 11:00 3.00 CLEAN P DECOMP PJSM. Set lower anchor on backoff tool ~ 2469' and upper anchor @ 2446'. -Set lower anchor w/500 psi and slack off 17k lbs. -Set upper anchor w12500 psi and slack off 5k fbs. -Press up to 3000 psi - no turn, press up to 3500 psi - no turn. Bled off. -Shut bag and pressure ann to 500 psi and held -Press up DP to 3500 - no turn. Bleed off DP and annulus. -Pressure up to 1400 psi and backoff tool turned 3/4 of turn. -Bleed off pressure to reset backoff tool. -Repeat pressure up and bleed off to achieve 4 turns total. 11:00 - 12:00 1.00 CLEAN N DFAL DECOMP PJSM. Release backoff tool and rack back 1 stand. -Drop ball and rod and attempt to open circ sub. Pressure up to 3500 psi, but did not open. -Drop another ball and rod and press up to 3800 psi -would not open. 12:00 - 13:00 1.00 CLEAN P DECOMP POH wet from 2848' to 420'. Diesel in i e all the wa out. 13:00 - 15:00 2.00 CLEAN P DECOMP PJSM. Lay down backoff tool BHA. 15:00 - 15:30 0.50 CLEAN P DECOMP Make up Spear and mule shoe. 15:30 - 16:30 1.00 CLEAN P DECOMP RIH from 12'to 2443'. -Engage fish to no-go. Pull 10k over and rotate left 7 turns. -4.5k - 5k ft-Ibs TO fish came free. 16:30 - 17:30 1.00 CLEAN P DECOMP POH from 2443' to spear. No fish at surface. -Lay down spear. 17:30 - 18:30 1.00 CLEAN N DPRB DECOMP Wait on Baker Fishing to bring pinned grapple for spear. 18:30 - 19:00 0.50 CLEAN N DPRB DECOMP PJSM. MU new grapple and spear assembly. 19:00 - 20:00 1.00 CLEAN N DPRB DECOMP RIH and tag C~3 2333'. Pick up and attempt to slack off - No Go. -Set down 3k and rotate left -came free. -Continue to RIH to 2443' - no-go on fish and rotate 1 turn left. 20:00 - 21:30 1.50 CLEAN N DPRB DECOMP PJSM. POH to fish and LD fish and spear. -Pin end of 7" stub had a split 2" deep. -7" recovered stub was 19.44' 21:30 - 00:00 2.50 CLEAN N DPRB DECOMP Wait on SLB wireline for string-shot to shoot across next 7" connection. 3/28/2008 00:00 - 01:30 1.50 CLEAN N DPRB DECOMP Wait on SWS. Spot wireline unit. 01:30 - 02:30 1.00 CLEAN N DPRB DECOMP PJSM. RU SLB wireline unit. 02:30 - 03:30 1.00 CLEAN N DPRB DECOMP RIH w/ CCL and 5 strand string shot. -Fire string shot from 2498' to 2510' across 7" connection C~ 2504' 03:30 - 04:00 0.50 CLEAN N DPRB DECOMP PJSM. POH and Rig Down SWS. 04:00 - 06:00 2.00 CLEAN N DPRB DECOMP PJSM. Pick up and make up 7" Backoff BHA. Printed: 4/11/2008 12:30:23 PM BP EXPLORATION Page 17 of 20 Operations Summary Report Legal Well Name: C-176 Common Well Name: C-176 Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code. NPT Phase Description of Operations 3/28/2008 06:00 - 08:30 2.50 CLEAN N DPRB DECOMP PJSM. RIH to 2887' DPM, fill every JT w/fresh water. P/U = 80K, S/O = 80K. Set bottom anchor @ 2510' & top anchor ~ 2486'. 08:30 - 11:00 2.50 CLEAN N DPRB DECOMP Pressure up to 600 psi, slack off to 63K -set bottom anchor. Bleed off -wait 5 min, pressure up & attempt to break connection w/ 3900 psi - no break. Bleed off pressure. - Close bag, apply 700 psi to annulus for 4 min -bleed off. - Pressure up to 1400 psi -break connection. - Repeat process and achieve 5 complete turns on surface. 11:00 - 11:30 0.50 CLEAN N DPRB DECOMP Drop ball & open circ sub ~ 2100 psi. Circulate pipe volume ~ 500 GPM ~ 620 psi. Pump slug. 11:30 - 12:30 1.00 CLEAN N DPRB DECOMP PJSM. POH from 2887'. 12:30 - 14:00 1.50 CLEAN N DPRB DECOMP B/D L/D back-off BHA. Clean & clear rig floor. 14:00 - 15:00 1.00 CLEAN N DPRB DECOMP M/U 7" spear ass'y. RIH to 2470' -bottom out on no-go. 15:00 - 15:30 0.50 CLEAN N DPRB DECOMP ear & back out 7" JT. 15:30 - 16:30 1.00 CLEAN N DPRB DECOMP Pump hi-vis sweep C~ 525 GPM @ 570 psi. 16:30 - 19:00 2.50 CLEAN N DPRB DECOMP PJSM. POH from 2470'. 19:00 - 19:30 0.50 CLEAN P 19:30 - 21:00 1.50 CASE P 21:00 - 00:00 3.00 CASE P 3/29/2008 100:00 - 02:00 I 2.001 CASE I P 02:00 - 03:30 I 1.501 CASE I P -Fish on spear. Top collar on joint had 1/2" split. Bottom pin was good. Fished joint strapped at 41.26' DECOMP PJSM. Pull wear ring. DECOMP R/U 7" CSG handling equipment & tools. DECOMP PJSM. RIH w/ screw in sub, Baker Insert Collar, and ES DECOMP RIH w/ 7" CSG to 2504' (torqued connections to 10,100 ft/Ibs). .Rotated to swallow slum wJ cutli uide. PJU = 85K, S/O = 90K. - Screwed in triple connect sub to stump - 11 turns. - 10K torque applied C~ surface -work torque down. - Pull & hold casing to 150K over (250K on indicator). DECOMP Test 7" casing to 500 psi for 5 min, then 1000 psi for 10 min - passed (charted). Pressure up to 3000 psi to shear disc - unable to shear. Pressure up to 3300 psi - no shear. Pressure 03:30 - 04:30 1.00 CASE P DECOMP Break circulation ~ 400 GPM @ 200 psi w/ 100 degree seawater. Hold PJSM w/ SLB cementers. 04:30 - 05:30 1.00 CASE P DECOMP Blow down top drive. Drop Bakerite ball. R/U cement head and XOs. 05:30 - 07:00 1.50 CASE P DECOMP Switch to SLB Pumps and pump 5 bbls fresh water. -Test lines to 4000 psi -failed. Walk lines and refunction valves. -Retest lines to 4000 psi -good. -Pump 15 bbls fresh water w/red dye ~ 5 bpm. -Pump 85 bbls 15.8 ppg Class G cement ~ 5 bpm, 880 psi. -Drop ES cementer closing plug and chase w/5 bbls fresh water. -Swap to rig pumps and displace w/seawater ~ 5 bpm. -When red dye at surface, shut down pumps, close bag, divert flow to cuttings tank. -Continue pumping ~ 5bpm. Slow to 2 bpm for last 7.5 bbls before plug bump. -Bump plug ~ 2 bpm, 1140 psi. -Continue ressure u to 2900 si nd h I Cementer closed w/2300 psi. Printed: 4/11/2008 12:30:23 PM $P EXPLORATION Page 18 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To ; Hours Task Code ~ N 3/29/2008 05:30 - 07:00 07:00 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 21:30 3/30/2008 3/31/2008 21:30 - 00:00 00:00 - 03:00 03:00 - 04:00 04:00 - 07:00 07:00 - 10:30 10:30 - 11:00 11:00 - 13:00 1.50 CASE P 1.50 CASE P 1.00 WHSUR P 2.50 WHSUR P 2.00 WHSUR P 1.00 BOPSU P 6.50 BOPSU P 2.50 BOPSU~P 3.00 BOPSU P 1.00 BOPSU P 3.00 BOPSU P 3.50 BOPSU P 0.50 BOPSU~P 2.00 CASE P T Phase Description of Operations DECOMP -Bleed off and check for flow back -none. -15 bbls cement back to surface. -CIP @ 06:55 hrs. DECOMP Blow down surface equipment and rig down circ lines. -Rig down cement head. Clear floor and suck out 7" joint and stack. DECOMP Split and lift up BOP's and tubing spool. DECOMP Set emergency slips w/150k tension on 7" csg. -Cut 7" csg with Wachs Cutter. Cut piece strapped @ 31.64'. -Install pack-off DECOMP PJSM. Nipple up BOPE. Test 7" pack-off and lower flange to 4200 psi for 30 minutes -good test. DECOMP PJSM. Change out top rams from 7" to 3-112" x 6" VBR. DECOMP PJSM. Rig up to test BOPE. Test BOPE to 250 psi low / 3500 psi high w/ 4" and 4-1/2" test joints. -Hydril, choke valve #9, and 3.1/2" x 6" VBR Rams Failed. -Blow down choke & testing equipment. -Witness of test waived by AOGCC Rep John Crisp. -Test witnessed by WSL Bil Decker and NTP Charlie Henley. DECOMP PJSM. Change out Hydril element. DECOMP Continue changing out Hydril Element and Rebuild choke valve #9. -Mechanic timed out. Install new 3-1/2" x 6" VBR Rams while waiting on Master Mechanic from NOC. Continue to install new element when Master Mechanic arrived. DECOMP PJSM. Change out top rams to new 3 1/2" x 6" variables. DECOMP Inspect Hydril seals,lnstall Hydril top and torque in place. -Install turn buckles mouse hole, and riser. -Clear and clean cellar. DECOMP Test #9 choke valve to 250 psi low and 3500 psi high. -Test Upper pipe rams with 4 1/2" and 4" test joints to 250 psi low and 3500 psi high. Test Hydril to 250 psi low and 2500 psi high. Test witnessed by BP rep Bill Decker and NAD rep Charlie Henley. DECOMP Pull test plug and install wear ring. -Blow down surface equipment. DECOMP Pick up Baker tools to floor and make up clean out BHA to 1.00 CASE P DECOMP PJSM. Run in hole from 397' to 2490'. 8.00 CASE P DECOMP Drill cement, ES cementer, and float collar from 2430' to 2498'. -525 GPM C~ 1610 psi -RPM 80 torque 1-3k ft lbs. WOB 10-14K. Push Insert collar to 3153'. Rotate on top of Insert collar frrom 3153' - 3185'. 13:00 - 14:00 14:00 - 22:00 0.50 CASE P DECOMP Circ hi-vis sweep around C~ 525 GPM ~ 1820 psi. Recovered sand, small rubber chunks and approx 1/2" aluminum pieces over the shakers. -Pull up to 3105' for test. 1.00 CASE P DECOMP PJSM. Test 7" casin to a 3500 si charted - assed. 0.50 CASE P DECOMP PJSM. POH L/D drill pipe. 2.00 CLEAN P CLEAN UD drill pipe from 2638' to 399'. 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:00 Printed: 4/11/2008 12:30:23 PM • BP EXPLORATION Page 19 of 20 Operations Summary Report Legal Well Name: C-176 Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ~ Code ~ NPT ~' Phase Description of Operations 3/31/2008 02:00 - 03:00 1.00 CLEAN P CLEAN UD drillout BHA. Recovered 1 gal of sand & aluminum pieces in boot baskets- 6 1/8" bit in good shape. 03:00 - 04:00 1.00 CLEAN P CLEAN MU RCJB BHA. 04:00 - 05:00 1.00 CLEAN P CLEAN PJSM. RIH w/ RCJB ass'y. 05:00 - 07:00 2.00 CLEAN P CLEAN Conduct D-6 stripping drill w/ 4" DP. 07:00 - 07:30 0.50 CLEAN P CLEAN Run in hole from 2273' to 3115' -install blower hose -drop reverse junk basket ball. 07:30 - 09:00 1.50 CLEAN P CLEAN Tag top of sand ~ 3189'_ -Work string several times -Pump Hi-Vis sweep -Blow down top drive,Remove blower hose 09:00 - 09:30 0.50 CLEAN P CLEAN POH from 3201' to 1806'. 09:30 - 10:30 1.00 CLEAN P CLEAN Lay down drill pipe from 1806' to 408',change out handling equipment. 10:30 - 12:00 1.50 CLEAN P CLEAN Lay down BHA from 408'. -Clear floor. 12:00 - 13:30 1.50 CLEAN P CLEAN PJSM. Make up RBP retrieving tool and run in to 3201'. 13:30 - 14:30 1.00 CLEAN P CLEAN Wash down to RBP - Set down 15k, pick up,not latched -Set down 20k,pick up ,turn 1/4 turn to right,set down 15k,latched -Pull up with 10k overpull. -Circulate sweep around,500 GPM C~ 940 psi. -Turn 1/2 turn to right and RBP pulls free. 14:30 - 17:30 3.00 CLEAN P CLEAN POH laying down drill pipe and BHA. -Lay down retrieving tool and RBP. 17:30 - 18:00 0.50 BOPSU P RUNCMP PJSM. Pull wear ring. 18:00 - 20:00 2.00 BUNCO RUNCMP PJSM. Ri u to run 4 1/2" chrome com letion. 20:00 - 00:00 4.00 BUNCO RUNCMP Run 4 1/2" 13cr-80 Vam Top completion. 4/1/2008 00:00 - 12:00 12.00 BUNCO RUNCMP Run 4 1/2" 13cr-80 Vam Top completion from 1914' - 10,088'. M/U torque value ~ 4400 ft-Ibs. 12:00 - 14:30 2.50 BUNCO RUNCMP Run 4 1/2" 13cr-80 Vam Top completion from 10,088' - 10,152' M/U torque value ~ 4400 ft-Ibs. -Shear overshot pins ~ 10,156'. -No go ~ 10,162' -Space out tubing to 10,158' -RILDS 14:30 - 15:30 1.00 BUNCO RUNCMP PJSM. Reverse 130 bbls inhibited seawater,followed by 60 bbls clean seawater,122 GPM C~ 350 psi. 15:30 - 17:30 2.00 BUNCO RUNCMP PJSM. Drop ball & rod assembly and pressure up tubing to -Bleed tubing to 1500 psi and presure up annulus to 3500 psi,hold for 30 minutes and chart -passed. -Bleed annulus then TBG to 0 psi. -Shear DCK valve (~ 800 psi, -Circulate both ways. Ann = 122 GPM r~ 700 psi, TBG = 122 GPM ~ 700 psi. 17:30 - 18:00 0.50 BUNCO RUNCMP PJSM. Install TWC, test above & below to 1000 psi -passed. 18:00 - 20:00 2.00 BOPSU P RUNCMP PJSM. N/D BOPE. 20:00 - 23:30 3.50 WHSUR P RUNCMP PJSM. N/U adapter flange & tree. Test adapter flange &TBG Printed: 4/11/2008 12:30:23 PM C~ BP EXPLORATION Page 20 of 20 Operations Summary Report Legal Well Name: C-17B Common Well Name: C-17B Spud Date: 3/6/2008 Event Name: WORKOVER Start: 3/5/2008 End: 4/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/2/2008 Rig Name: NABOBS 2ES Rig Number: 2ES bate From - To Hours Task Code NPT Phase I, Description of Operations 4/1/2008 20:00 - 23:30 3.50 WHSUR P RUNCMP hanger pack-off to 5000 psi for 30 min -passed. 23:30 - 00:00 0.50 WHSUR P RUNCMP PJSM. R/U DSM lubricator. 4/2/2008 00:00 - 01:00 1.00 WHSUR RUNCMP R/U DSM. Test lubricator to 500 psi. Pull TWC. 01:00 - 03:00 2.00 WHSUR RUNCMP PJSM. R/U to LRS to circulate diesel. Test lines to 3500 psi. Reverse circulate 75 bbls of diesel @ 2 BPM C~ 700 psi. 03:00 - 05:00 2.00 WHSUR RUNCMP Allow TBG and annulus to U-tube. 05:00 - 07:00 2.00 WHSUR RUNCMP Install BPV. Prepare to move rig. Rig release 07:00 Hrs on 04-02-08 Printed: 4/11/2008 12:30:23 PM Digital Well File V1/ell: C-17 ~ • Well History Weli Date Summary C-17B 4/2/2008 T/I/0=0/0/0; Pulled 4-1/16" CIW H TWC and Set 4-1/16" CIW H BPV thru tree after U-tube for 2ES; 1-2' ext. used, tagged C~3 102"; ***Complete*** (Best/Wortham) C-176 4/6/2008 T/I/O =VAC/0/0 Pulled 4" CIW BPV post rig work ***job complete*** C-176 4/7/2008 serviced tree post rig C-17B 4/8/2008 ***WELL S/I ON ARRIVAL*** (post nvo) „PULLED B&R FROM 10123' SLM PULLED DGLV FROM STA#3 @ 5953' SLM & DCK SHEAR VALVE FROM STA# 4 @ 3253' SLM SET SET GENERIC GASLIFT DESIGN IN STA'S # 4 & 3 PULLED RHC PLUG BODY FROM 10125' SLM DRIFTED TO 10172' SLM W/ 3.70" CENT (BAKER QUICK DRILL C~ 10179') "°~PECCCEFT P NOTIFIED*** C-17B 4/13/2008 CTU #9.1.50" Coil. Mill QuickDrill. MIRU MU and RIH with Baker MHA and 3.13" venturi jet junk basket. C-17B 4/13/2008 CTU #9.1.50" Coil. Mill QuickDrill. MIRU MU and RIH with Baker MHA and 3.13" venturi jet junk basket. Circulate through venturi and taa alua at 10183' ctmd. Reciprocate with venturi from 10183' - 10143' ctmd. POOH. Continued on WSR 04/14/08. C-176 4/13/2008 CTU #9.1.50" Coil. Mill QuickDrill. MIRU MU and RIH with Baker MHA and 3.13" venturi jet junk basket. Circulate through venturi and tag plug at 10183' ctmd. Reciprocate with venturi from 10183' - 10143' ctmd. POOH. Continued on WSR 04/14/08. C-176 4/14/2008 CTU #9 w/ 1.5" OD CT. Mill composite plug, continued from WSR 04/13/08. Pull to surface with venturi. Inspect venturi junk basket -find several large chunks of metal debris clogging lower-most flutter cage. Redress flutter cages and RBIH with 3.13" OD venturi jet junk basket. Circulate through venturi and tag plug at 10186' ctmd. Reciprocate with venturi from 10186' - 10100' ctmd. Pull to surface. Inspect....Found 3 small brass pieces. MU and RIH with 3.70" opti-cut mill. Tag C~ 10187' ctmd. Begin milling Baker quick drill. Job in Progress ...................... C-176 4/14/2008 CTU #9 w/ 1.5" OD CT. Mill composite plug, continued from WSR 04/13/08. Pull to surface with venturi. Inspect venturi junk basket -find several large chunks of metal debris clogging lower-most flutter cage. Redress flutter cages and RBIH with 3.13" OD venturi jet junk basket. Circulate through venturi and tag plug at 10186' ctmd. Reciprocate with venturi from 10186' - 10100' ctmd. Pull to surface. Inspect venturi basket -found 3 small brass pieces. MU and RIH with 3.70" opti-cut mill. Tag @ 10187' ctmd. Begin milling Baker quick drill. Break throu h lu ;lose all returns at surface as well goes on vac. Begin pushing plug to bottom. Continued on 04 15 08. C-17B 4/14/2008 CTU #9 w/ 1.5" OD CT. Mill composite plug, continued from WSR 04/13/08. Pull to surface with venturi. Inspect venturi junk basket -find several large chunks of metal debris clogging lower-most flutter cage. Redress flutter cages and RBIH with 3.13" OD venturi jet junk basket. Circulate through venturi and tag plug at 10186' ctmd. Reciprocate with venturi from 10186' - 10100' ctmd. Pull to surface. Inspect.... C-176 4/14/2008 CTU #9 w/ 1.5" OD CT. Mill composite plug, continued from WSR 04/13/08. Pull to surface with venturi. Inspect venturi junk basket -find several large chunks of metal debris clogging lower-most flutter cage. Redress flutter cages and RBIH with 3.13" OD venturi jet junk basket. Circulate through venturi and tag plug at 10186' ctmd. Reciprocate with venturi from 10186' - 10100' ctmd. Pull to surface. Inspect venturi basket -found 3 small brass pieces. MU and RIH with 3.70" opti-cut mill. Tag C~3 10187' ctmd. Begin milling Baker quick drill. Break through plug; lose all returns at surface as well goes on vac. Begin pushing plug to bottom. Continued on WSR 04/15/08. C-17B 4/15/2008 CTU #9 w/ 1.50" OD CT. Mill composite plug, continued from WSR 04/14/08. Continue to work composite plug down to 11900' ctmd with numerous stalls and bit sticking. POOH for 5-blade mill and jars. Cut pipe, MU and RIH with jars, PDM and 3.70" OD 5-bladed mill. Push plug to 12570' ctmd. At this depth, begin stalling motor erratically and begin encountering stalls, motor work and overpulls during PUs. Conclude we are beginning to get into fill at this depth. Begin POOH. Continued on WSR 04/16/08. C-176 4/15/2008 CTU #9 w/ 1.50" OD CT. Mill composite plug, continued from WSR 04/14/08. Continue to work composite plug down to 11900' ctmd with numerous stalls and bit sticking. POOH for 5-blade mill and jars. Cut pipe, MU and RIH with jars, PDM and 3.70" OD 5-bladed mill. Job in Progress ...................... C-17B 4/15/2008 CTU #9 w/ 1.50" OD CT. Mill composite plug, continued from WSR 04/14/08. C-176 4/16/2008 CTU #9 w/ 1.5" OD CT. Mill composite plug, continued from WSR 04/15/08. Pull to surface after pushing remnants of Baker Quikdrill composite bridge plug to 12570' ctmd. RDMO. Job complete. Print Date: 5/13/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.c om/WIInfo/Reports/ReportViewer. aspx Page 1 of 1 5/13/200$ . 03/12/08 ~chlamberger N0.4629 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~~'~~~~ ~~~ ~ ~ 2U~i3 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Endicott Wnll _Inh tt 1 nn Daacriniinn DatP_ t3L Color CD C-176 12031461 USIT - it 03/0,x/08 1 1 1-67/T-20 12014001 USIT - ~ ~ 03 09/08 1 1 E-21B 11661157 MCNL a 06/19!07 1 1 02-35B 11216177 MCNL ~ 02/09/06 1 1 C-34A 11216194 MCNL j U~ ~ 05/11/06 1 1 G-08A 11628761 MCNL ~ * 05/11/07 1 1 04-01A 11661146 MCNL 05/15/07 1 1 PLEASE ACKNUWLEDGE RECEIPT BY SIGNING ANU Hti UHNINCi UNt LUNY tACli I U: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 .- , •~ i 900 E. Benson Blvd. `` Anchorage, Alaska 99508 tt Date Delivered: ~`~1~',S'~ -~ "~ ~j~~`ls; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: • • • ..~=~_ MICROFILMED 03101 /2008 DO NOT PLACE ~.~~„ ~.~. .: °"= ~v ANY NEW MATERIAL UNDER THIS PAGE F:~I.aserFiche\C~rPgs_InsertstMicrofihn_Marker.doc • • g SARAH PALIN, GOVERNOR CO1~SE~t~Rg A,IIOH ~ ~ SIOl~ 333 W 7th AVENUE, SUITE 100 •` i,+~•••~~.~~ilil~~•lliiii----777 Qis ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska, Inc. ~V~~~7 DEC ~ ~ 2007 PO Box 196612 ~ ~ ~ ~' Anchorage, Alaska 99519-6612 ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-17B Sundry Number: 307-381 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~~~day of December, 2007 Encl. Sincerely, ~~ ~'~~J STATE OF ALASKA ~dca~lO~ ~ ALASKA OIL AND GAS CONSERVATION COMMfSSION ~~a~~ '~}`"~ ~ '~ ~~p~ /Z~LI~ ~ ~ APPLICATION FOR SUNDRY APPROVAL ~Rl~~ka oil ~ ~~ ~ ~ a:~. t,~ ~ ~ _~: ~~~ 20 AAC 25.280 =.l ,., ,r,. 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drilf Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-094' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20439-02-00 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-17B - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~ ADL 028304 ~ 61.7' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12_ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12770 8944 - 12682 ~ 8946 - None None Casin Len th Size MD TVD Burst Colla se Structural Conductor 110' 20" x 30" 110' 110' Surface 2662' 13-3/8" 2662' 2662' 5380 2670 Intermediate 10498' 9-5/8" 9418' 7459' 6870 4760 Production 10348' 7" 10373' 8329' 7240 5410 Liner Liner 2547' 4-1l2" 10222' - 12769' 8183' - 8944' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11300' - 12675' 8987' - 8946' 4-1/2", 12.6# 13Cr80 10228' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 10171' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 20, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jovy Roach, 564-4352 Printed Name Greg bbs Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4191 Date /L~/8~+~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~$OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 3~fld ~g ~ ~r~Q ~~~ Subsequent Form Required: i-~dl...t APPROVED BY /~R~/~ A roved B O TONER THE COMMISSION Date Form 10-403 Revised 06/2006 R 1y ~ I ~`~ ~ M ~OQ1 O R I G I N A L submit In Duplicate • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: 13 December 2007 Re: PBU C-17B RWO (Application for Sundry Approval) by Scope of Work: This primary focus of this workover is to eliminate the surface casing leak that currently exists with this well. The plan to remediate the SC leak will include the following RWO activities/procedures: 1. Cut and pull the 7" casing. Run new casing and cement to surface. 2. Cut and pull the 9-5/8" casing. Run new casing and cement to surface. 3. Cement a top job on the 13-3/8" x conductor annulus for abandonment. 4. Replace the wellhead, making the 9-5/8" the new surface casing. 5. Complete the well with new 4-1/2" chrome tubing with a stacker packer completion. Please note the following outline as provided below for more specific details regarding the workover plans for this well. MASP: 2320 psi Well Type: Ivishak Producer Estimated Start Date: January 20, 2008 C-17B RWO Planned Operations Summary (12/07/07) Pre-Rig Operations: (Work needs to be done within a 45 days of 2ES moving onto well.) 1. S RU, drift 4-1/2" tubing to the top of tubing tail plug (4-1/2" Baker Quik Drill) at 10180' MD. 2 E Jet cut the 4-1/2", 12.6#, 13-CR tubing ~ 1ft from the top of 2nd pup joint above the 7" x 4-1/2" Baker S-3 acker at 10171' MD cut tubin at 10152' MD . 3 F Circulate the well to seawater through the tubing cut. Freeze protect the IA and tubing with . diesel to 2,200'. 4 W Bleed OA, IA & TBG to zero psi. PPPOT - OC (13-3/8") 800 psi, PPPOT - IC (7") 3500 psi, PPPOT-T 4-1 /2" 5,000 si. Function all lock-down screws. 5 O Pressure test the OA (13-3/8" casing) to 2000 psi for 30 minutes. CMIT T x IA to 3,500 psi for . 30 minutes. 6. O Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 7 O Remove the well house. Level the pad. Please provide total well preparation cost on the . handoverform. F-48 RW O • Rise Operations: 1. MIRU Nabors 2ES. 2. MIT-OA 2000 psi. If MIT fails, obtain a LLR. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC and test from below to 1000 psi (also test TxIA) and from above to 3500 psi. 3. Nipple down tree. Nipple up and test BOP'. Pull TWC. 4. RU and pull the 4-1/2" tubing from the pre-rig jet cut ~ 10152'. Spool up SSSV control lines. Count bands and clamps retrieved. 5. RU E-line. Run USIT/GR/CCL from cut stub to surface to confirm the TOC on the back-side of the casing. (TOC on 7" casing estimated to be ~ 3600'.) 6. Cut and pull the 7" casing from above the TOC. 7. Run 9-5/8" casing scraper to top of 7" casing stub, ensure casing is clean. 8. Change one set of BOP rams to accommodate 9-5/8" casing. Test. 9. Cut and pull the existing 9-5/8" casing from above the TOC (USIT 07/05/04 confirmed TOC at 2650.) 10. Run and cement to surface a new 9-5/8" casing scab with ES Cementer. 11. Split the BOP stack. Rough cut 9-5/8" casing to set stack back. 12. LD cut joint of 9-5/8" casing, remove BOP stack. 13. Cut 13-3/8" casing with Wachs cutter and remove well head. 14. Install Sliplock wellhead. 15. Pump a cement top job through 1" pipe down 13-3/8" x 20" annulus, assuring voids are full of cement. 16. NU BOP and test. Ensure both sets of variables are installed. 17. Run and cement to surface a new 7" tie-back casing string with ES Cementer. 18. MU a clean-out BHA and RIH and drill-out the FasDrill plug in the 4-1 /2" tubing tail at 10,180' prior to running a new 4-1/2", 12.6#, 13 Cr80, VamTop stacker-packer completion. 19. Run 4-'/2", 12.6#, 13Cr-80, VamTop conventional single production packer completion. 20. Displace the IA to packer fluid and set the packer. 21. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 22. Set BPV. ND BOPE. NU and test tree. RDMO. Post-Ria Work: 1. O Install wellhouse and flowlines. (NOTE: An S-riser modification will be required.) 2. S MIRU slick line. Pull the ball and rod / RHC plug from 'X' nipple. 3. S Install gas lift valves. F-48 RW O 2 TREE = 6" McEV OY 1NELLHEAD= FMC ACTUATOR = OTIS KB. ELEV = 62.15' BF. ELEV = 34.3' KOP = 3300' Max Angie = 95 @ 12487' Datum MD = 10910' Datum TV D = 8800' SS 9-5/8" DV PKR 13-318" CSG, 72#, L-80, ID = 12.347" I 2584' I ***4-1 /2" CHROME TBG*** 2108' I~ 4-112" HES X NIP, ID = 3.813" -360U' I~ EST. TOP OF CMT GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3257 3254 9 CAMCO DMY BK 0 07!14/05 3 5964 5260 53 CAMCO DMY BK 0 07(14/05 2 8376 6746 46 KBG-2 DMY BK 0 07/20/04 1 10081 8046 14 KBG-2 DMY BK 0 07/20/04 7" SCAB LNR, 26#, L-80, ID = 6.276" i-I 25'- Minimum ID = 3.725" @ 10215' 4-112" HES XN NIPPLE 923T 7" TIEBACK SLV 9245' 9-5/8" X 7" BKR LNR TOP PKR MILLOUT WINDOW 9418' - 9434' 10150' 4-1 /2" HES X NIP, ID = 3.813" ,~~ 10171' 7" X 4-1/2" BKR S-3 PKR CIBP 9436' 5-112" TBG, 17#, L-80 9666' 7" BOT LNR HGR 9956' 9-5/8" CSG, 47#, L-80, ID = 8.681" -{ 1 U496 PERFORAT~N SUMMARY REF LOG: MWD / LWD ON JULY 2004 ANGLE AT TOP PERF: 89 @ 11300' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 4 11300 - 11515 O 07/18/04 2-7/8" 4 11680 - 11750 O 07/18/04 2-7/8" 4 11770 - 11875 O 07/18/04 2-7/8" 4 12010 - 12045 O 07/18/04 2-7/8" 4 12390 - 12450 O 07!18!04 2-7/8" 4 12465 - 12675 O 07/18/04 7" LNR, 29 #, L-80, .0371 bpf, ID = 6.184^ 11704' C-17B 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" ~ 12760' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 05/10/80 ORIGINAL COMPLETION 03/23/06 RPH/PJC WANER SAFETY NOTE 02/22/85 RWO 08/29/06 RDW/TLH WANER SFTY NOTE DELETED 03/15/98 GTD SIDETRACK (C-17A) 07/21/04 DAV/KA RIGSIDETRACK(C-17B) 01/10/05 ROY/TLP TBG &LNR CORRECTIONS 07/14105 JAR/TLH GLV GO PRUDHOE BAY UNIT WELL: G17B PERMff No: 2040940 API No: 50-029-20439-02 SEC 19, T11 N, R14E, 6' SNL & 1217' WEL BP Exploration (Alaska) 10194' --j 4-1 /2" HES X NIP, ID = 3.813" 10215' 4-1 /2" HES XN NIP, ID = 3.725" 10226' 4-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 10228' 4-1 /2" WLEG, ID = 3.958" 10229' 7" X 5" BKR LNR TOP PKR 10373' ~7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 2682' H PBTD TR~- ELLHEAD- ACTUA~OR - kB. EL Ed - 62.15' BF.ELL'J- 34,3' IMP - 33m' ~[ A ~ g1e - 96 ~ 12487' o0trm LID- 10910' oatrm TJ D - SSOQ s5 ~_~- 1 7' SCAB LNR, 261p, LSO, D -6276' 25'- 927 MinimumlD = 3.?~~" 7a21~' 4-'1!~' HE S ?€N NIPPLE C~e~1 943 5-11. TEG, 17ip, L~0 yam' 7' 8OT LNR HG R $" 9f~' C9G, 47 i7, LSO, D - 8b81' 10' PERPO RATIQ N 5:U LILIP, RY REF LOG: I~UDILWD4NJULY 2004 ANGLEATIQP PERF: ~~ 113m' ND~6e: Re1~rb Prad~aib~ DBriarikbrlcalparf~ia SfZE SPF INTERJAL Op1r6~ a4TE 2-7 r6' 4 113D0 - 11515 O 071180 4 2-7~' 4 1168D- 11750 O Q7118~04 2-7 r6' 4 1177 0- 1187 5 O 071110 4 2-7 J3' 4 12010- 12045 O 0711804 2-7 r6' 4 12390- 12450 O 0711&04 2-7~' 4 12465- 12675 O 07118A4 I7- LNR,29iP, LSO, D~71 apr, D-6.1$4' I~ 11704' 2 71S LNR. 6.1617, LSD, ID58 bpf, D -2 ~7' H 12760' 4x112' LNR,12.6~V, LSO, 0152 bpT, ID- *~*4-12" GHROMETBC~'~* 214$' ~-ilk' HES 5C N P, G - 3,813' 264' USIT71S,0~uerrBdTOCbeYI~~9~IS 364 4' EST. TOP 4 F C 13T GAS LFT Lt4NDREL9 ST LID Td D DEJ TYPE 4' LV LA71CH PORT GATE 4 3t2S7 3254 ~ CALIGd aLfr aK D D71141a5 3 5964 5260 53 cp, LIGd DLIY 8 {{ D 07114146 2 5376 67 46 46 141 G 2 DLIY B K 0 D7l2DID4 1 10081 8046 14 141 G 2 DLIY 8 K D D712DlD4 9237' I I7' TE8ACI4~LV PI{R t LIILLOUTWINDOW 9415-9431 -~ 14481 7' x 4ri1r Siacxer P14i N 14121 4x112 HE3 5€ NIP, D - 31313' .. 14166 U~q~e Ouera iat 10171' 7' SC 1x112 BItR S3 P~ 10194' 4-i f2' HES~C NP, ID- 3 E13' DATE RBd 8Y COLILIBYTS DATE REU 8Y COMMENTS 05r14rBp ORIGINAL COM FLETK?N Oa23rD6 RPWPJC WRLrERSAFETY NDTE 0~~~r83 17~A,0 0829V06 RDWITLH WAMlERSFTY NQTE DELETED asrisrsa crDSI~ETRACKt~irat] OTr21~d CIl1lrY.4K RIG S IDETRACK [G1T ~ 01110A5 RGYITL P TBG & L NR CO RRBCTIG NS 07114A5 JARITLH GLL' CA 1C~1~ ~--~4ri12' HES~NNIP. D-3.725' 1[p~6' 4x112' l'8G,12:E~1, 1S-CR, ~ 152 bpt, D - 3958• 1022 iril2' WL~, D - 3958' 1022 7' 7C 5' 8141 LN R T4 P P kR 140373' 7' LNR,261l, LSO, X363 6pf, D - 6276' xx 126$2' H PBTD PRUDHDE 8RY UN8' WELL: C-178 PERII7T Na: 2D409 40 APINa: SD-029 X439-D2 SBG 19, T11N, R14E,6'S~NL & 1217' WEL Ela E;plarailan (Alai NaJ f ~ LICEuOY _,. FL1G SA OTB -1 ~ ~ F~1J ~ [~ R F T 07/23/07 Scblumberger SCANNE.D JUL 2 7 2007 NO. 4339 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '" p' Z007 ¿ :;) - . I c!}04 - Ot:::¡L.f Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Oil &. C(¡!1(¡. Commission ,~!1çhorage l~¿;f1Ò Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD 5-400 40012946 OH EDIT 2 1 W-01A 40012483 UHr::ull 11/06/05 2 1 S-401 (REVISED) 40014121 OH EDIT MWD/LWD 10/21/06 2 1 S-401 PB1(REVISED) 40014121 OH EDIT MWD/LWD 10/08/06 2 1 C-17B 10715418 MCNL 08/10/04 1 L5.15 11626485 RST 05/12/07 1 1 N-15 11637129 RST 01/13/07 1 1 15-38A 10715446 MCNL 12/11/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. 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 Date Delivered: Received by: /\ . . ;(} ß.~,- DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2040940 Well Name/No. PRUDHOE BAY UNIT C-17B Operator BP EXPLORATION (ALASKA) INC ~ J\I!S~v( API No. 50-029-20439-02-00 MD 12770,/ TVD 8944 Completion Date 7/21/2004.,- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: DIR / GR / PWD, DIR / GR / RES / DEN / NEU I ASI (data taken from Logs Portion of Master Well Data Maint Run No Interval Start Stop . Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I ./ D Asc Directional Survey -1,ED ~ Directional Survey D C Lis 13627 Induction/Resistivity £ Neutron ~ D Lis 13329 Induction/Resistivity i Log Log Scale Media OH/ CH 9418 Received Comments 8/5/2004 MWD 8/5/2004 MWD 12770 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics 11271 2/3/2005 mcnl/mem gr/ccl/cnl 12709 Open 10/26/2005 GR EWR4 ASI PWD CNP SLD ROP 2 Slu 10015 9169 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? v0 Chips Received? i I N Daily History Received? ~ . Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ Date: ~i~ ~<ø . . WELL LOG TRANSMITTAL ct!04 -oq4- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 J 3& ;;r1 RE: MWD Formation Evaluation Logs C-17B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 C-17B: LAS Data & Digital Log Images: 50-029-20439-02 1 CD Rom ~i() !ÞI 'ð [1{00/ '.'.'.. .~ 5 ,.,:>1 . \ì w WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 27,2005 RE: MWD Formation Evaluation Logs: C-17B, AK-MW-3164914 1 LDWG formatted Disc with verification listing. J] 1 ~ 9 API#: 50-029-20439-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry 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:? 7 ó'ct-Át\) r 1LJ &/JJ Signed: ~ è fwI/ - (J' \,Jl C-17B (PTD #2040940) Classified as Problem Well . All, Well C-17B (PTD #2040940) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 07/07/05 were 2260/2260/15/vac. A TIFL failed on 717/05 on overnight build up rate. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED on BUR 2. SL: Run DGL Vs 3. FB: MITIA to 3000 psi Attached is a wellbore schematic. Please call if you have any questions. «C-17B.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr Content-Description: C-17B.pdf Content-Type: application/octet-stream Content-Encoding: base64 H-e<;;SliveC; scJ> )vtfol-{P '"¿ J"f:F<1P ¡- I '1-- 4,ù f''>í ¿::..~ 'Z.ZbÛ PSI 7Z4cJ ^~-I r >. 3 Î ,2. tl.o òr- fo"' tD 4tt 2- (]i<~ 7/7:7(oc 6Pr ì5'r\ \in 6ß70fs: 63(YJr~ ò (,~ . Z-lc co ,A:- D 1 of! 7/18/200512:51 PM TREE = 6" McEVOY WELLHEAD = FMC 'ÀCTUA TO'R";' offS' KB. ELEV = 6Ú~/ BF. ELEV = 34.3' ,~-~,- .. ,~~~~~"..,~,~,,,.~~~""~, KOP = 3300' 'Max Angle = 95~@'12487; 'Datum M[)';~'~'-~ 10916' ~ _'_~~~~'__'__'''. ,~._m,~_,_~ Datum TVD = 8800' SS 19-5/8" DV PKR H 113-3/8" CSG, 72#, L-80, ID= 12.347" I-{ 2584' 2662' . I ~ 17" SCAB LNR, 26#, L-80, ID = 6.276" H 25'· 9273' Minimum ID = 3.725" @ 10215' 4-1/2" HES XN NIPPLE ! CIBP H 15-1/2" TBG, 17#, L-80 H 17" BOT LNR HGR H 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9436' 9666' 9956' 10496' C-17B I SA~ES: 4-1/2" CHROMETBG, 2108' H4-1/2" HES X NIP, ID" 3.813" I /-~. I~ EST. TOP OF CMT I GAS LIFT MANDRELS ST MO TVD DEV TYÆ VLV LA TCH PORT DATE 4 3257 3254 9 CAMCO DOME BEK 16 08/09/04 >< 3 5964 5260 53 CAMCO S/O BK 20 08/09/04 >< ~ 2 8376 6746 46 KBG-2 DMY BK 07/20/04 >< 1 10081 8046 14 KBG-2 DMY BK 07/20/04 >< r---i 9237' I~ 7" TIEBACK SL V 1 9245' H 9-5/8" X T' BKR LNR TOP PKR I L "II ÆRFORA TION SUMMARY REF LOG: MWD / LWD ON JULY 2004 ANGLEATTOPÆRF: 89 @ 11300' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11300-11515 0 07/18/04 2-7/8" 4 11680-11750 0 07/18/04 2-7/8" 4 11770 - 11875 0 07/18/04 2-7/8" 4 12010 - 12045 0 07/18/04 2-7/8" 4 12390 -12450 0 07/18104 . 17" L:8~9' ~80:::~::f'~:~56'84" ~~ 110:=~84 ~ _ ~ 12-7/8" LNR, 6.16#, L-80, .0058 bpf, iO" 2.37" H 12760' I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12769' OA TE REV BY COMMENTS 05110180 ORIGINAL COMPLETION 02122185 RWO 03115198 CTD SIDETRACK (C-17A) 07121104 DAVIKAK RIG SIDETRACK (C-17B) 08/09104 JLJrrLP GL V ClO 08/17104 TLHrrLH CORRECTION (7" SCAB LNR) MILL OUT WINDOW 9418' - 9434' 10150' H4-112" HES X NIP, 10 = 3.813" I 10171' HT' X 4-1/2" BKR $-3 PKR I I .. þ I. I. I. ~ DATE 08/18/04 09130/04 01/10/05 REV BY COMMENTS TLHlTLP TBG CORRECTIONS ROY rrLH TBG & LNR CORRECTIONS ROY fTLP TBG & LNR CORRECTIONS 10194' 10215' 10226' 1-14-1/2" HES X NIP, 10 = 3.813" I 1-14-1/2" HES XN NIP, ID = 3.725" I 114-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" -f4-1/2" WLEG, ID = 3.958" I H 7" X 5" BKR LNR TOP PKR I H 7" LNR, 26#, L-80, .0383 bpf, ~O = 6.276" 10228' 10229' 10373' I 12682' H PBID I PRUDHOE BAY UNfT WELL: C-17B ÆRMfT No: 2040940 API No: 50-029-20439-02 SEC 19, T11N, R14E, 6' SNL & 1217' WEL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth . Well Job# 10715391 10728396 10715393 10715395 10715402 10715404 10670016 10715406 10715407 10861913 10715410 10861916 10715413 10861920 10715418 10715421 20'b-)"JL,G-12B ~15-3S'B ).,0:3 " i qL¡ '-",vJ-¡ ( {,; D-04B -./ DS 18-13A 20'3-1'15 K-10B DS 02-15A 1...., 12'" DS 2-33A ~..,N ~ J ì <¡Fail.. DS 07 -03A '2tlJ.¡q¿ DS 07-29C /17'ð/1-_E-15B ~ ~5t{ DS 18-27C ";,c;"Cqi E-24B r-"./09 D518-31 ~.¡- II 0 K-09C ./0'1·0'11 C-17B (PJ~.&N C-39 .(prints ~ ~ only-Job not complete) MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL /07S~ c:{úc/ - óc¡f 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 03/21/04 1 04/03/04 1 04/07/04 1 04/16/04 1 05/16/04 1 05/18104 1 OS/23/04 1 06/03/04 1 06/04/04 1 06/05104 1 06/13/04 1 06/20/04 1 07/05/04 1 07/16/04 1 08/10/04 1 08/19/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: . /'; ~ #:J/Oh I / Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283. uL ATTN: Beth - / Roo· edb" :¡:¿li CU£M.C<-- . STATE OF ALASKA e RECEIVED ALASKA'IIIf5'IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPlETION REPORT AND lOG AUG 1 82004 Alaska Oil & Gas Cons. Commission 1b. Well Class: Anchorage a Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-094 13. API Number 50- 029-20439-02-00 14. Well Name and Number: No. of Completions 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 21. Logs Run: DIR I GR I PWD, DIR I GR I RES I DEN I NEU / ABI CASING, liNER AND CEMENTING RECORD SETTING DEPTHMD SETTINGDEi>THTVD ToÞ BOTTOM BOTTOM Surface 110' Surface 110' Surface 2662' Surface 2662' Surface 9418' Surface 7459' 25' 10373' 25' 8329' 10222' 12769' 8183' 8944' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 6' SNL, 1217' WEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 4613' NSL, 496' EWL, SEC. 17, T11N, R14E, UM Total Depth: 827' NSL, 185' WEL, SEC. 07, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664128 y- 5961208 Zone- ASP4 TPI: x- 665723 y- 5965863 Zone- ASP4 Total Depth: x- 665004 y- 5967341 Zone- ASP4 18. Directional Survey a Yes 0 No 22. 20" x 30" Insulated 72# 47# 26# 12.6# Conductor L-80 L-80 L-80 L-80 13-3/8" 9-518" 7" 4-1/2" 23. Perforations open to Production (MD + TVD of T<?e and Bottom Interval, Size and Number; if none, state none"): 2-7/8" Gun Diameter, 4 spf MD TVD MD TVD 11300' - 11515' 8987' - 8989' 11680' - 11750' 8985' . 8982' 11770' - 11875' 8981' - 8977' 12010' -12045' 8975' - 8975' 12390' -12450' 8966' - 8961' 12465' - 12675' 8960' - 8946' 26. Date First Production: August 13,2004 Date of Test Hours Tested PRODUCTION FOR 8/13/2004 4 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ....... Press. 590 24-HoUR RATE""'" 27. One Other 5. Date Comp., Susp., or Aband. 7/21/2004 6. Date Spudded 7/8/2004 7. Date T.D. Reached 7/16/2004 8. KB Elevation (ft): 61.7' 9. Plug Back Depth (MD+ TVD) 12682 + 8946 10. Total Depth (MD+TVD) 12770 + 8944 11. Depth where SSSV set (Nipple) 2108' MD 19. Water depth, if offshore NIA MSL 36" 17-1/2" 12-1/4" 8-1/2" 6-1/8" SIZE 4-1/2", 12.6#, 13Cr80 25. PBU C-17B 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028304 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 12.9 cu yds Permafrost Concrete 3720 co ftAS II, Top Job: 59 cu tlAS I 1560 co ft Class 'G', 130 cu ft AS 286 cutl 'G', 663 cutl 'G', 163 cutl 'G' 365 cu ft Class 'G' DEPTH SET (MD) 10228' PACKER SET (MD) 10171' DEPTH INTERVAL (MD) 2100' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 73 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BBl GAs-McF WATER-BBl 374 174 2 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core cnips; if.no¡)e, state "none". COMPlETION . !),il1l 7/)1/ ;2ò9J ~BJ Oll-BBl 2,245 None Form 10-407 Revised 12/2003 GAs-McF 1,041 WATER-BBl 11 OR'GI~lAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO 176 464 Oil GRAVITY-API (CORR) ~Brt. AU6 1 ~ 2UU~ 0Y' 28. e GEOLOGIC MARKERS NAME MD TVD Sag River 10383' 8339' Shublik A 10420' 8375' Shublik B 10455' 8409' Shublik C 10475' 8428' Sadlerochit I Zone 4B 10498' 8450' Zone 4A 10560' 8510' Zone 3 I CGL 10650' 8595' Base CGL I Top Zone 2 10720' 8660' 22TS 10855' 8780' Zone 1 B 11043' 8914' Zone 1 A /TDF 11108' 8947' Base Sadlerochit 11520' 8989' e 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECE\VED AUG 1 81.\1\14 C mmlssiof\ 0'\ & Gas Cons. 0 A\a$~a \ MchoraQe 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~QJVLi 0_ dJ~ Title Technical Assistant Date æ.. (7 -(i.( PBU C-17B 204-094 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 4,651 (psi) 2.00 (ppg) 4,328 (psi 10.00 (ppg) e e Printed: 7/28/2004 2:02:31 PM 465 (psi 693 (psi 0.80 (ppg) 8.40 (ppg) 8,330.0 (ft) 0,373.0 (ft) Legal Name C-17B Common Name: C-17B 7/7/2004 FIT 7/12/2004 FIT Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/4/2004 10:00 - 11 :30 1.50 MOB P PRE Prepare rig for move to C-17B. Changeout saver sub and secure the rig floor. RD and remove the cuttings tank. Move the shop buildings. 11 :30 - 17:00 5.50 MOB P PRE PJSM with both crews and truck drivers prior to moving pits and sub. Move pits to C-17B. Pull sub off of C-24A and move, with 25 stands in the derrick, to C-17B. Lay herculite, spot and level the sub. Spot the pits, camp, shop and cuttings tank. Berm in all essential areas and take on seawater. Rig Accepted @ 17007/4/2004. 17:00 - 17:30 0.50 WHSUR P DECOMP Pre-Spud meeting with drill crew 17:30 - 18:00 0.50 WHSUR P DECOMP Install secondary annulus valve. 18:00 - 19:00 1.00 WHSUR P DECOMP Rig up drill site maintenance Lubricator. Pull CIW 63/8 type 'J' BPV, no pressure on well. 19:00 - 22:30 3.50 WHSUR P DECOMP Rig up lines to tree and annulus taking returns to cuttings tank. Circulate diesel from the well @ 3 bpm, 250 psi. Circulate a soap pill @ 9 bpm, 1,000 psi. Blow down circulation lines. RD lines. 22:30 - 00:00 1.50 WHSUR P DECOMP ND tree and adapter flange. 7/5/2004 00:00 - 03:30 3.50 BOPSUF P DECOMP NU BOP's. 03:30 - 07:30 4.00 BOPSUP P DECOMP Test BOP's and associated equipment, with the exception of the Annular Preventer, to 250/3,500 psi. Test the Annular Preventer to 250/2,500 psi. The witness of the BOP test was wavied by John Spaulding of the AOGCC. 07:30 - 08:30 1.00 WHSUR P DECOMP RU DSM lubricator and pull TWC. RD lubricator. 08:30 - 10:00 1.50 PULL P DECOMP MU Hanger XO's on landing joint. Hold PJSM. Back out the lock down screws and pull hanger to the rig floor - 195K to pull free and then 170K PU. Break out and LD hanger and landing joint 10:00 - 11 :00 1.00 PULL P DECOMP RU handling equipment and Schlumberger spooling unit. 11 :00 - 13:30 2.50 PULL P DECOMP LD 5-1/2",17#, L-80 BTC tubing from 9,666' to SSSV @ 7,490. Terminate control lines and LD SSSV. Recovered 25 Rubber Clamps, 25 Pins and 4 Stainless Steel Bands. 13:30 - 14:00 0.50 PULL P DECOMP RD spooling unit. 14:00 - 20:00 6.00 PULL P DECOMP LD 5-1/2" tubing from 7,490' RD handling equipment and clear the floor. Recovered 223 joints + 19.34' cut joint. 20:00 - 21 :30 1.50 BOPSUF P DECOMP RU 4-1/2" BOP testing equipment. Test the lower and upper pipe rams to 250/3,500 psi and the hydril to 250/2,500 psi. Pull test plug, install wear ring and RD test equipment. 21:30 - 22:15 0.75 EVAL P DECOMP PJSM. RU SWS. 22:15 - 00:00 1.75 EVAL P DECOMP RIH w/8.5" Gauge Ring 1 Junk Basket / CCL 1 Gamma Ray to top of tubing stub @ 9,666 ELM'. Gamma Ray Log up to 2,662'. 7/6/2004 00:00 - 01 :30 1.50 EVAL P DECOMP Log up with Gamma Ray from top of tubing stub @ 9,666 ELM' to 2,662'. POH. LD 8.5" GR/JB/Gamma. Minor amount of junk found. No restrictions while RIH or POH. 01 :30 - 07:30 6.00 EVAL C DECOMP RU and RIH with USIT. Log up from 9,660' to 2,400'- top of cement @ 2,650'. POH LD USIT. 07:30 - 11 :30 4.00 DHB P DECOMP Make up Halliburton wireline set 9 5/8 CIBP & Baker model 20 setting tool - RIH with CIBP, Set BP at 9,436' Elm - Pooh, Rig down Schlumberger 11 :30 - 12:30 1.00 DHB P DECOMP Rig up lines, Test 9 5/8 casing 9,436' to surface to 3,500 psi for 30 minutes on chart - ok 12:30 - 16:00 3.50 REMCM-C DECOMP Run 1" schedule 40 line pipe in 133/8 x 20" annulus, Tag up at Printed: 7/27/2004 10:43:04 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/14/2004 Rig Release: 7/21/2004 Rig Number: Spud Date: End: 7/612004 12:30 - 16:00 3.50 REMCM-C DECOMP 33' below ground level - Rig up Dowell, Cement 13318 x 20" to surface with 63 sx Arctic Set 1, yield .93 cf/sx, 10.5 bbls of slurry mixed at 15.7 ppg - Rig down lines and Dowell 16:00 - 16:30 0.50 STWHIP P WEXIT Pre-Job safety meeting on picking up 9 5/8 whipstock and millling assembly - Pull tools to rig floor 16:30 - 20:00 3.50 STWHIP P WEXIT Pick up Baker 9 5/8 Window Master whipstock and milling assembly - 8.00" Pilot mill, 8.00" Lower mill and 8.50" Upper mill - Program and orient MWD, surface test -ok - Pick up 9 - 6 1/4" Drill collars and 18 - 5" Hwt drill pipe from pipe shed for shear off weight 20:00 - 00:00 4.00 STWHIP P WEXIT TIH with whipstock picking up 4" 15.7# S-135 HT-40 drill pipe from pipe shed, Approx 5500' in hole at 2400 hrs 7/7/2004 00:00 - 03:30 3.50 STWHIP P WEXIT Continue TIH picking up 4" Drill pipe from pipe shed to 9,385' - Install blower hose & Fill pipe 03:30 - 04:00 0.50 STWHIP P WEXIT Orient whipstock to 91deg Right of high side, Tag BP at 9,443' dpm - Set anchor with 20k, Verify with 15k over pull - Shear off whipstock with 40k 04:00 - 05:30 1.50 STWHIP P WEXIT Displace wellbore to 10.8ppg LSND mud at 500 gpm 2100 psi - Clean out from under shale shakers, Obtain Slow pump rate with new mud system 05:30 - 09:00 3.50 STWHIP P WEXIT Mill window in 9 5/8 47# L-80 Casing 9,418 to 9,434' - Pilot mill finished at 9,448' - Mill with 100 rpm's, Pumping 530 gpm at 2650 psi 09:00 - 10:00 1.00 STWHIP P WEXIT Circulate hole clean with sweep - Recovered total 70 Lbs of metal while milling window 10:00 - 10:30 0.50 STWHIP P WEXIT Pull into casing - Test formation to 465 psi at 7,462' TVD with 10.8 ppg mud in hole for 12.0 ppg EMW FIT test - ok 10:30 - 16:30 6.00 STWHIP P WEXIT Pump slug - Pooh, Lay down mills and bumper sub - 8.5" Upper mill in gauge 16:30 - 17:30 1.00 STWHIP P WEXIT Pull wear bushing - Flush out wellhead and BOP stack, Function Bop and flush - Install wear bushing 17:30 - 20:30 3.00 STWHIP P WEXIT Make up Drilling BHA: Pick up RR 8.5" Smith M75 PDC bit jetted with 7-13's, Sperry 7" motor set at 1.5 degree bend, MWD/GR/PWD - Orient and program MWD - finish picking up BHA 20:30 - 23:30 3.00 STWHIP P WEXIT TIH to 9,339' - Fill pipe evey 30 stands 23:30 - 00:00 0.50 STWHIP P WEXIT Cut and Slip drill line 7/8/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Finish cutting drill line 124' - Service top drive and grease crown 01 :00 - 01 :30 0.50 STWHIP P WEXIT Orient to 90 deg right, Pass thru window at 9,418 to 9,434' without pumps, no problem - Ream under gauge hole to 9,448' 01 :30 - 21 :30 20.00 DRILL P INT1 Directional drill 9,448 to 7" Casing point at 10,374' in top of Sag River Formation as per on site Geologist - Ast 7.02 hrs, Art 5.01 hrs, Average Rop 77 ft/hr - Turn wellbore 19 to 77 Azimuth, Drop angle 47 to 14 degree - Maintain mud wt. at 10.8 ppg - Pumping 510 gpm at 3200 psi, Rotating at 80 - 100 rpm's with 8 -12 k torque 21 :30 - 23:00 1.50 DRILL P INT1 Circulate bottoms up for Sag River verification, Continue circulation until hole clean at two bottom up 23:00 - 00:00 1.00 DRILL P INT1 Short trip to window - no problem with slick BHA in open hole, Mad Pass for Gamma Ray tie -in 9,434 to 9,200' 7/9/2004 00:00 - 01 :00 1.00 DRILL P INT1 Finish Mad Pass to 9200' Printed: 7/27/2004 10:43:04 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/9/2004 01 :00 - 01 :30 0.50 DRILL P INT1 TIH, precautionary ream 70' to bottom at 10,374' - no fill 01 :30 - 03:30 2.00 DRILL P INT1 Circulate two bottom up, Spot liner running pill while pumping slug - Drop Sperry ESS 03:30 - 07:30 4.00 DRILL P INT1 Pooh to casing shoe, Monitor well, Remove blower hose, blow down top drive - Continue Pooh stand back drill pipe 07:30 - 10:30 3.00 DRILL P INT1 Lay down BHA, Flush MWD with water and down load, clear rig floor 10:30 - 11 :00 0.50 CASE P INT1 Rig up 7" YC elevators, Hand slips and power tongs 11 :00 - 13:30 2.50 CASE P INT1 Pre-Job safety meeting - Run 27jts 1112' of 7" 26# L -80 Btc-mod R-3 Liner, Make up Baker 7 x 9 5/8 'HMC' liner hanger with liner top packer and 6' Tie back sleeve 13:30 - 14:00 0.50 CASE P INT1 Circulate liner volume, Rig down power tongs and clear floor 14:00 - 19:00 5.00 CASE P INT1 TIH to top of window with liner on 4" drill pipe - Fill pipe every 1 0 stands 19:00 - 19:30 0.50 CASE P INT1 Circulate Drill pipe volume at 5 bpm 800 psi - full returns 19:30 - 20:30 1.00 CASE P INT1 Continue TIH 9,335 to 10,360' - No problem - Make up Baker Cementing head, Break circulation at 2 bpm and wash to bottom at 10,374' - Liner pick up wt 195K, S/O 130k 20:30 - 22:00 1.50 CEMT P INT1 Stage rate up from 2 bpm to 6 bpm at 1250 psi- Circulate one hole volume, did not reciprocate pipe 22:00 - 23:30 1.50 CEMT P INT1 Cement with Dowell as follows: Pump two bbl of water, Test lines to 4000 psi, Pump 30 bbls of mud push II spacer mixed at 11.8 ppg, Followed by 245 sx Class 'G' wi .3% D-65 + .4% D-167 + .07% B-155, yield 1.16 cf/sx, 50 bbls of slurry mixed at 15.8 ppg - Drop wiper dart with 10 bbls of water and displace with rig pump and 10.8 ppg mud - Bump plug to 3500 psi and set liner hanger with shoe at 10,373' - Top of liner at 9,237'- CIP at 2330 hrs 7/9/2004 - Floats ok - Full returns 23:30 - 00:00 0.50 CEMT P INT1 Rotate off of liner with 15 turns to right, Prressure drill string to 1000 psi and pull seal out of hanger - Circulate at 12.0 bbl 1 minute for 5 minutes, shut down and set liner top packer with all drill string wt. and Rotating, Packer set - Continue circulate excess off top of liner at 12 bbl/min 3000 psi 7/1 0/2004 00:00 - 01 :30 1.50 CEMT P INT1 Continue circulate excess off top of liner at 12 bpm 3000 psi- spacer back to surface but no cement - Circulate Two bottoms up - Pump slug - Lay down cementing head 01 :30 - 05:30 4.00 CEMT P INT1 Pooh with Baker liner running tool - Lay down tool 05:30 - 06:30 1.00 CASE C INT1 Pull wear bushing - Rig up Power tongs, 7" YC elevators, and hand slips 06:30 - 07:30 1.00 CASE C INT1 Test 7" Casing and Liner Lap to 3500 psi for 30 minutes on chart - ok 07:30 - 19:00 11.50 CASE C INT1 Make up Baker Ported Tie back seal assemby on 20' pup jt with Halliburton oriface Float collar - Run 222 jts 9197' 7" 26# L-80 Btc-mod R-3 casing 19:00 - 20:00 1.00 CASE C INT1 Change Bail to 15' casing bail for Cement head - Pick up Landing jt - Sting into Tie back sleeve at 9237' 20:00 - 22:00 2.00 CEMT C INT1 Make up Dowell cement head, Verify stung into tie back sleeve with 1000 psi, Pick up 4' and Break circulate and stage up to 6 bpm at 1600 psi - Circulate bottom up at 6 bpm with pressure decreasing to 1400 psi - Loss 60k weight on indicator due to hydraulic pressure lifting string 22:00 - 00:00 2.00 CEMT C INT1 Cement with Dowell as follows: Pump 5 bbls of water, Test lines to 4000 psi, pump 25 bbls of water, 35 bbls of high vis Printed: 7/27/2004 10:43:04 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/10/2004 22:00 - 00:00 2.00 CEMT C INT1 water spacer, 60 bbls of Diesel, 10 bbls of Mud Push II spacer mixed at 11.8 ppg, Drop bottom plug, Cement with 370 sx Class 'G' wI .60% D-167 + .35% D-65 + .02% C359 + 8.0% D-20 + .15% XE920 - Yield 1.80 cf/sx - 118 bbls of slurry mixed at 13.5 ppg, Tailed with 140 sx Class 'G' wI .07% B-155 + .4% D167 + .3% D65, Yield 1.16 cf/sx, 29 bbl slurry mixed at 15.8 ppg - Drop top plug with 10 bbls of water - Displace with rig pump and 10.8 ppg mud 7/11/2004 00:00 - 01 :00 1.00 CEMT C INT1 Finish displacing with 10.8 ppg mud at 6 bpm 900 psi - Bump plug to 1500 psi, - CIP at 0050 hrs 7/11/04 - Bled off pressure, sting into tie back sleeve at 9,237' - ok 01 :00 - 01 :30 0.50 CEMT C INT1 Rig down Dowell cement head - Suck out mud from inside 7" casing 01 :30 - 02:30 1,00 WHSUR C INT1 Break and Pick up BOP stack 02:30 - 03:00 0.50 WHSUR C INT1 Set FMC 7 x 13518 slips with intergal pack-off, 200k net on slips 03:00 - 04:30 1.50 WHSUR C INT1 Rig up Cameron Cold casing cutter, Cut and bevel 7" Casing 04:30 - 05:30 1.00 WHSUR C INT1 Nipple up FMC 135/8 x 135/8 5K Tubing head - Test pack-off to 80% of collaspe of 7" 4300 psi 05:30 - 07:30 2.00 WHSUR C INT1 Nipple up Bop stack 07:30 - 09:30 2.00 WHSUR C INT1 Change casing bails to Drill pipe, Pick up Drill pipe elevators, - Clear rig floor 09:30 - 10:30 1.00 WHSUR C INT1 Install Test plug, Test break between tubing head and bop stack to 250 low / 3500 high - Pull test plug - Install wear bushing 10:30 - 13:30 3.00 DRILL P PROD1 Make up 61/8" hole BHA: Make up Smith 6 1/8 XR20 insert bit w/3-12's, Pick up Sperry 5" motor set at 1.76 deg bend and ABI, MWD/GR, Orient and program MWD - Finish pick up BHA 13:30 - 16:00 2.50 DRILL P PROD1 TIH picking up 99 jts of 4" drill pipe from pipe shed 16:00 - 16:30 0.50 DRILL P PROD1 Service top drive and Grease Crown - change out Sperry depth sensor 16:30 - 18:30 2.00 DRILL P PROD1 TIH with 4" drill pipe out of derrick to 9,076 18:30 - 19:30 1.00 DRILL P PROD1 Break circulate and wash down to float collar of Tie back sting at 9,216' - Drill float collar and wash to 9,263' 19:30 - 20:30 1.00 DRILL P PROD1 TIH 9,263 to 10,260' - Wash down and tag landing collar at 10,288' 20:30 - 21 :30 1.00 DRILL P PROD1 Test casing to 3500 psi for 30 minutes on chart - Lost 200 psi in 30 minutes - ok 21 :30 - 22:30 1.00 DRILL P PROD1 Drlg float equipment, & cement to shoe at 10,373' - Drill out shoe and one ft new hole to 10,375' 22:30 - 00:00 1.50 DRILL P PROD1 Pump 100 bbls water spacer + 40 bbls pill wth 2 drum of EP mud lube followed by 8.4 ppg New Flo-Pro drill in mud system - Displace at 300 gpm rotating at 30 rpm's 7/12/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Finish displacing to 8.4 ppg Flo-Pro mud system - Clean out from under shale shakers 01 :30 - 02:00 0.50 DRILL P PROD1 Drill 20' of new formation to 10,394' 02:00 - 02:30 0.50 DRILL P PROD1 Test formation to 693 psi at 8330 Tvd with 8.4 ppg mud in hole, 10.0 ppg EMW - ok 02:30 - 00:00 21.50 DRILL P PROD1 Drill ahead 10,394 to 10,870' - Art 5.53 hrs, Ast 7.90 hrs, Average Rop 36.93 ftlhr - Pumping 270 gpm's at 2250 psi on bottom, 2000 psi off - Rotate at 45 rpm's with 5 - 7000 ftllbs torque - P/U 180k, S/O 140k, RT 160k - Turn welbore from 77 deg Azimuth to 11 deg, Build angle 14 to 28 degrees - Maintain Printed: 7/27/2004 10:43:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/12/2004 02:30 - 00:00 21.50 DRILL P PROD1 mud wt at 8.4 ppg and 4% Lubricate and run bead to aid sliding - Sliding hard going 7/13/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Continue directional drilling 10,870 to 10,882 - Art 0 hrs, Ast .27 hrs - Not getting needed dog leg for angle build, and bit quit drilling 01 :30 - 07:00 5.50 DRILL P PROD1 Pump Slug - Pooh for Bit - Bit 1/4" out of gauge 07:00 - 09:00 2.00 DRILL P PROD1 Change out MWD to satisfy JORPS, Remove stablizer and add kick pad to Motor, leave motor set at 1.76 degree bend, Change bit and orient MWD 09:00 - 13:30 4.50 DRILL P PROD1 TIH, Fill pipe every 30 stands, Check shot survey at 10,664' - Wash 30' to bottom at 10,882' 13:30 - 00:00 10.50 DRILL P PROD1 Directional drill 1 0,882 to 11,269' - Art 2.45 hrs, Ast 5.47 hrs, Average rop 48.8 ftIhr - Build angle 28 to 85 deg, Turn wellbore to left 11 to 347 deg Azimuth - Maintain mud wt. 8.54 -8.5 ppg - Pumping 270 - 280 gpm at 2400 psi - P/U 185, SIO 135, Rt 160 - 35 rpm's with 6 -7K torque 7/14/2004 00:00 - 08:00 8.00 DRILL P PROD1 Continue Directional drilling 11,269 to 11,506' - Horizontal at 8,988 Tvd - Art 3.69 hrs, Ast 2.39 hrs, Average Rop 38.9 ftIhr - Pumping 278 gpm at 2400 psi - Wob 20-25, Rotating at 35 rpm's with 7,000 ftIlbs torque - Pump sweep around as drilling last 30' 08:00 - 10:00 2.00 DRILL P PROD1 Pooh wet to 7" shoe - Monitor well 10:00 - 10:30 0.50 DRILL P PROD1 Drop bar and open pump out sub in BHA, Pump slug 10:30 - 12:00 1.50 DRILL P PROD1 Pooh to 5,995' 12:00 - 12:30 0.50 DRILL P PROD1 Service rig, Adjust Brakes 12:30 - 14:30 2.00 DRILL P PROD1 Continue Pooh to BHA at 300' 14:30 - 18:30 4.00 DRILL P PROD1 Change BHA: Pick up Security 6 1/8" FM2634 jetted with 3-12's, Blank off jet in top of motor and set motor at 1.5 deg bend, MWD/GR/RESI DENI Neutron - Orient motor and load source 18:30 - 19:00 0.50 DRILL P PROD1 Service top drive and grease crown 19:00 - 19:30 0.50 DRILL N RREP PROD1 Rig Repair, Repair Iron Roughneck 19:30 - 23:30 4.00 DRILL P PROD1 TIH, Fill pipe evey 3000' - Taking wt. at 10,690' 23:30 - 00:00 0.50 DRILL P PROD1 Ream 10,690 to 10,876 - New BHA not wanting to slide around high dogleg section 7/15/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Continue Ream 10,876 to bottom at 11,506' - Taking as much as 20k and rotation to push BHA around dogleg 01 :30 - 00:00 22.50 DRILL P PROD1 Directional drill as per on site geologist 11,506 to 12,184' - Art 2.91 hrs, Ast 6.77 hrs, Average Rop 70 ftIhr - Pumping 310 to 320 gpm at 3000 psi - Sliding difficult, Hanging up, Differential sticking, Stalling out - using 4 -5% Lubricant and Lubri Beads to aid sliding - P/U 180k, S/O 130, RT 155k 7/16/2004 00:00 - 16:00 16.00 DRILL P PROD1 Continue directional drill as per on site geologist 12,184 to 12,650' - Build angle to 94 deg and turn Azimuth 333 to 327 deg - Drop angle back to 90 deg - Sliding difficult, 6% Lubricant and Lubri Beads to aid sliding 16:00 - 17:00 1.00 DRILL P PROD1 Short trip to 11,531' - Attempt to improve hole for sliding - Tight at 12,262 - 12,235' 35k over pull 17:00 - 19:00 2.00 DRILL P PROD1 Continue directional drill 12,650 to TD at 12,770' - total for day Art 3.81 hrs, Ast 5.79 hrs, Average Rop 61 ftlhr - Pumping 320 gpm at 3300 psi, Rotating at 100 rpm's with 6 -8,000 ftIlbs torque 19:00 - 20:30 1.50 DRILL P PROD1 Pump High vis sweep and circulate hole clean with two Printed: 7/27/2004 10:43:04 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/16/2004 19:00 - 20:30 1.50 DRILL P PROD1 bottoms up pumping 325 gpm, Rotating at 100 rpm's 20:30 - 21 :30 1.00 DRILL P PROD1 Short trip from 12,770 to 11,170' - Tight at 12,250 - 12,235' 35k over pull 21 :30 - 22:30 1.00 DRILL P PROD1 Continue pooh - MAD PASS at 180 ftIhr 11,170 to 10,970' 22:30 - 23:00 0.50 DRILL P PROD1 Finish pooh to 7" Shoe at 10,373' - 25k over pull at 10,729 & 10,635' 23:00 - 00:00 1.00 DRILL P PROD1 Cut and slip drill line 7/17/2004 00:00 - 00:30 0.50 DRILL P PROD1 Adjust Brakes 00:30 - 01 :00 0.50 DRILL P PROD1 Service top drive and grease crown 01 :00 - 02:00 1.00 DRILL P PROD1 TIH, +1- 20k drag at 10,630 to 10,730 & 11,030 to 11,060' 02:00 - 03:30 1.50 DRILL P PROD1 Pump high vis sweep and circulate hole clean with two bottom up - Pump 100 bbls of new 8.4 ppg Flo-Pro mud with 6% Lubricants and spot in open hole 03:30 - 11 :30 8.00 DRILL P PROD1 Pooh for 4 1/2" Production liner, No problem in open hole, Pump slug at caisng shoe - Continue pooh - Lay down 78 jts of 4" drill pipe - Lay down BHA, Remove source and down load LWD tools - Clear rig floor 11 :30 - 12:00 0.50 CASE P LNR2 Rig up Nabors Casing power tong, 4 1/2" 'YT' elevators and hand slips 12:00 - 16:30 4.50 CASE P LNR2 Pre-Job safety meeting with drill crew and service personnel - Run 61 jts 4 1/2" 12.6# L-80 IBT liner 2,571' - Make up Baker 7 x 4 1/2" 'HMC' liner hanger with liner top packer and 6' tie back sleeve 16:30 - 17:00 0.50 CASE P LNR2 Circulate liner volume - Clear rig floor 17:00 - 21 :00 4.00 CASE P LNR2 TI H with 4 1/2" liner to 7" casing shoe at 10,373' on 4" Drill pipe, Fill pipe every 10 stands 21 :00 - 21 :30 0.50 CASE P LNR2 Circulate pipe volume at 6 bpm 1030 psi - P/U 165, Slo 130 21 :30 - 22:30 1.00 CASE P LNR2 TIH open hole with liner to 12,740' - No problem 22:30 - 23:30 1.00 CASE P LNR2 Make up Baker Top drive cement head and break circulation at 2 bpm 900 psi 23:30 - 00:00 0.50 CASE P LNR2 Wash down 12,740 to bottom at 12,770' - Stage pump up 2 bpm to 6 bpm at 1800 psi 7/18/2004 00:00 - 01 :30 1.50 CEMT P LNR2 Continue circulate liner at 6 bpm pressure decreased 1800 to 1600 psi, Reciprocate liner 15' strokes - Batch mix cement- Pre-job safety meeting wlith drill crew and Dowell 01 :30 - 03:00 1.50 CEMT P LNR2 Cement production liner as follows: Pump 5 bbls of water, test lines to 4500 psi, Pump 15 bbls CW100 + 25 bbls Mud push II spacer mixed at 9.5 ppg, followed by 312 sx Class 'G' w/2 gal/sx GASBLOK + .17 % D-800 + .42% D-65 - Yield 1.17 cf/sx - 65 bbls slurry mixed at 15.8 ppg - Wash out Cement liner, Drop Wiper dart and displace with 60 bbls of Perf pill followed by 80 bbls of 8.5 ppg Flo-Pro mud - Bump plug to 3500 psi and set liner hanger - Check floats -ok, CIP at 0250 hrs 7/18/2004- Reciprocate pipe entire job - Top of liner at 10,222' - Shoe at 10,769' 03:00 - 04:00 1.00 CEMT P LNR2 Rotate off liner hanger with 15 turns to right, Pressure drill pipe to 1000 psi and pull seal out of hanger, Circulate 58 bbls at 11.6 bpm - slow pumps to 6 bpm, Set liner top packer with 50K down wt., Rotate down on top of liner top - circulate two bottom up at 12.0 bpm 3000 psi - 25 bbls spacer and approx 20 bbls of cement to surface - 04:00 - 05:30 1.50 CEMT P LNR2 Displace well bore to Seawater at 12.6 bpm 3500 psi - Reciprocate pipe, - Flush surface lines, Clean from under Printed: 7/27/2004 10:43:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/18/2004 04:00 - 05:30 1.50 CEMT P LNR2 shakers, Lay down Cement head 05:30 - 10:00 4.50 CEMT P LNR2 Pooh, Lay down Baker running tool - Clear rig floor 10:00 - 11 :00 1.00 PERFOB P OTHCMP Pre-Job Safety meeting with drill crew and Schlumberger TCP personnel on perforating - Rig floor for 2 7/8 guns 11 :00 - 11 :30 0.50 PERFOB P OTHCMP Test liner lap and casing to 3500 psi for 30 minutes on chart- ok 11 :30 - 14:00 2.50 PERFOB P OTHCMP Pick up 1,408.48' of 2 7/8" guns with 695' Loaded with HSD 2906PJ charge at 4 spf 60 deg phasing 14:00 - 16:00 2.00 PERFOB P OTHCMP Pick up 36 jts 2 7/810.4# PAC drill pipe with make up torque of 2900 ft/lbs - Clear rig floor 16:00 - 20:30 4.50 PERFOB P OTHCMP TIH with guns on 4" drill pipe - Tag Landing collar at 12,682'- Pick up 7' and position bottom shot at 12,675' dpm 20:30 - 00:00 3.50 PERFOB N WAIT OTHCMP Hydrocarbon release in C-pad manifold building - At the request of GPB operations, Secure well, suspend operation, account for all personnel and stand-by 7/19/2004 00:00 - 13:00 13.00 PERFOB N WAIT OTHCMP Continue with operation suspended as per GPB operations due to hydrocarbon releasing in C-pad manifold building - Pad secured all personnel accounted for 13:00 - 13:30 0.50 PER FOB P OTHCMP Pressure up to 3000 psi, Bled off pressure and open hyd rill , Wait 10 minutes for guns to fire - Perforate over balanced with 27/8" guns, HSD 2906PJ charge 4spf at 60 1120 deg phasing, Perf interval: 11,330-11,515, 11,680 -11,750, 11,770 -11875, 12,010 -12,045, 12,390 - 12,450, 12,465 -12,675' total 695' 13:30 - 14:00 0.50 PERFOB P OTHCMP Pull guns above top perf, Standing back 15 stands 14:00 - 14:30 0.50 PERFOB P OTHCMP Monitor well, Fluid loss to formation 4 bph, Pump slug 14:30 - 23:30 9.00 PERFOB P OTHCMP Pooh lay down drill pipe and 36 jts 2 7/8 Pac drill pipe 23:30 - 00:00 0.50 PER FOB P OTHCMP Pre-Job safety meeting, Lay down Perf guns 7/20/2004 00:00 - 05:00 5.00 PER FOB P OTHCMP Continue Laying down perf guns, All shots fired - Clear and Clean rig floor 05:00 - 05:30 0.50 RUNCOMP RUNCMP Pull wear bushing 05:30 - 07:00 1.50 RUNCOMP RUNCMP Rig up stack power tongs and compensator for 4 1/2" chrome completion 07:00 - 07:30 0.50 RUNCOMP RUNCMP PU WLEG, 'XN', 'X', S-3 Packer, and 'X' assemblies. All connections below packer are Bakerloc'd. 07:30 - 19:00 11.50 RUNCOMP Final Depths: WLEG - 10,230' XN (3.725" ID) - 10,218' X (3.813" ID) -10,197' S-3 Packer - 10,173' X (3.813" ID) - 10,152' RUNCMP PU remaining 4-1/2" 12.6#, 13Cr Vam Top completion with 4 x GLMs and 'X' Nipple to 10,230'. 19:00 - 20:30 1.50 RUNCOMP Final Depths: 4.5" x 1" KBG-2 w/DV and BK latch - 10,084' 4.5" x 1" KBG-2 w/DV and BK latch - 8,378' 4.5" x 1" KBG-2 w/DV and BK latch - 5,966' 4.5" x 1" KBG-2 w/DCK Shear Valve and BEK latch - 3,260' X (3.813" ID) - 2,109' RUNCMP Spaceout completion. LD 2 joints of 4-1/2" tubing. PU 2.07', Printed: 7/27/2004 10:43:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-17B C-17B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/14/2004 7/21/2004 Spud Date: End: 7/20/2004 19:00 - 20:30 1.50 RUNCOMP RUNCMP 2.06' and 18.79' pups. LD compensator and change out elevators. PU landing joint, MU hanger and land tubing. RILDS. Ran a total of 238 joints of 4-1/2". Utilized Jet Lube Seal Guard Thread Lubricant 20:30 - 23:00 2.50 RUNCOMP RUNCMP Reverse circulate 155 bbls of clean seawater, 122 bbls seawater wI corrosion inhibitor followed by 60 bbls of clean seawater @ 3 bpm, 300 psi. 23:00 - 00:00 1.00 RUNCOMP RUNCMP Drop ball and rod and allow to seat in RHC-M in 'XN' profile @ 10,218'. Pressure up on the tubing to 3,500 psi to set the packer. Hold pressure and plot on chart for 30 minutes - good test. 7/21/2004 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Bleed off tubing pressure to 1,500 psi. Pressure up on the annulus to 3,500 psi. Hold pressure and plot on chart for 30 minutes - good test. Bleed off tubing pressure and observe indication of DCK shear. Dry rod set TWC. Clear floor. 01 :00 - 03:00 2.00 BOPSUF P RUNCMP ND BOPE. 03:00 - 06:00 3.00 WHSUR P RUNCMP NU and test Tree to 5,000 psi. RU DSM and pull TWC with lubricator 06:00 - 08:00 2.00 WHSUR P RUNCMP RU pumping service, test lines to 3500 psi, pump 73 bbls of 50 degree diesel down annulus at 800 psi, 3 bpm, U-tube to tubing. Freeze protect well to 2100' on tbg and annulus 08:00 - 08:30 0.50 WHSUR P RUNCMP Set BPV, test f/ below to 1000 psi 08:30 - 09:30 1.00 WHSUR P RUNCMP Remove secondary annulus valve, secure well, release rig at 0930 hours on 7/21/04 Printed: 7/27/2004 10:43:04 AM e . 31-Jul-04 AOGCC ~as6n 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-17 B ~(j vf -0 tfi Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the * .PTT and * .PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,399.50' MD 9,418.00' MD 12,770.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date J-. /J; .2.~l11 Please call me at 273-3545 if you have any questions or concerns. Regards, /7/) 1\. /1 I Signed ~ ! O~ William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA C Pad C-17B Job No. AKMW3164914, Surveyed: 16 July, 2004 Survey Report 29 July, 2004 Your Ref: API 500292043902 Surface Coordinates: 5961208.00 N, 664128.00 E (70018' 01.2578N N, 148040' 14.2869N W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 961208.00 N, 164128.00 E (Grid) Surface Coordinates relative to Structure Reference: 3953.86 N, 1664.73 E (True) Kelly Bushing Elevation: 61. 70ft above Mean Sea Level Kelly Bushing Elevation: 61.70ft above Project V Reference Kelly Bushing Elevation: 61.70ft above Structure Reference SpE!ï'ï'Y-SUí1 DRIL.LING SeRViCeS A Halliburton Company DEFINITIVE e e Survey Ref: svy4310 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-1TB Your Ref: API 500292043902 Job No. AKMW3164914, Surveyed: 16 July, 2004 BPXA North Slope Alaska Measured True 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) (0/100ft) 9399.50 47.120 19.700 7385.18 7446.88 4106.31 N 1375.32 E 5965343.37 N 665413.30 E 4267.73 Tie On Point MWD Magnetic 9418.00 47.090 19.760 7397.77 7459.47 4119.06 N 1379.90 E 5965356.22 N 665417.60 E 0.288 4281.04 Window Point 9461.15 45.930 24.130 7427.48 7489.18 4148.09 N 1391.58E 5965385.50 N 665428.64 E 7.823 4311.50 9492.47 43.350 27.590 7449.76 7511.46 4167.89 N 1401.16 E 5965405.50 N 665437.79 E 11.316 4332.53 e 9525.19 40.410 31 .480 7474.12 7535.82 4186.90 N 1411.90 E 5965424.74 N 665448.11 E 11.985 4352.95 9554.33 37.760 31.710 7496.74 7558.44 4202.55 N 1421.53E 5965440,59 N 665457.39 E 9.108 4369.88 9585.73 35.650 34.250 7521.92 7583.62 4218.29 N 1431.73 E 5965456.56 N 665467.25 E 8.277 4387.00 9617.29 32.780 37.680 7548.01 7609.71 4232.66 N 1442.13E 5965471.15 N 665477.34 E 10.953 4402.78 9647.51 29.810 40.380 7573.84 7635.54 4244.86 N 1452.00 E 5965483.56 N 665486.94 E 10.866 4416.34 9678.24 27.000 42.790 7600.86 7662.56 4255.80 N 1461.69E 5965494.71 N 665496.39 E 9.874 4428.63 9710.32 24.150 43.380 7629.80 7691.50 4265.92 N 1471.15 E 5965505.03 N 665505.62 E 8.919 4440.06 9741.60 21.820 44.040 7658.59 7720.29 4274.75 N 1479.59 E 5965514.04 N 665513.86 E 7.494 4450.07 9774.41 19.710 45.320 7689.27 7750.97 4283.02 N 1487.76 E 5965522.50 N 665521.85 E 6.578 4459.50 9803.32 17.800 48.790 7716.64 7778.34 4289.36 N 1494.55 E 5965528.98 N 665528.50 E 7.649 4466.80 9834.05 16.620 52.110 7746.00 7807.70 4295.15 N 1501.55 E 5965534.93 N 665535.38 E 4.995 4473.59 9866.60 16.050 55.590 7777.23 7838.93 4300.56 N 1508.94 E 5965540.49 N 665542.64 E 3.479 4480.05 9895.77 15.360 61.310 7805.32 7867.02 4304.69 N 1515.66 E 5965544.77 N 665549.27 E 5.808 4485.16 9925.95 14.940 67.920 7834.45 7896.15 4308.07 N 1522.77 E 5965548.30 N 665556.30 E 5.887 4489.58 9960.23 14.720 69.920 7867.59 7929.29 4311.23 N 1530.95 E 5965551.64 N 665564.42 E 1.625 4493.95 10018.93 14.860 76.930 7924.35 7986.05 4315.49 N 1545.29 E 5965556.21 N 665578.66 E 3.056 4500.34 10069.83 14.520 78.250 7973.59 8035.29 4318.27 N 1557.90 E 5965559.26 N 665591.20 E 0.937 4505.00 e 10112.14 14.280 78.860 8014.57 8076.27 4320.35 N 1568.21 E 5965561.58 N 665601.47 E 0.671 4508.63 10161.38 13.900 79.420 8062.32 8124.02 4322.61 N 1579.98 E 5965564.09 N 665613.19 E 0.820 4512.66 10206.50 13.710 79.390 8106.14 8167.84 4324.59 N 1590.56 E 5965566.30 N 665623.72 E 0.421 4516.22 10258.72 15.090 78.070 8156.72 8218.42 4327.14 N 1603.30 E 5965569.13 N 665636.40 E 2.716 4520.68 10299.92 14.730 77.480 8196.53 8258.23 4329.38 N 1613.66 E 5965571.60 N 665646.71 E 0.948 4524.47 10374.49 13.940 77.310 8268.78 8330.48 4333.41 N 1631.67 E 5965576.02 N 665664.63 E 1.061 4531.19 10409.86 13.380 77.230 8303.15 8364.85 4335.25 N 1639.82 E 5965578.03 N 665672.74 E 1.584 4534.25 10457.80 13.4 70 76.170 8349.78 8411.48 4337.81 N 1650.65 E 5965580.83 N 665683.51 E 0.547 4538.43 10502.21 14.880 73.990 8392.84 8454.54 4340.62 N 1661.16 E 5965583.87 N 665693.95 E 3.394 4542.80 29 July, 2004 - 10:53 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-17B Your Ref: API 500292043902 Job No. AKMW3164914, Surveyed: 16 July, 2004 BPXA North Slope Alaska Measured True 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) (0/10aft) 10532.46 16.050 72.160 8421.99 8483.69 4342.97 N 1668.87 E 5965586.39 N 665701.61 E 4.190 4546.30 10565.09 17.830 71.190 8453.20 8514.90 4345.97 N 1677.90 E 5965589.58 N 665710.57 E 5.523 4550.63 10595.08 17.620 70.290 8481.77 8543.47 4348.98 N 1686.51 E 5965592.78 N 665719.12 E 1.151 4554.92 10627.56 19.160 53.700 8512.61 8574.31 4353.79 N 1695.45 E 5965597.79 N 665727.94 E 16.736 4561.04 10656.83 22.170 43.410 8540.00 8601.70 4360.65 N 1703.12 E 5965604.81 N 665735.46 E 16.079 4568.99 e 10688.94 23.530 37.770 8569.60 8631.30 4370.12 N 1711.21 E 5965614.46 N 665743.34 E 8.024 4579.58 10720.24 25.460 31.850 8598.08 8659.78 4380.78 N 1718.59 E 5965625.27 N 665750.49 E 9.969 4591.23 10753.90 27.090 27.260 8628.27 8689.97 4393.74 N 1725.91 E 5965638.39 N 665757.53 E 7.736 4605.16 10783.71 26.590 19.070 8654.88 8716.58 4406.08 N 1731.21 E 5965650.85 N 665762.55 E 12.509 4618.16 10816.83 28.050 7.870 8684.32 8746.02 4420.81 N 1734.70 E 5965665.65 N 665765.72 E 16.111 4633.25 10848.31 28.980 357.110 8712.00 8773.70 4435.77 N 1735.33 E 5965680.62 N 665766.02 E 16.562 4648.13 10876.38 31.920 349.640 8736.20 8797.90 4449.87 N 1733.65 E 5965694.68 N 665764.04 E 17.059 4661.81 10910.24 38.140 345.360 8763.92 8825.62 4468.82 N 1729.39 E 5965713.52 N 665759.37 E 19.741 4679.89 10941.35 43.810 343.490 8787.40 8849.10 4488.45 N 1723.90 E 5965733.03 N 665753.45 E 18.645 4698.46 10970.54 46.980 346.310 8807.90 8869.60 4508.51 N 1718.50 E 5965752.97 N 665747.61 E 12.853 4717.46 11004.38 52.050 349.130 8829.86 8891.56 4533.65 N 1713.05 E 5965777.99 N 665741.61 E 16.265 4741.48 11034.35 54.670 350.360 8847.75 8909.45 4557.32 N 1708.77 E 5965801.55 N 665736.82 E 9.341 4764.22 11063.53 57.630 349.820 8864.00 8925.70 4581.18 N 1704.60 E 5965825.32 N 665732.13 E 10.260 4787.18 11096.41 63.110 348.340 8880.25 8941.95 4609.23 N 1699.18 E 5965853.25 N 665726.10 E 17.119 4814.07 11124.67 66.720 347.220 8892.23 8953.93 4634.24 N 1693.76 E 5965878.13 N 665720.13 E 13.269 4837.97 11157.64 70.910 347.330 8904.14 8965.84 4664.22 N 1686.99 E 5965907.96 N 665712.71 E 12.712 4866.57 11188.29 74.640 347.220 8913.22 8974.92 4692.77 N 1680.54 E 5965936.36 N 665705.64 E 12.174 4893.81 e 11219.19 80.130 346.360 8919.96 8981.66 4722.12 N 1673.65 E 5965965.55 N 665698.11 E 17.973 4921.76 11250.80 85.800 345.940 8923.83 8985.53 4752.57 N 1666.14 E 5965995.82 N 665689.94 E 17.986 4950.71 11281.77 89.380 345.190 8925.13 8986.83 4782.53 N 1658.43 E 5966025.61 N 665681.57 E 11.810 4979.15 11314.09 89.260 344.920 8925.52 8987.22 4813.75 N 1650.10 E 5966056.64 N 665672.56 E 0.914 5008.74 11344.06 88.400 341.830 8926.13 8987.83 4842.46 N 1641.53 E 5966085.16 N 665663.36 E 10.700 5035.81 11437.48 89.940 337.930 8927.48 8989.18 4930.15 N 1609.40 E 5966172.13 N 665629.33 E 4.488 5117.60 11463.44 89.880 337.320 8927.52 8989.22 4954.15 N 1599.52 E 5966195.91 N 665618.93 E 2.361 5139.82 11513.16 90.250 337.830 8927.47 8989.17 5000.11 N 1580.55 E 5966241.44 N 665598.96 E 1.267 5182.36 11556.76 90.370 338.150 8927.23 8988.93 5040.54 N 1564.21 E 5966281.50 N 665581.74 E 0.784 5219.82 11647.83 92.340 337.400 8925.08 8986.78 5124.81 N 1529.78 E 5966365.00 N 665545.47 E 2.315 5297.88 11740.68 92.900 337.600 8920.83 8982.53 5210.50 N 1494.28 E 5966449.90 N 665508.12 E 0.640 5377.18 11834.92 92.160 336.970 8916.67 8978.37 5297.35 N 1457.93 E 5966535.93 N 665469.87 E 1.031 5457.48 11929.26 91.600 337.650 8913.58 8975.28 5384.34 N 1421.56 E 5966622.10 N 665431.61 E 0.933 5537.93 29 July, 2004 - 10:53 Page 3 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-17B Your Ref: API 500292043902 Job No. AKMW3164914, Surveyed: 16 July, 2004 BPXA North Slope Alaska Measured True 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) (0/100ft) 12022.34 88.890 339.030 8913.18 8974.88 5470.84 N 1387.21 E 5966707.83 N 665395.38 E 3.267 5618.19 12087.10 90.310 338.910 8913.63 8975.33 5531.28 N 1363.97 E 5966767.75 N 665370.82 E 2.201 5674.39 12115.76 90.000 338.830 8913.56 8975.26 5558.01 N 1353.64 E 5966794.25 N 665359.91 E 1.117 5699.24 12174.82 90.990 333.660 8913.05 8974.75 5612.05 N 1329.85 E 5966847.76 N 665334.96 E 8.912 5749.03 12207.55 91.360 331.660 8912.37 8974.07 5641.11 N 1314.83 E 5966876.49 N 665319.30 E 6.213 5775.48 e 12241.55 91.790 328.340 8911.44 8973.14 5670.54 N 1297.83 E 5966905.54 N 665301.67 E 9.843 5801.98 12300.43 92.41 0 326.800 8909.28 8970.98 5720.21 N 1266.28 E 5966954.50 N 665269.04 E 2.818 5846.26 12393.79 94.260 325.720 8903.85 8965.55 5797.71 N 1214.52 E 5967030.85 N 665215.59 E 2.294 5914.99 12487.35 94.880 328.530 8896.39 8958.09 5876.02 N 1163.90 E 5967108.04 N 665163.27 E 3.066 5984.69 12577.98 94.080 327.490 8889.32 8951.02 5952.65 N 1116.03 E 5967183.61 N 665113.75 E 1 .445 6053.15 12674.63 92.040 325.070 8884.16 8945.86 6032.92 N 1062.46 E 5967262.69 N 665058.43 E 3.272 6124.33 12701.18 90.930 327.750 8883.47 8945.17 6055.02 N 1047.78 E 5967284.47 N 665043.27 E 10.922 6143.94 12770.00 90.930 327.750 8882.35 8944.05 6113.22 N 1011.06 E 5967341.85 N 665005.29 E 0.000 6195.88 Projected Survey All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 8.750° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12770.00ft., The Bottom Hole Displacement is 6196.26ft., in the Direction of 9.391 ° (True). e 29 July, 2004 - 10:53 Page 4 of5 DrillQuest 3.03.06.002 · Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-17B Your Ref: API 500292043902 Job No. AKMW3164914, Surveyed: 16 July, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9399.50 9418.00 12770.00 7446.88 7459.47 8944.05 4106.31 N 4119.06 N 6113.22N 1375.32 E 1379.90 E 1011.06E Tie On Point Window Point Projected Survey e Survey tool program for C-178 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9399.50 0.00 9399.50 7446.88 12770.00 7446.88 BP High Accuracy Gyro - Boss-Gyro (C-17) 8944.05 MWD Magnetic (C-17B) e 29 July, 2004 - 10:53 Page 50f5 Dril/Quest 3.03.06.002 TREE = 6" rvk:EVOY WI3..LHEAD = FMC 'Ä~ëTÛA TOR';,-,m . ···OTIS ~KB~'ÊI.EV ;^' ,~n~~<. ,.. "~ä2.15' mSF. ELE\Î--; 34.3' KaP ;_.~_m_ 3300' MaX Angíe =95m@ 12487' Datum MD = 10910' Datum TVD = 8800' SS e 19-5/8" DV PKR H 113-3/8" CSG, 72#, L-80, 10 = 12.347" H 2584' 2662' 17" SCAB LNR, 26#, L-80, 10 = 6.276" H 25'- 9273' IMinimum ID = 3.725" @ 10215'1 4-112" HES XN NIPPLE I CIBP 1-1 9436' 17" BOT LNR HGR H 9956' 19-518" CSG, 47#, L-80, 10 = 8.681" H 10496' PERFORA TlON SLMfv\I\RY REF LOG: MND/ LWD ON JULY 2004 ANGLE AT TOP PERF: 89 @ 11300' I\bte: Refer to A"oductbn DB for historical perf data SIZE SA' INlERVAL OpnlSqz DA TE 2-7/8" 4 11300-11515 0 07/18iV4 2-7/8" 4 11680-11750 0 07/18iV4 2-7/8" 4 11770 -11875 0 07/18iV4 2-7/8" 4 12010 - 12045 0 07/18iV4 2-7/'(5' 4 12390 - 12450 0 07/18iV4 2-7/'(5' 4 12465 - 12675 0 07/18iV4 17" LNR, 29 #, L-80, .0371 bpf, 10 = 6.184" H 11704' ; 12-718" LNR. 6.16#, L-80, .0058 bpf,lD =2.37" H 12760' I e C-17B SAFETY NOTES: 4-1/2" CHROMETBG. 2108' H4-1/Z' HES X NIP, 10= 3.813" I ST MD TVD 4 3257 3254 3 5964 5260 2 8376 6746 1 10081 8046 GAS LIFT MANDRELS DEV TYPE VL V LATCH 9 CArvcO DOME BB< 53 CArvcO SlO BK 46 KBG-2 DI\i1Y BK 14 KBG-2 DI\i1Y BK PORT DA lE 16 08109104 20 08109/04 07/20/04 07/20/04 9237' WT'TIEBAO< SLY 9245' H 9-5/8" X 7" BKR LNR TOP PKR MLLOUTWINDOW 9418' - 9434' 10150' 1-{4-1/2" HESXNP, 10=3.813" I i 10171' 1-7"X4-112"BKRS-3PKRI ... I 10194' 10215' 1 0226' H4-1/2" HESX NIP,ID =3.813" I H4-1/2" HES XN NIP, 10 = 3.725" I H4-1/2"TBG, 12.6#, 13-CR. 1.0152 bpf, 10 = 3.958" 1-4-1/2" WLEG, 10 = 3.958" I H T' X 5" BKR LNR TOP PKR I HT' LNR. 26#, L-80, .0383 bpf, 110 = 6.276" .... 10228' 10229' 10373' .. "v\I'o I I I .. - q ~ ~ I 12682' H FßlD I 14-112" LNR. 12.6#, L-80, .0152 bpf, 10 = 3.958" H 12769' DA lE REV BY COMWENTS 05110/80 ORIGINAL COM PlETION 02/22/85 RWO 03115198 CTD SlDErRACK (C-17A) 07/21/04 DAV/KAK'RIG SlDErRACK(C-17B) 0&'09/04 JLJIlLP GLV CiO 0&'17104 lLHIlLH CORRECTION (7" SCAB LNR) DATE REV BY OOM'v1ENTS PRUDHOE BAY UNrr WI3..L: C-17B ÆRMT I\b: 2040940 APII\b: 50-029-20439-02 SEC 19, T11N, R14E. 6' SN.. & 1217' WEL BP Exploration (Alaska) e -- Phil, Per 20 AAC 25.035 (h) (1), alternate BOPE is hereby approved for wells C-17B (PTD 204-(94) and K-03B (PTD 204-115), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Smith, Phil G (ASRC) wrote: Winton, As discussed yesterday, I neglected to request in the permit application dispensation from changing rams to 7" while running the drilling liner on C-17B. We would like to keep the drillpipe rams in place while running the liner as it is a safer, more efficient method. Please confirm your approval with a reply. Likewise the K-03B permit has been approved without the ram dispensation. K-03B and C-17B are quite similar except that K-03B has just a 550' liner planned (about half that of C-17B). We also request the same dispensation for K-03B. Apologies for the inconvenience, Phil Smi th Operations Drilling Engineer 564-4897 . lill . '1 '~ (êiJ Qi)' FRANK H. MURKOWSKI, GOVERNOR AI,A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay C-17B BP Exploration (Alaska) Inc. Permit No: 204-094 Surface Location: 6' SNL, 1217' WEL, SEe. 19, T11N, R14E, UM Bottornhole Location: 937' NSL, 236' WEL, SEe. 07, T11N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 - 7 (pager). o~ BY ORDER 9~ THE COMMISSION DATED this-1-bIa'ay of June, 2004 cc: Department ofFish & Game, Habitat Section w/oencI. Department of Environmental Conservation w/o encI. v~GI\- &1 f¡LL~C4- o Drill III Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 6'SNL, 1217'WEL, SEC. 19, T11N, R14E, UM Top of Productive Horizon: 4762' NSL, 470' EWL, SEC. 17, T11N, R14E, UM Total Depth: 937' NSL, 236' WEL, SEC. 07, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664128 y- 5961208 Zone- ASP4 16. Deviated Wells: Kickoff Depth 18. Casing Program Size Casing 7" 4-1/2" . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 11 b. Current Well Class 0 Exploratory II Development cfl¡fH;!mfMiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: iii Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU C-17B // 6. Proposed Depth: 12. Field I Pool(s): MD 12911 TVD 8947 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028304 JUN 0:3 8. Land Use Permit: 13. Approximate Spud Date: June 25, 2004 14. Distance to Nearest Property: 17990' 9. Acres in Property: 2560 9423 ft Maximum Hole Angle 93° 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 62.8 feet C-19B is 642' away 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3230 psig Surface: 2400 psig Quantityõ~~ (c.f.or sac (includinQ stage.... data) 280 cu ft Class 'G' /' 377 cu ft Class 'G' / Hole 8-1/2" 6-1/8" WeiQht 26# 12.6# Grade L-80 L-80 Coupling LenQth BTC-M 1167' IBT-M 2646' MD TVD MD TVD 9250' 7345' 10417' 8372' 10265' 8225' 12911' 8947' PR!:S.e:NT WEt.L..·CON)ITION.$l.JMMARY(T()·bø..C()mpløtø~forRêdl'ÍnANO·. Rø..~ntry. PPørations) Total Depth MD (ft): Total Depth TVD Plugs (measured): Effective Depth MD (ft): Effective Depth TVD 12760 8931 12609 12609 8923 Structural Conductor 110' 20" x 30" 12.9 cu yds Permafrost Concrete 110' 110' Surface 2662' 13-3/8" 3720 cu ft Arcticset II 2662' 2662' Intermediate 10498' 9-5/8" 1560 cu ft Class 'G', 130 cu ft Arcticset 10498' 8177' Production Liner 1284' 7" 531 cu ft Class 'G' 9956' - 11240' 7828' - 8689' Liner 2992' 2-7/8" 104 cu ft Class 'G' 9768' - 12760' 7699' - 8931' 20. Attachments iii Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IperfOration Depth TVD (ft): 8911' - 8926' iii Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report iii Drilling Fluid Program iii 20 AAC 25.050 Requirements Perforation Depth MD (ft): 11686' - 12570' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Date: Contact Phil Smith, 564-4897 Phone 564-5521 Date ~I 0310'-1 Prepared By Name/Number: Terrie Hubble, 564-4628 API Number: -J. I See cover letter for 50- 029-20439-02-00 (,.., other requirements Required 0 Yes þ{No ~~es 8 No Hydroge fide Measures ~Yes 0 No Directional Survey Required ~ res 0 No Other: T~ So f-"B 0 P E . 500 p.f, / p eý C, O. 51 &- < 000 . Approved 8V,I77: / Fo,," 10-401 't2~3 Permit To Drill Number: 2- Conditions of Approval: ORIGiNAL BY ORDER OF THE COMMISSION Dare tiitteV · . IWell Name: IC-178 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A Bottom Hole Location: x = 664,128.2 Y = 5,961,208.2 ./ 8' FNL 1217' FEL Sec. 19, T11 N, R14E Umiat /' X = 665,693.0 Y = 5,966,011 TVDss 8920' 518' FNL 470' FWL Sec. 17, T11N, R14E Umiat ~~. X = 664,950.0 Y = 5,967,450.0 TVDss 8884' 937' FSL 236' FEL Sec. 7, T11N, R14E Umiat ,/.. I AFE Number: I PBD4P2242 I I Estimated Start Date: I 06/25/04 I Rig: I Nabors 2ES / I Operating days to complete: 119 I MD: 112,911' II TVD: 18,947' I I GL: 134.3' I KB: 128.5' 1 I KBE: 162.8' I Well Design (conventional, slimhole, etc.): I Two String Horizontal Sidetrack I Objective: I Ivishak Zone 1 A Formation Markers Formation Tops (wp07) MD TVD TVDss CM2 6674 -6611 CM1 9000 7173 -7110 KOP 9423 7464 -7401 THRZ 9501 7518 -7455 TKNG 9734 7716 -7653 T JD 9996 7716 -7904 T JC 10,085 7967 -7989 T JB 10,236 8052 -8135 TJA 10,321 8198 -8217 TSGR 10,417 8280 -8309 TSAD 10,499 8372 -8388 TCGL 10,651 8451 -8534 BCGL 10,722 8597 -8602 23SB 10,788 8665 -8663 22TS 10,839 8726 -8708 21TS 10,913 8771 -8768 TZ1 B 11,030 8831 -8846 TDF 11,099 8909 -8880 BSAD (AT LANDING) 11,285 8943 -8922 TD Criteria: 800' perfs minimum with last half in upper Zone 1 A. C-17B Permit to Drill Comments ABOVE KICKOFF ABOVE KICKOFF 3230 psi @ 8800 Page 1 _470 in the 8-1/2" intermediate section (at KOP) _930 in the 6-1/8" horizontal section C-08A, C-19B, and C-38 pass BP's anti-collision policy when minor risk based at 1/200. All three wells fail major risk criteria against C-17B while in the production interval. The center to center distance is 1061' on C-08A, 642' on C-19B, and 966' on C-38. These wells fail major risk criteria due to old tool code on their original surveys. MWD Standard . Directional - Sperry wp07 KOP: I 9423' MD Maximum Hole Angle: Close Approach Wells: Survey Program: . Casingrrubing Program Hole Size CsglTbg Wt/Ft Grade Co~ Length Top Btm O.D. r'"/ MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 1 ,167' 9,250'/7,345' 10,417'/8,372' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2,646' 10,265/8,225' 12,911 '/8,947' Tubing 4-1/2" 12.6# 13Cr-80 VAM Top 10,236' GL 10,265'/8,225' Mud Program Section Millinr Mud Properties: LSND Density (ppg) Viscosity I PV 10.8 50 - 65 11-13 Intermediate Mud Properties: LSND Den~~Þjg) I Viscosity I PV ~ 45 - 55 12-15 Production Mud Properties: FloPro Density (ppg) I Viscosity I PV 8.4 - 8.5 45-55 4 - 7 I Whip Stock Window 9-5/8", 47# I YP I TauO I HTHP FL I PH 25-30 5-9 <12 8.5 - 9.0 I 8-1/2" hole section YP I TauO 20-25 3-7 I I HTHP FL I PH <12 8.5 - 9.0 YP MBT 20 - 28 < 3 APIFI N/C pH 8.5 - 9.0 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlPWD Open Hole: None Cased Hole: GR Prior to setting whipstock 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GRlABI (+Res for ABI only) None MCNL post rig C-17B Permit to Drill Page 2 . . Cement Program I Casing Size I 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track, 994' of 7" X 8-1/2" open hole with 40% excess, 1S0' 7" X 9-S/8" lap, and 200' of -S/81' X 4" DP excess. Tail TOC 92S' D (Top of Liner) ~ I Total Cement Vol. I Tail Iso bbls, 280 ft3,(242ß'á'cks Class G @ 1S.8 ppg, 1.16 ft3/sack ..7 I I Casing Size 14.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on 80',?hoe track, 2494' of 4-1/2" X 6-1/8" open hole with 40% excess, 1S0' 4-1/2" X 7" Liner Lap, ang20QYof 7" X 4" DP excess. . Tail TOC:~MD (Top of Liner) 10 'UpS I ~ I Total Cement Voluri1¡{; I Tail 167 bbls, 377 ft132gAacks Class G @ 1S.8 ppg, 1.16 ft3/sack '/ Well Control Well control equipment consisting of SOOO psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingl7" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3230psi @ 8300' TVDss (7.S ppg EMW) 2400 psi (.10 psi/ft gas gradient to surface) Infinite with a 12.0 ppg FIT / Rams test to 3,SOO psi/250 psi. Annular test to 2,SOO psi/2S0 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' from middle of window 3230 psi @ 8800' TVDss (7.1 ppg EMW) 2350 psi (.10 psi/ft gas gradient to surface) Infinite with a 10.0 ppg FIT // Rams test to 3,SOO psi/2S0 psi. Annular test to 2,SOO psi/2S0 psi 3S00 psi surface pressure 10.0 ppg FIT after drilling 20' of new hole 8.S ppg Seawater / 7.2 ppg Diesel Disposal . No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. C-17B Permit to Drill Page 3 . . Sidetrack and Complete Procedure Summary Pre-Riq Work: 1. Cycle the tubing hanger LDS & test the tubing hanger seals and 9 5/8" mandrel packoff to 5000 psi. 2. RIH with slickline and recover the L TTP tail pipe plug. Run a 2" OD drift through the 27/8" liner to as deep as possible (Inclination exceeds 700 at 11,676' MD) 3. Confirm fluid levels in the tubing and annulus and fluid pack as necessary for cement plug. 4. R/U and RIH with coil tubing to plug and abandon the well bore from the CIBP at 12,609' to 500' above the 7" window depth at 11,240' (TOC = ±1 0,740'). Estimated cement volume = 10 bbls. 5. Pressure test the cement plug to 3500 psi. 6. R/U slick-line. Drift the 5 W' tubing to 9,700' md to confirm clear to the required cut depth of 9,680'md. Run a 2" drift in the liner to confirm TOC. 7. R/U E-line. RIH with chemical cutter and severe the 5 W' tubing in the center of the first full joint of tubing above the packer -9,680' md ref tubing tally 2-22-85. 8. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect both the tubing and annulus to -2,100' MD with diesel. 9. Bleed casing and annulus pressures to zero. 10. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. Riq Operations: 1. Mil RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. ~pvrrwc. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPVrrWC. 4. R/U. Pull 5 W' tubing from the cut at -9,600' MD and above. 5. RIH wi 8 W' gauge ring I junk basket with gamma ray to top of tubing stub. Log casing from tubing stub to surface shoe at 2662' 6. RIH with HES EZSV and set bridge plug as required to avoid cutting casing collar and place top of /" whip stock at -9,423'. Adjust as necessary to kick off in siltier section of lower CM1. RID E-line. 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. /' 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. /' 9. Displace the well to 10.8 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at ± 9,423' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. / 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POOH. 12. M/U 8 W' Dir/GR/PWD assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. /'" 13. Run and cement a 7",26.0#, L-80 intermediate drilling liner. 14. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. // 15. M/U 61/8" Dir/GR/Res/ABI assembly. RIH to the landing collar. 16. Drill out the 7" liner float equipment and cement to the shoe. / 17. Displace the well to 8.5ppg Flo-Pro drilling fluid. /' 18. Drill out the 7" shoe plus drill -20' new formation; pull up into the shoe and conduct an FIT to 10.0ppg ./" EMW. Drill ahead to horizontal landing point. POOH for bit I BHA change. 19. RIH, drill horizontal section to planned TD, short trip as necessary. 20. Circulate, short trip, spot liner running pill, POOH. 21. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UD all drill pipe. 22. RIH with 2 7/8" perf guns and perforate ±800'. 23. R/U and run 41/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. 24. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. / / C-17B Permit to Drill Page 4 . . 25. Set a TWC and test to 1000 psi / 26. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. / 27. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 28. Rig down and move off. Post-RiQ Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. Run MCNL on slickline to determine GOC. 4. POP well to test unit until cleaned up. /,/ C-17B Drilling Program Job 1: MIRU Hazards and Contingencies y C-17 is the northernmost well on C-Pad at 110' center from the closest well, C-16. No well houses will require removal or shut-in for the rig m~ onto C-17. y C-Pad is not designated as an H25 site. Recent H2S data from the pad is as follows: .~..--~ #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name C-16 C-15 C-08A C-19 H2S Reading No Data No Data No Data No Data Date C-26 and C-27 measured 10 ppm on 10/22/00 ~ Post Permit to Drill in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies y Prior to shut-in in 2003, C-17 A was producing at ±900 BOPD, low water cut and 37K GOR. Pre- Rig operations will include P&Aing the perforations in the 2-7/8" liner with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. y A caliper log in October 2003 indicates fair to good tubing throughout, though a leak detection log confirms two tubing holes between GLMs 4 and 5. Wall loss is from 20-48% of mostly isolated pitting and light line corrosion. No significant wall loss or ID restrictions were recorded. y NORM test all retrieved well head and completion equipment. y Verify the hanger type and connection. Be prepared with necessary equipment to remove. C-17B Permit to Drill Page 5 e . Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies ~ C-17 lacks a gamma ray log through the 9 5/8" casing and KOP is based on offset logs. Since the window of preferred kick-off (a silty section of lower CM1) the KOP may be adjusted slightly after running a GR log and before setting the whipstock. ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the Colville and TO at the top of Sag River. Since C-17B will start at <500 inclination and drop angle, 10.8 ppg mud weight will be adequate to maintain wellbore stability though the HRZ and Kingak shale to interval TO. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ KICK TOLERANC~:,- the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradi~,nt'ôf 1 .0 ppg at the 9-5/8" casing window, and 9.8 ppg mud in the hole, the kick tolerance (~~it Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP C-17B Permit to Drill Page 6 e . Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies þ> The proposed C-17B well lies in a moderate risk province of the field for lost circulation and the risk of loss circulation events should be below average. Only 6 loss circulation events were encountered in the entire geologic section in 5 of the surrounding 29 wells. The planned well will pass within 100 ft of a fault plane (Fit #3) while drilling the build section in lower Zone 2 and Zone 1. Care must be taken to not allow the well to drop below plan trajectory in this section. Two small faults of about 10ft throw each are expected to be crossed perpendicularly by the planned well bore in the horizontal section. These faults will be encountered in Zone 1A at approximately 11790 ft MD and 12210 ft MD. A fault tipout zone (Flt#4) will also be crossed at about 12250 ft MD. Additional faults and tipout zones are present on both sides of the drilling polygon within 0- 250 ft of its edge. The polygon lines are hardlines on all sides and cannot be extended. þ> The landing is targeted 3' above BSAD. If BSAD comes in higher than expected, geosteer up into Z1 A after consultation with town geologist. þ> Three wells have been minor risked to allow drilling (see anti-collision report). These wells are >600' from the planned well path but the high error associated with their Boss gyros has placed them in within tolerance of the polygon. Watch for magnetic interference in the areas of interest. ~ KICK TOLERANC;yE".,....... .. In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradienÞ~ 9. ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance 01e Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production liner Hazards and Contingencies þ> Differential sticking is a concern. The 8.5 ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. þ> Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. þ> Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program C-17B Permit to Drill Page 7 . . Job 10: DPC Perforate Production Casinq Hazards and Contingencies >- Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies >- Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP .:. "Use of 13-Cr Tubulars" .:. "Running and Handling 13-Cr" Job 13: ND/NUlRelease Riq Hazards and Contingencies >- No wells will require well house removal or shut-in for the rig move off of C-17B. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP C-17B Permit to Drill Page 8 TREE = WELLHEAoO = ActUA TOR"" ....,.....,'~,__.<__'''..___........ ~«M KB. ELEV = BF. ELEV = KOP= Max Angle = ,...____________ ~..N Datum MD = ~,'~.".,~ < <M ~~,,~ Datum TVD = 6" McEVOY FMC OTIS 62.15' 34.3' 3300' 98 @ 12272' 11570' 8800' SS · C-17A/ ~NOTES: WELL> 70° @ 11676' AND GOES HORIZONTAL@ 11800'. 2584' I 2662' ~ . L 19-5/8" DV PKR H 113-3/8" CSG, 72#, L-80, ID = 12.347" H Minimum ID = 2.372" @ 9772' TOP OF 2-7/8" LINER 3.75"BKR DEPLOYMENTSLV, ID=3.00" H I TOP OF 2-7/8" LINER, ID = 2.372" H 9768' I 9772' I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 9863' 17" BOT LNR HGR H 9956' 19-5/8" CSG, 47#, L80, ID = 8.681" H 10496' ~ ÆRFORA TION SUMMARY REF LOG: SWS MCNL ON 03/14/98 ANGLEATTOPÆRF: 72 @ 11686' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11686 - 11711 0 01/14/02 2" 6 11725 - 11750 0 01/14/02 2" 4 11810-11900 0 05/17/00 2" 4 11970 - 12030 0 11/14/99 2" 6 12206 - 12231 0 01/14/02 1-11116" 4 12300 - 12349 C 12/28/00 1-11116" 4 12380 - 12498 C 12/28/00 1-11116" 4 12521 - 12570 C 12/28/00 1-11116" 4 12640 - 12690 C 12/28/00 IT' LNR, 29#, L-80, .0371 bpf, ID=6.184" H 11704' DATE 05/10/80 02/22/85 03/15/98 07/29/01 01/21/02 03/11/03 REV BY COMMENTS ORIGINAL COM PLETION RWO CTD SIDETRACK (C-17A) CHlKAK CORRECTIONS PoNElTLH ADD ÆRFS KYITP CIBP LOCATION CHANGE . 2149' H5-1/2" OTIS SSSVN, ID = 4.562" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH 5 3155 3091 8 OTIS LBD DMY RA 4 5720 5053 56 OTIS LBD DMY RA 3 8206 6566 47 OTIS LBD DMY RA 2 9419 7397 47 OTIS LBD DMY RA 1 9575 7504 47 OTIS LBD **DMY RA ** STA #1 = DMY HAS EXTENDED PACKING PORT DATE o 08/26103 o 08/26/03 o 08/03/97 o 08/03/97 o 10104/03 I I I 9645' H5-1/2" OTIS XA SLIDING SLY, ID = 4.562" I í ~ I 9708' H5-1/2" TBG SEAL ASSY I Z Z--l 9723' H 9-5/8" X 5-1/2" TIW PKR, ID = 4.75" I 1-15-1/2" OTIS XNIP, ID = 4.562" I 9820' H 5-1/2" OTIS XN NIP, ID = 4.455" I 9776' I-ï 9864' 9848' H 5-1/2" TIW WLEG I H ELMD TT LOG NOT AVAILABLE I , I ¡ I ~ 7" MLLOUT WINDOW 11240'-11248' TOP OF WHIPSTOCK @ 11240' RA TAG @ 11249' 12609' '12-718"HESMCIBPPUSHED I DOWN FROM 12275', 03/11/03 H 12698' I 12-7/8" LNR, 6.16#, L-80-STL, .0058 bpf, ID = 2.37" H 12760' I DATE 04/08/03 08/26/03 08/26103 09/15/03 10104/03 PRUDHOE BA Y UNrT WELL: C-17A ÆRMrT No: 1980230 API No: 50-029-20439-01 SEC 19, T11 N, R14E, 6' SNL & 1211' WEL REV BY COMMENTS MHlKAK CIBP DEPTH CORRECTION RWLlKK GLM DEPTH CORRECTION RWLlKK GL V C/O CMOITLP DATUM MD & ÆRF ANGLE JCMlTLP EXTENDED PACKING IN STA #1 BP Exploration (Alaska) TREE = WELLHEAD = Á Ci'ÜÄTOR '" KB. ELEV = "................. .",. BF. ELEV = KOP= Max Angle = Datum MD = ^ ~...^ ".~ ~~,~.~ Datum lYD = 4" erN FMC ··01'15 62.15' 34.3' 3300' C-1 ~ Proposed~NOTES' 8800'SS 19-5/8" DV PKR H 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2584' 2662' Minimum ID = 3.725" @ XN I ~ . 2100' 114-1/2" OTIS X Nipple, 10 = 3.813" I GAS LIFT MANDRELS ST MD lYD DEV TYÆ VLV LATCH PORT DATE 4 3260 4.5" x 1.5" DCK ~ 3 5950 4.5" x 1.5" DMY 2 8360 4.5" x 1.5" DMY L 1 10150 4.5" x 1" DMY 141/2" 12.6# 13CR80 VAMTop Tubing (3.958" ID) 1- l 17" 26# L-80 Drilling Liner (6.276" ID) l-f 9250' I - II ÆRFORA TION SUMMARY REF LOG: MNDI LWD July 2004 ANGLEATTOPÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I Cherrical Cut (Top of Fish) H 9600' 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 9863' 17" BOT LNR HGR H 9956' 19-5/8" CSG, 47#, L80, ID = 8.681" H 10496' 17" LNR, 29#, L-80, .0371 bpf, ID=6.184" H 11704' DATE 05/10/80 02/22/85 03/15/98 04/27/04 REV BY COMMENTS ORIGINAL COM PLETION ~O CTD SIDETRACK (C-17 A) PGS Proposed Rotary Sidetrack J 'I' /' 9423' H 9 5/8" Window I 10,225' H4 1/2" X Nipple (3.813" ID) I 1 10,230' l-f 7" x 4 1/2" Baker Premier Packer I I 10,245' H4 1/2" X Nipple (3.813" ID) I 1 10,255' H4 1/2" XN Nipple (3.725" ID) I 1 10,265' H41/2" WLEG I I 10,265' 1-f4 1/2" Hanger / liner top packer I 1 10,417' HT' 26# L-80 (6.276" ID) 0.383 bpf I , I ,~ 14 1/2" 12.6# L-80 Liner PBTD H 12,835' 141/2" 12.6# (3.958" ID) 0,0152 bpf H 12,910' 1 Abandoned 2-7/8" LNR, 6.16#, L-80-STL H 12760' I DATE PRUDHOE BAY UNIT WELL: C-17B ÆRMIT No: 1980230 API No: 50-029-20439-02 SEe 19, T11 N, R14E. 6' SNL & 1211' WEL REV BY COMMENTS BP Exploration (Alaska) IIIIIIIIII COMPANY DETAILS SURVEY PROGRAM Plan: C-J7B WP07 (C-l1/PJan(>J7B) REF1;RI~CB INFOR1vfATlON BP Amoco Date' [kptb Fm Depth To Surwy/Phm 9423.00 12910.95 P-!anued C-17B WP07 V70 1'001 Created By: Troy Jitkabosky Checked" Date: 4/29/2004 MWD Date" Reviewed' 7500 FORMA nON TOP DETAILS No. TVDPalh MDPath Fonnation 1 7517.80 9500.62 THRZ 2 7715.80 9734.07 BHRZ 3 7715.80 9734.07 TKNG 4 7966.80 9996.27 TID 5 8051.80 10084.56 TIC 6 8197.80 10236.20 TJB 7 8279.80 10321.37 TJA 8 837!.80 10416.92 TSGR 9 8450.80 10498.97 TSAD 10 8596,80 10650.61 TCGL 11 8664.80 10721.72 BCGL 12 8725.80 10787.60 23SB 13 8770.80 1083836 22TS 14 8830.80 10912.91 21TS 15 8908.80 11030.14 TZIB 16 8942.80 11099.05 TDF 17 8964 .24 11790.00 Fau!t#1 18 8950.77 12210.00 Fault #2 WELL DETAILS Name .;-Ni-S <oEi_W Northing F.asting Lttit.!.iœ I.ol1gìtu.de Slol ('-17 395451 1663.96 5961208.00 66412&.00 1lf'J8'OI.258N 148:"'4û'J4.287W t7 TARGET DETAILS Name TVD +N/-S +EI-W Northing Basting Shape C-17B TD3 8946.80 6222.99 958.2 1 5967450.00 664950.00 Poînt C-17B T3 c 8952.80 5473.29 1391.97 5966710.00 665400.00 Point C-17B Poly 8974.80 4726.45 1465.68 5965965.00 665490.00 Polygon C-17B T2 d 8977.80 4958.00 1600.00 5966199.42 665619.21 Point C-17B T1d 8982.80 4768.00 1670.00 5966011.01 665693.34 Point CASING DETAILS No. TVD MD Name Size 8371.80 10416.92 7" 7.000 8946.81 12910.00 4-1/2" 4.500 " ~ ;5 :::::. 8100 oS '" " C¡ ';;¡ 0 ·5 > " " Þ 8400 7800 C-17B T3 e C-17B TD3 SECT10N DETAILS See MD AZl TVD +N/-S +E/-W TFace VSec 9423.00 47.09 19.77 7463.23 4121.75 1380.86 0.00 0.00 4283.89 9443.00 47.34 23.02 7416.81 4135.42 1386.21 12.00 85.00 4298.21 3 9834.11 15.68 7459 7810.67 4287.78 1497.76 10.00 160.39 4465.77 4 10632.83 15.68 7459 8579.68 4345.12 1705.84 0,00 0.00 4554.11 5 11285.02 90.00 339.75 8982.80 4768.00 1670.00 14.00 -94.66 4966.62 6 1132L16 91.44 339.71 8982.34 4801.89 1657,48 4.00 -1.75 4998.21 7 11452.95 91.44 339.71 8979.02 4925.47 1611.78 0.00 0.00 5113.39 8 11487.58 92.60 340.47 8977.80 4958.00 1600.00 4.00 33.45 5143.75 9 11488.31 92.57 340.47 8977. 77 4958.69 1599.75 4,00 178.91 514439 10 11783.27 92.57 340.47 896454 5236.40 1501.25 0.00 0,00 5403.88 11 12044.77 92.56 330,00 8952.80 5473.29 1391.97 4.00 -89.82 562J.37 12 12100.67 90.32 329.95 8951.39 5521.66 1364.oJ 4.00 -178.61 5664.93 13 12910.95 90.32 329.95 8946.80 6222.99 958.21 0.00 0.00 629633 Target C-17.B Tld C-17B T2 d Start Dir 14/lûO' : 10632.83' Mil, 8579.68TVD ! 1285.02' MD, 8982.8'TVD : 11321.16' MD, 8982,34' TVD EndDir: Jl488.31'MD, 8977.77' TVD 8700 9000 I 6900 5600 :s '" "" "" :!:, 7' ! 0 5200 ~ -;d 15 0 ø COMPANYDE'fAILS REFERENCE INFORMATION BPAmúÇ{} 6400 6000 4800 4400 4000 W estHlEast( +) [400ftlin] SURVEY PROGRAM Plan: C-l7il \\'1'07 (C-17/PlanC-17B) Depth Fm D¢pth To Survey!P!¡m 9423.00 12910.95 Planned: C-1713 WP07 V70 Too] Created By: Troy Jakabosky Checked: WELL DETAILS Date: 4/2912004 MWD Date Name ;-N/-S ~Eí-W Nordling l!asting Latitude LOßgitwle Slol C-17 3954.51 1663.96 5961208.00 664128.00 7WIW0L25SN 148~40'14287W 17 TARGET DETAILS Name TVO +NI-S +EI-W Northing Easting Shape C-17B Fault #8 8879.80 5766.46 1708.47 5967010.00 665710.00 Polygon C-17B Fault #7 8881.80 6276.87 1239.48 5967510.00 665230.00 Polygon C-17B Fault #6 8891.80 6449.94 643.07 5967670.00 664630.00 Polygon C-!7B Fault #2 8892.80 5469.27 1346.87 5966705.00 665355.00 Polygon C-17B Fa\!lt # I 8897.80 5052.70 1412.79 5966290.00 665430.00 Polygon C-17B Fault #3 8906.80 4638.10 1388.73 5965875.00 665415.00 Polygon C-!7B Fault #5 8907.80 5379.09 1124.83 5966610.00 665135.00 Polygon C-17B Fault #4 8909.80 4954.27 1110.55 5966185.00 665130.00 Polygon C-!7B Tm 8946.80 6222.99 958.21 5967450.00 664950.00 Pomt C-17B 13 c 8952.80 5473.29 1391.97 5966710.00 665400.00 Poiut C-17B Poly 8974.80 4726.45 1465.68 5965965.00 665490.00 Polygon C-17B 12 d 8977.80 4958.00 1600,00 5966199.42 6656] 9.21 Point C-17B Tld 8982.80 4768.00 1670.00 5966011.01 665693.34 Point SECTION DETAILS Sec MD !nc Azi TVD +N/-S +EI-W DLeg TFace VSec Target 1 9423.00 47.09 19.77 7463.23 4121.75 1380.86 0.00 0.00 4283.89 2 9443.00 47.34 23.02 7476.81 4135.42 1386.21 A-'2.00 85.00 4298.21 3 9834.11 15.68 74.59 7810.67 4287.78 1497.76 10.00 ]60.39 4465.77 4 10632.83 15.68 74.59 8579.68 4345.12 1705.84 0.00 0.00 4554.11 5 11285.02 90.00 339.75 8982,80 4768.00 1670.00 14.00 -94.66 4966.62 C-17B Tld 6 11321.16 91.44 339.7] 8982.34 4801.89 1657.48 4.00 -1.75 4998.21 7 11452.95 91.44 339.71 8979.02 4925.47 1611.78 0.00 0.00 5113.39 8 11487.58 92.60 340.47 8977.80 4958.00 1600.00 4.00 33.45 5143.75 C-17B12d 9 1]488.31 92.57 340.47 8977.77 4958.69 1599.75 4.00 178.91 5144.39 10 11783.27 92.57 340.47 8964.54 5236.40 1501.25 0.00 0.00 5403.88 1] 12044.77 92.56 330.00 8952.80 5473.29 1391.97 4.00 -89.82 5621.37 C-17B T3 c ]2 12100.67 90.32 329.95 8951.39 5521.66 1364.01 4.00 -178.61 5664.93 13 ]2910,95 90.32 329.95 8946.80 6222.99 958.2 1 0.00 0.00 6296.33 C-17B Tm FORMATION TOP DETAILS No. TVDPath MOPath Formation 1 7517.80 9500.62 THRZ 2 7715.80 9734.07 BHRZ 3 771 5.80 9734.07 TKNG 4 7966.80 9996.27 TIO 5 8051.80 10084.56 TJC 6 8]97.80 10236.20 TJB 7 8279.80 10321.37 TJA 8 8371.80 104]6.92 TSGR 9 8450.80 10498.97 TSAD 10 8596.80 10650.61 TCGL 11 8664.80 10721.72 BCGL ]2 8725.80 10787,60 23SB 13 8770.80 10838.76 22TS 14 8830.80 10912.91 2]TS 15 8908.80 ] 1030.14 TZlB 16 8942.80 ] 1099.05 TOF 17 8964.24 1] 790.00 Fan!t#l ]8 8950,77 ]2210.00 Fault #2 . BP Planning Report . Principal: Yes Plan: C-17B WP07 Date Composed: Version: Tied-to: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: 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 5957218.72 ft 662550.03 ft Latitude: 70 17 Longitude: 148 41 North Reference: Grid Convergence: 4/28/2004 70 From; Definitive Path Alaska, Zone 4 Well Centre bggm2003 22.367 N 2.797 W True 1.24 deg Well: C-17 Slot Name: 17 C-17 Well Position: +N/-S 3954.51 ft Northing: 5961208.00 ft Latitude: 70 18 1.258 N +E/-W 1663.96 ft Easting : 664128.00 ft Longitude: 148 40 14.287 W Position Uncertainty: 0.00 ft Wellpath: Plan C-17B Current Datum: Magnetic Data: Field Strength: Vertical Section: Casing Points 2ES @ 28.5+34.3 4/9/2004 57589 nT Depth From (TVD) ft 29.80 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 C-17 9423.00 ft Mean Sea Level 25.31 deg 80.86 deg Direction deg 8.75 10416.92 8371.80 12910.00 8946.81 Formations Height 62.80 ft +N/-S ft 0.00 7.000 4.500 8.500 6.125 7" 4-1/2" 9500.62 9734.07 9734.07 9996.27 10084.56 10236.20 10321.37 10416.92 10498.97 10650.61 10721.72 10787.60 10838.76 10912.91 11030.14 11099.05 11790.00 12210.00 0.00 0.00 7517.80 7715.80 7715.80 7966.80 8051.80 8197.80 8279.80 8371.80 8450.80 8596.80 8664.80 8725.80 8770.80 8830.80 8908.80 8942.80 8964.24 8950.77 CM2 CM1 THRZ BHRZ TKNG TJD TJC TJB TJA TSGR TSAD TCGL BCGL 23SB 22TS 21TS TZ1B TDF Fault #1 Fault #2 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . . BP Planning Report Targets C-17B Fault #8 8879.80 5766.46 1708.47 5967010.00 665710.00 70 18 57.969 N 148 39 24.441 W -Polygon 1 8879.80 5766.46 1708.47 5967010.00 665710.00 70 18 57.969 N 148 3924.441 W -Polygon 2 8879.80 5355.11 1764.51 5966600.00 665775.00 70 18 53.923 N 148 39 22.809 W C-17B Fault #7 8881.80 6276.87 1239.48 5967510.00 665230.00 70 19 2.989 N 148 39 38.122 W -Polygon 1 8881.80 6276.87 1239.48 5967510.00 665230.00 70 19 2.989 N 148 39 38.122 W -Polygon 2 8881.80 6309.54 1575.29 5967550.00 665565.00 70 19 3.310 N 148 3928.323 W C-17B Fault #6 8891.80 6449.94 643.07 5967670.00 664630.00 70 19 4.692 N 148 39 55.523 W -Polygon 1 8891.80 6449.94 643.07 5967670.00 664630.00 70 19 4.692 N 148 39 55.523 W -Polygon 2 8891.80 6439.79 1107.99 5967670.00 665095.00 70 19 4.592 N 148 3941.957 W C-17S Fault #2 8892.80 5469.27 1346.87 5966705.00 665355.00 70 18 55.047 N 148 39 34.992 W -Polygon 1 8892.80 5469.27 1346.87 5966705.00 665355.00 70 18 55.047 N 148 39 34.992 W -Polygon 2 8892.80 5622.93 1410.25 5966860.00 665415.00 70 18 56.558 N 148 39 33.142 W C-17S Fault #1 8897.80 5052.70 1412.79 5966290.00 665430.00 70 18 50.949 N 148 39 33.071 W -Polygon 1 8897.80 5052.70 1412.79 5966290.00 665430.00 70 18 50.949 N 148 39 33.071 W -Polygon 2 8897.80 5336.97 1679.08 5966580.00 665690.00 70 18 53.745 N 148 3925.301 W C-17B Fault #3 8906.80 4638.10 1388.73 5965875.00 665415.00 70 1846.872 N 148 39 33.776 W -Polygon 1 8906.80 4638.10 1388.73 5965875.00 665415.00 70 1846.872 N 148 39 33.776 W -Polygon 2 8906.80 4316.25 1926.87 5965565.00 665960.00 70 18 43.705 N 148 39 18.080 W C-17B Fault #5 8907.80 5379.09 1124.83 5966610.00 665135.00 70 1854.160 N 1483941.471W -Polygon 1 8907.80 5379.09 1124.83 5966610.00 665135.00 70 18 54.160 N 1483941.471W -Polygon 2 8907.80 5511.93 767.62 5966735.00 664775.00 70 18 55.467 N 148 39 51.892 W C-17B Fault #4 8909.80 4954.27 1110.55 5966185.00 665130.00 70 18 49.982 N 148 3941.889 W -Polygon 1 8909.80 4954.27 1110.55 5966185.00 665130.00 70 18 49.982 N 148 3941.889 W -Polygon 2 8909.80 5490.90 1272.32 5966725.00 665280.00 70 18 55.259 N 148 3937.167 W C-17B TD3 8946.80 6222.99 958.21 5967450.00 664950.00 70 19 2.460 N 148 39 46.328 W C-17S T3 c 8952.80 5473.29 1391.97 5966710.00 665400.00 70 18 55.086 N 148 39 33.676 W C-17S Poly 8974.80 4726.45 1465.68 5965965.00 665490.00 70 1847.741 N 148 3931.530 W -Polygon 1 8974.80 4726.45 1465.68 5965965.00 665490.00 70 1847.741 N 148 3931.530 W -Polygon 2 8974.80 5456.02 1266.56 5966690.00 665275.00 70 18 54.916 N 148 39 37.335 W -Polygon 3 8974.80 6136.83 781.28 5967360.00 664775.00 70 19 1.613N 148 3951.491 W -Polygon 4 8974.80 6290.90 1054.73 5967520.00 665045.00 70 19 3.128 N 148 39 43.512 W -Polygon 5 8974.80 5692.38 1436.77 5966930.00 665440.00 70 18 57.241 N 148 3932.368 W -Polygon 6 8974.80 4789.55 1782.16 5966035.00 665805.00 70 18 48.361 N 148 3922.298 W C-17S T2 d 8977.80 4958.00 1600.00 5966199.42 665619.21 70 18 50.018 N 148 3927.611 W C-17B T1d 8982.80 4768.00 1670.00 5966011.01 665693.34 70 1848.149 N 148 3925.570 W Plan Section Information 9423.00 47.09 19.77 7463.23 4121.75 1380.86 0.00 0.00 0.00 0.00 9443.00 47.34 23.02 7476.81 4135.42 1386.21 12.00 1.28 16.26 85.00 9834.11 15.68 74.59 7810.67 4287.78 1497.76 10.00 -8.10 13.19 160.39 10632.83 15.68 74.59 8579.68 4345.12 1705.84 0.00 0.00 0.00 0.00 11285.02 90.00 339.75 8982.80 4768.00 1670.00 14.00 11.40 -14.54 -94.66 C-17B T1d 11321.16 91.44 339.71 8982.34 4801.89 1657.48 4.00 4.00 -0.12 -1.75 11452.95 91.44 339.71 8979.02 4925.47 1611.78 0.00 0.00 0.00 0.00 11487.58 92.60 340.47 8977.80 4958.00 1600.00 4.00 3.34 2.21 33.45 C-17S T2 d 11488.31 92.57 340.47 8977.77 4958.69 1599.75 4.00 -4.00 0.08 178.91 11783.27 92.57 340.47 8964.54 5236.40 1501.25 0.00 0.00 0.00 0.00 . . BP Planning Report Plan Section Information 12044.77 92.56 330.00 8952.80 5473.29 1391.97 4.00 0.00 -4.00 -89.82 C-17B T3 c 12100.67 90.32 329.95 8951.39 5521.66 1364.01 4.00 -4.00 -0.10 -178.61 12910.95 90.32 329.95 8946.80 6222.99 958.21 0.00 0.00 0.00 0.00 C-17B TD3 Survey 9423.00 47.09 19.77 7463.23 4121.75 1380.86 0.00 0.00 0.00 Start Dir 12/100' : 9423' 9425.00 47.11 20.09 7464.59 4123.13 1381.36 12.00 1.07 16.32 MWD 9443.00 47.34 23.02 7476.81 4135.42 1386.21 12.00 1.30 16.25 Start Dir 10/100' : 9443' 9450.00 46.68 23.34 7481.59 4140.12 1388.23 10.00 -9.41 4.61 MWD 9500.00 42.01 25.87 7517.34 4171.90 1402.75 10.00 -9.35 5.06 MWD 9500.62 41.95 25.91 7517.80 4172.27 1402.93 10.00 -9.29 5.52 THRZ 9550.00 37.40 28.91 7555.80 4200.26 1417.40 10.00 -9.22 6.07 MWD 9600.00 32.88 32.65 7596.68 4224.99 1432.07 10.00 -9.03 7.48 MWD 9650.00 28.51 37.41 7639.67 4245.91 1446.65 10.00 -8.75 9.52 MWD 9700.00 24.35 43.68 7684.45 4262.85 1461.02 10.00 -8.31 12.55 MWD 9734.07 21.71 49.20 7715.80 4272.06 1470.65 10.00 -7.75 16.19 TKNG 9750.00 20.55 52.23 7730.66 4275.69 1475.09 10.00 -7.29 19.01 MWD 9800.00 17.34 64.09 7777.96 4284.33 1488.74 10.00 -6.42 23.72 MWD 9834.11 15.68 74.59 7810.67 4287.78 1497.76 10.00 -4.88 30.79 End Dir : 9834.11' MD, 7 9900.00 15.68 74.59 7874.11 4292.51 1514.93 0.00 0.00 0.00 MWD 9996.27 15.68 74.59 7966.80 4299.42 1540.01 0.00 0.00 0.00 TJD 10000.00 15.68 74.59 7970.39 4299.69 1540.98 0.00 0.00 0.00 MWD 10084.56 15.68 74.59 8051.80 4305.76 1563.01 0.00 0.00 0.00 TJC 10100.00 15.68 74.59 8066.67 4306.87 1567.03 0.00 0.00 0.00 MWD 10200.00 15.68 74.59 8162.95 4314.05 1593.08 0.00 0.00 0.00 MWD 10236.20 15.68 74.59 8197.80 4316.65 1602.51 0.00 0.00 0.00 TJB 10300.00 15.68 74.59 8259.23 4321.23 1619.13 0.00 0.00 0.00 MWD 10321.37 15.68 74.59 8279.80 4322.76 1624.70 0.00 0.00 0.00 TJA 10400.00 15.68 74.59 8355.51 4328.41 1645.18 0.00 0.00 0.00 MWD 10416.92 15.68 74.59 8371.80 4329.62 1649.59 0.00 0.00 0.00 7" 10498.97 15.68 74.59 8450.80 4335.51 1670.97 0.00 0.00 0.00 TSAD 10500.00 15.68 74.59 8451.79 4335.59 1671.24 0.00 0.00 0.00 MWD 10600.00 15.68 74.59 8548.07 4342.77 1697.29 0.00 0.00 0.00 MWD 10632.83 15.68 74.59 8579.68 4345.12 1705.84 0.00 0.00 0.00 Start Dir 14/100' : 10632 10650.00 15.66 65.68 8596.21 4346.69 1710.19 14.00 -0.09 -51.88 MWD 10650.61 15.67 65.37 8596.80 4346.76 1710.34 14.00 0.99 -51.72 TCGL 10675.00 16.27 53.13 8620.25 4350.18 1716.07 14.00 2.47 -50.19 MWD 10700.00 17.55 41.91 8644.18 4355.09 1721.39 14.00 5.12 -44.89 MWD 10721.72 19.11 33.58 8664.80 4360.49 1725.54 14.00 7.16 -38.32 BCGL 10725.00 19.37 32.45 8667.90 4361.40 1726.13 14.00 8.06 -34.73 MWD 10750.00 21.59 24.70 8691.32 4369.08 1730.28 14.00 8.89 -30.96 MWD 10775.00 24.11 18.43 8714.36 4378.11 1733.82 14.00 10.06 -25.12 MWD 10787.60 25.46 15.72 8725.80 4383.16 1735.37 14.00 10.72 -21.48 23SB 10800.00 26.83 13.31 8736.93 4388.45 1736.73 14.00 11.08 -19.43 MWD 10825.00 29.71 9.10 8758.95 4400.06 1739.01 14.00 11.51 -16.86 MWD 10838.76 31.34 7.08 8770.80 4406.98 1739.99 14.00 11.87 -14.63 22TS 10850.00 32.70 5.58 8780.33 4412.90 1740.65 14.00 12.06 -13.42 MWD 10875.00 35.77 2.59 8801.00 4426.93 1741.63 14.00 12.29 -11.94 MWD 10900.00 38.91 0.02 8820.87 4442.08 1741.97 14.00 12.54 -10.27 MWD 10912.91 40.55 358.83 8830.80 4450.33 1741.88 14.00 12.70 -9.23 21TS 10925.00 42.09 357.79 8839.88 4458.31 1741.65 14.00 12.78 -8.65 MWD . . BP Planning Report Survey 10950.00 45.31 355.81 8857.95 4475.55 1740.67 14.00 12.89 -7.91 MWD 10975.00 48.57 354.04 8875.02 4493.74 1739.05 14.00 13.01 -7.07 MWD 10982.30 49.52 353.56 8879.80 4499.22 1738.46 14.00 13.08 -6.61 C-17B Fault #8 10985.39 49.93 353.36 8881.80 4501.56 1738.19 14.00 13.10 -6.48 C-17B Fault #7 11000.00 51.85 352.44 8891.02 4512.81 1736.78 14.00 13.13 -6.27 MWD 11001.27 52.01 352.37 8891.80 4513.80 1736.65 14.00 13.16 -6.08 C-17B Fault #6 11002.90 52.23 352.27 8892.80 4515.08 1736.48 14.00 13.16 -6.05 C-17B Fault #2 11011.16 53.32 351.78 8897.80 4521.59 1735.57 14.00 13.17 -5.95 C-17B Fault #1 11025.00 55.14 350.98 8905.89 4532.69 1733.88 14.00 13.21 -5.73 MWD 11026.60 55.35 350.89 8906.80 4533.99 1733.68 14.00 13.23 -5.59 C-17B Fault #3 11028.36 55.59 350.80 8907.80 4535.42 1733.44 14.00 13.23 -5.56 C-17B Fault #5 11030.14 55.82 350.70 8908.80 4536.87 1733.21 14.00 13.24 -5.52 TZ1B 11031.92 56.06 350.60 8909.80 4538.33 1732.97 14.00 13.24 -5.49 C-17B Fault #4 11050.00 58.46 349.64 8919.58 4553.31 1730.36 14.00 13.26 -5.33 MWD 11075.00 61.78 348.38 8932.03 4574.58 1726.22 14.00 13.31 -5.02 MWD 11099.05 64.99 347.25 8942.80 4595.59 1721.68 14.00 13.35 -4.72 TDF 11100.00 65.12 347.20 8943.20 4596.44 1721.49 14.00 13.37 -4.59 MWD 11125.00 68.47 346.09 8953.05 4618.79 1716.18 14.00 13.39 -4.47 MWD 11150.00 71.82 345.02 8961.54 4641.55 1710.31 14.00 13.41 -4.26 MWD 11175.00 75.18 343.99 8968.64 4664.65 1703.91 14.00 13.44 -4.10 MWD 11200.00 78.54 343.00 8974.32 4687.99 1696.99 14.00 13.45 -3.98 MWD 11225.00 81.91 342.03 8978.57 4711.48 1689.59 14.00 13.47 -3.88 MWD 11250.00 85.28 341.07 8981.36 4735.04 1681.73 14.00 13.48 -3.82 MWD 11275.00 88.65 340.13 8982.68 4758.59 1673.44 14.00 13.48 -3.78 MWD 11285.02 90.00 339.75 8982.80 4768.00 1670.00 14.00 13.48 -3.77 C-17B T1d 11300.00 90.60 339.73 8982.72 4782.05 1664.81 4.00 4.00 -0.12 MWD 11321.16 91.44 339.71 8982.34 4801.89 1657.48 4.00 4.00 -0.12 End Dir : 11321.16' MD, 11400.00 91.44 339.71 8980.36 4875.82 1630.14 0.00 0.00 0.00 MWD 11452.95 91.44 339.71 8979.02 4925.47 1611.78 0.00 0.00 0.00 Start Dir 4/100' : 11452. 11487.58 92.60 340.47 8977.80 4958.00 1600.00 4.00 3.34 2.21 C-17B T2 d 11488.31 92.57 340.47 8977.77 4958.69 1599.75 4.00 -4.00 0.08 End Dir : 11488.31' MD, 11500.00 92.57 340.47 8977.24 4969.70 1595.85 0.00 0.00 0.00 MWD 11600.00 92.57 340.47 8972.76 5063.85 1562.45 0.00 0.00 0.00 MWD 11700.00 92.57 340.47 8968.27 5158.00 1529.06 0.00 0.00 0.00 MWD 11783.27 92.57 340.47 8964.54 5236.40 1501.25 0.00 0.00 0.00 Start Dir 4/100' : 11783. 11790.00 92.57 340.20 8964.24 5242.74 1498.99 4.00 0.01 -4.00 Fault #1 11800.00 92.57 339.80 8963.79 5252.12 1495.57 4.00 0.01 -4.00 MWD 11900.00 92.58 335.80 8959.29 5344.60 1457.83 4.00 0.00 -4.00 MWD 12000.00 92.57 331.79 8954.80 5434.21 1413.73 4.00 -0.01 -4.00 MWD 12044.77 92.56 330.00 8952.80 5473.29 1391.97 4.00 -0.02 -4.00 C-17B T3 c 12100.67 90.32 329.95 8951.39 5521.66 1364.01 4.00 -4.00 -0.10 End Dir : 12100.67' MD, 12200.00 90.32 329.95 8950.83 5607.64 1314.26 0.00 0.00 0.00 MWD 12210.00 90.32 329.95 8950.77 5616.29 1309.26 0.00 0.00 0.00 Fault #2 12300.00 90.32 329.95 8950.26 5694.19 1264.18 0.00 0.00 0.00 MWD 12400.00 90.32 329.95 8949.70 5780.75 1214.10 0.00 0.00 0.00 MWD 12500.00 90.32 329.95 8949.13 5867.30 1164.02 0.00 0.00 0.00 MWD 12600.00 90.32 329.95 8948.56 5953.85 1113.94 0.00 0.00 0.00 MWD 12700.00 90.32 329.95 8948.00 6040.41 1063.86 0.00 0.00 0.00 MWD 12800.00 90.32 329.95 8947.43 6126.96 1013.78 0.00 0.00 0.00 MWD 12900.00 90.32 329.95 8946.86 6213.52 963.70 0.00 0.00 0.00 MWD 12910.00 '" 90.32 329.95 8946.81 6222.17 958.69 0.00 0.00 0.00 4-1/2" 12910.95 / 90.32 329.95 8946.80 6222.99 958.21 0.00 0.00 0.00 C-17B TD3 TERRIE l HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 108 "Mastercard Check" DATE 010 - 03~o'-( PAY TO THE \..tI--A- ...2. niL · rL_ !^ì'6~ $ 100 00 ORDER OF ~ ~ \~ r'\J..J '-- I . . [)\Q U a,,-r..1Jf\/I)} W (DAm .- -_.f)OLLP-RS First Nationa}~ A~~a\Vl;>L Anchorage, AK 99501 L, ~ I /) LJ ¡¡ '"þ" MEMO Q. - \ ( 6 ~ if~ ¿7'\. µt<»V ~ . I: ~ 2 5 2000(;OI:~~ ~~III(; 2 2 71" ~ 55(;11- 0 ~Oß . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fßf1 C-)7B PTD# AOtj- OyLj X Development Service CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weUboresegment of existing well Permit No, API No. Production should continue to be reported as a function' of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of i1 conservation order approving a spacing e:xception. (Company Name) assumes tbe liability of any protest to tbe spacinge:Jception that may occur. An dry ditcb sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT C-17B Program DEV Well bore seg D PLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On _ Annular Disposal D Administration P,ermit fee attache.d. ' - - - - - Yes - - - -- 2 .Leas~numberappropriate , Yes - - - - - 3 .Unique wel'-n.a(n~.aod lJl!mb.er . . . . . , . . . . . . . . . _ . . . . _ _ ........ yes - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - ~ - - 4 WeJI JQcat~d in,a. <tefinep pool, Yes 5 WeJIJQcated proper ,distance, from driJling unit boundary. . . ,. Yes - - - -- 6 WellJQcated proper .distance from QtheJ wells, . ' ' Y.es 7 .Sutfjcientacreageayailable lndrilJiog unjL Y.es - - - - 8 Jfdeviç¡ted, js, weJlbQre plç¡Ul'!cJu,ded . Y~s - - -- 9 .Operator on I)' affected Party. . Yes - - - - - 10 .Operator bas. appropriate. Qond inJorce . _ . . . . _ . . _ . _ . . . . . . . . . . . . . X~s - - - - - - - - - - - - - - - - - - - - - - - -- . - - - - - - -- 11 P~rmit can be iSSl!ed wjthout co.nserva.tion Qrder. , . , , Xes - - - - - - Appr Date 12 P~rmit c,ao be issued wjthout ç¡<tmil'!istratille.approvaJ . , X~s - - - - -- RPC 6/3/2004 13 Can permit be approved before 15-day wait Yes . 14 Well JQcated withil'! ç¡rea ç¡l'ld,strata .authorized by.lnjectioo Order # (puUO# in corn(n.eots) (For .NA 15 .AJI wel)s.withi.n .1 l4.ruite.area.of reyieW jd~lJtified (For servj~.we[l ol'!l)') _ . . . . _ . . . . . . . . . .NA - - - - ~ - - - - - - - - - - - - - - - - - - - - . - - - - - - -- 16 Pre-produ.ced injector; purationof pre-propuction tes$. thal'l3 mOl'!ths (For,sel'Vtce well QnJy) . ' .NA 17 ACMP. finding .of CQn,si$tency h.as bee,n jssued, for, tbis project NA - - - - -- Engineering 18 .Coodu.ctor stÖl'lgpJQvided ' . ' NA 19 S.uda~casil'lg.protec.t$. alLkIlOwl'l USQWs . , . ' ,NA 20 CMT vol. adequate. to circutate. oncol'!d.uctor & surf C!>g . , .NA 21 CMT vol. adeQu.ate. to tie-tnJQng .string tosud çsg, . . , ' .NA - - - - - 22 .CMTwill coyer,aJl kl'!ownpro.ductiye hQri;zol'ls, X~s 23 .C,asiog desigos adequa.te for C,.T" B.& p-erruafrost Yes - - - - - - - 24 .A.dequatetan.kage,oJ re,Serye pit. , , Yes ' Nabors2.ES, 25 Jf.aJe-prilt has.a lO-4.03 for abandonment beelJ apPJoved . . ' ., Yes * 26 A.dequate.we!lbore sepç¡ratjonproposed. . . - - - - - - - - - - - - - -- .... .Y~s - - - - - - - - - - - - - - - - - - - - - - - -- 27 Jf.djverterJeq,uired, does jtmeetJeguJa,tiol'!s. , . . , . ,NA New well, Appr Date 28 DriUíog fJujd.prQgranJ sc.hemç¡tic&eq.uipJistadequ¡:¡le, . , . . ' , Y~s .Mç¡xMW1P,B.ppg..,. ' - - -- WGA 6/4/2004 29 .B0P.Es,.do.they meetreguJatiPI'! . , Yes - - - - - - . 30 B.OPE.pre.ss rating appropriate; test to.(pu.t psig in.cpmrnel'!t$). . , Yes , . Test to .3500 psi. . MSP. 24.00 psi.. 31 .ChpkeruanjfQld cQnJpJies. w/APt RP.-53 (May 84). , , Yes 32 Work will pcc.ur withpyt,oper¡:¡tion .sb utdown, . , Yes - - - - 33 .Is presence, of H2S gas prob.able. , - - -- No, 34 Meçha.nlc¡:¡l.cpndJtton of we.lIs withil'! AOR yeriJied (fpr.s.ervice welJ only) NA Geology 35 P~rmit c.ao be lssu.ed w/Q hyd(Ogen s.ulfide meaS.ures No. 36 .D,ata.presel'!ted on, pote.ntial pverpres.sure ,zOl'!e.s, ,NA Appr Date 37 S~isrnlc.anç¡lysjs. Qf .shaJlow gasz.one.s, ' NA RPC 6/3/2004 38 S~abedcOl'!djtipo survey.(if Qff-sh,ore) . ' NA 139 , Conta.ct nam,elphQnefQrweekly prpgress,reports ,NA Geologic Date: Engineering ~~y Commissioner: Commissioner: (>15 ó/7/~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. 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 Sep 26 16:18:56 2005 it} 3")),1 Reel Header GI , Service name............ .LISTPE '1. b VI - O'"t Date.................... .05/09/26 ~ ~ Origin............. ......STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. ............LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/26 Origin....... ...... ......STS Tape Name............... . UNKNOWN Continuation Number.. . ., .01 Previous Tape Name...... . UNKNOWN Comments........ ..... ....STS LIS 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 C-17B 500292043902 BP Exploration (Alaska), Inc. Sperry Drilling Services 26-SEP-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 MW0003164914 J. SACK R. BORDES MWDRUN 2 MW0003164914 J. SACK R. BORDES MWDRUN 3 MW0003164914 J. SACK R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003164914 J. SACK R. BORDES MWD RUN 5 MW0003164914 P. SMITH R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 llN 14E 6 1217 61.70 34.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 9418.0 10374.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE . . NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVO). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 9418'MD/7459'TVO AND THE BOTTOM OF THE WHIPSTOCK WAS AT 9434'MD/7470'TVO. SROP DATA ARE INCLUDED FOR THIS RUN. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. MWD RUNS 4 & 5 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC RESISTIVITY - PHASE 4 (EWR4), AND ABI. MWD RUN 5 ALSO INCLUDED STABILIZED LITHO- DENSITY (SLD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD PASS DATA WERE ACQUIRED OVER THE INTERVAL 11170'MD - 10970'MD(BIT DEPTHS), WHILE POOH AFTER REACHING FINAL TD. THE PURPOSE OF THIS MAD PASS WAS TO TRY TO IDENTIFY THE GOC; THEREFORE, ONLY CTN AND SLD DATA ARE PRESENTED. 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN C-17A ON 5 JULY 2004. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 14 SEPTEMBER 2005, AS AUTHORIZED BY STEPHAN BERGBAUER (BP GEOSCIENTIST) . 7. MWD RUNS 1 - 5 REPRESENT WELL C-17B WITH API# 50-029-20439-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12770'MD/8944'TVO. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 - 8.6 PPG MUD SALINITY: 1900 - 2500 FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name. . . .... . . . .. .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/26 Maximum Physical Record..65535 File Type....... . ... . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF $ 1 PPM CHLORIDES 10,994 PPM CHLORIDES and clipped curves; all bit runs merged. .5000 START DEPTH 9169.0 9413 . 5 10829.5 10829.5 10829.5 10829.5 10829.5 10884.0 10884.0 10884.0 10892.5 10892.5 10892.5 STOP DEPTH 12709.5 12763.0 12717.0 12717.0 12717.0 12717.0 12717.0 12673.5 12673.5 12674.0 12688.0 12688.0 12688.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9169.0 9171 . 0 9174.5 9176.5 9178.0 9193.0 9196.0 9201. 0 9204.5 9207.5 9214.5 9216.5 9220.5 9222.5 9236.5 9242.5 9246.0 9252.0 9255.5 9257.0 9258.5 9261. 5 9266.0 9274.5 9282.5 9289.5 9297.5 9300.5 GR 9168.5 9170.5 91 74.0 9177.0 9179.5 9196.0 9198.5 9201. 5 9206.0 9208.5 9214.0 9216.5 9221.5 9224.5 9238.5 9245.0 9250.0 9253.0 9260.5 9262.0 9263.5 9267.0 9271.5 9279.5 9287.0 9295.0 9301.0 9305.0 . . 9304.5 9309.5 9326.5 9338.5 9357.5 9360.0 9365.0 9376.0 9391.5 9415.0 12763.0 $ 9308.0 9314.5 9331.5 9343.5 9361. 5 9364.5 9370.5 9383.5 9398.0 9422.0 12770.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 5 MERGE TOP 9420.5 9449.0 10374.0 10882.0 11506.0 MERGE BASE 9449.0 10374.0 10882.0 11506.0 12770.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.. .......... ......0 Data Specification Block Type.....O Logging Direction............. ....Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Unit s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9169 12763 10966 7189 9169 12763 ROP MWD FT/H 0.08 332.73 90.2423 6700 9413.5 12763 GR MWD API 13 .54 525.28 82.9933 7082 9169 12709.5 RPX MWD OHMM 8.78 108.26 27.2262 3776 10829.5 12717 RPS MWD OHMM 9.41 84.1 26.803 3776 10829.5 12717 RPM MWD OHMM 10.55 126.62 27.7865 3776 10829.5 12717 RPD MWD OHMM 12.47 151.08 28.515 3776 10829.5 12717 FET MWD HOUR 0.19 18.55 2.25475 3776 10829.5 12717 NPHI MWD PU-S 12.45 35.38 23.6966 2930 10884 12673.5 FCNT MWD CNTS 343.2 1266.4 687.864 2933 10884 12674 NCNT MWD CNTS 21920.9 38347.7 30732.3 2932 10884 12673.5 RHOB MWD G/CM 1.948 3.586 2.34999 2945 10892.5 12688 DRHO MWD G/CM -0.1 1.183 0.0855002 2945 10892.5 12688 PEF MWD BARN 0.39 5.64 2.23669 2945 10892.5 12688 First Reading For Entire File. ........ .9169 Last Reading For Entire File...... .....12763 . File Trailer Service name.............STSLIB.OOl Service Sub Level Name. . . Version Number... ....... .1.0.0 Date of Generation. . . . . . .05/09/26 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. ......05/09/26 Maximum Physical Record..65535 File Type...... . . . . . . . . . . LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 9420.5 STOP DEPTH 9449.0 # 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 $ # 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): # 07-JUL-04 Insite Memory 9449.0 9418.0 9449.0 .0 .0 TOOL NUMBER 8.500 9418.0 Water 8.40 28.0 .0 7000 .0 Based .000 .000 .000 .000 .0 132.0 .0 .0 . TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ......... ........0 Data Specification Block Type.....O Logging Direction............ .....Down Optical log depth units. . . ..... . . .Feet Data Reference Point............. . Undefined Frame Spacing................ .....60 .1IN Max frames per record.... ....... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 9420.5 4.91 Max 9449 21.26 Mean 9434.75 10.5907 Nsam 58 58 First Reading For Entire File..........9420.5 Last Reading For Entire File......... ..9449 File Trailer Service name..... ....... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .... .05/09/26 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. ......05/09/26 Maximum Physical Record. .65535 File Type. . . . ........... .LO Previous File Name. ......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9168.5 9449.5 STOP DEPTH 10342.0 10374.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 08-JUL-04 Insite 66.37 Memory . First Reading 9420.5 9420.5 Last Reading 9449 9449 . . TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10374.0 9449.0 10374.0 13.7 45.9 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120558 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 9418.0 # 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: LSND 10.80 57.0 9.3 900 4.0 .000 .000 .000 .000 .0 136.4 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ............. ...0 Data Specification Block Type... ..0 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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9168.5 10374 9771.25 2412 9168.5 10374 ROP MWD020 FT/H 0.69 238.63 89.9031 1850 9449.5 10374 GR MWD020 API 53.49 356.29 137.095 2348 9168.5 10342 First Reading For Entire File..... .....9168.5 Last Reading For Entire File.......... .10374 File Trailer Service name.. ...........STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/09/26 . 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...... .05/09/26 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 GR ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 10323.0 10374.5 STOP DEPTH 10828.5 10882.0 # 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 VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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: 13-JUL-04 Insite 66.37 Memory 10882.0 10374.0 10882.0 13 .4 27.6 TOOL NUMBER 184054 6.125 10374.0 Flo-pro 8.40 52.0 9.3 2500 8.2 .000 .000 .000 .000 .0 138.2 .0 .0 . . $ # 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 DEPT ROP MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10323 10882 10602.5 1119 10323 10882 ROP MWD030 FT/H 0.73 210.37 44.8398 1016 10374.5 10882 GR MWD030 API 14.27 525.28 60.1116 1012 10323 10828.5 First Reading For Entire File.... ......10323 Last Reading For Entire File......... ..10882 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/09/26 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.......05/09/26 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 RPS RPX ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10829.0 10836.5 10836.5 10836.5 10836.5 10836.5 10882.5 STOP DEPTH 11454.0 11461. 0 11461.0 11461.0 11461.0 11461.0 11506.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 14-JUL-04 . 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) 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.. ...0 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 . Insite 66.37 Memory 11506.0 10882.0 11506.0 28.1 89.9 TOOL NUMBER 184054 159436 6.125 10374.0 Flo-pro 8.40 53.0 9.0 2500 8.0 1.350 .660 1.200 1.450 66.0 141. 8 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10829 11506 11167.5 1355 10829 11506 ROP MWD040 FT/H 0.54 203.3 57.6541 1248 10882.5 11506 GR MWD040 API 13 .54 185.67 45.6095 1251 10829 11454 RPX MWD040 OHMM 8.78 108.26 34.5082 1250 10836.5 11461 RPS MWD040 OHMM 9.41 84.1 33.8828 1250 10836.5 11461 RPM RPD FET MWD040 OHMM MWD040 OHMM MWD040 HOUR . 10.55 12.47 0.54 126.62 151. 08 15.87 1250 1250 1250 35.2989 35.8317 2.4093 First Reading For Entire File......... .10829 Last Reading For Entire File.......... .11506 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. . . .. . .05/09/26 Maximum Physical Record. .65535 File Type.. ............. .LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.. ...........STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .05/09/26 Maximum Physical Record..65535 File Type.. . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ 6 . 10836.5 10836.5 10836.5 11461 11461 11461 header data for each bit run in separate files. 5 .5000 START DEPTH 10891. 0 10891.0 10891.0 10899.5 10899.5 10899.5 11454.5 11461. 5 11461. 5 11461. 5 11461.5 11461. 5 11506.5 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 STOP DEPTH 12680.5 12681. 0 12680.5 12695.0 12695.0 12695.0 12716.5 12724.0 12724.0 12724.0 12724.0 12724.0 12770.0 16-JUL-04 Insite 66.37 Memory 12770.0 11506.0 12770.0 88.9 94.9 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 TOOL NUMBER 184054 111109 113413 159436 . . $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10374.0 # 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: Flo-pro 8.60 53.0 9.5 2500 7.5 1.650 .840 1.550 2.000 72.0 147.2 72.0 72.0 # 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 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10891 12770 11830.5 3759 10891 12770 ROP MWD050 FT/H 0.08 332.73 126.653 2528 11506.5 12770 GR MWD050 API 19.99 166.82 60.4399 2525 11454.5 12716.5 RPX MWD050 OHMM 11.79 67.12 23.6227 2526 11461. 5 12724 RPS MWD050 OHMM 11.98 56.82 23.2995 2526 11461.5 12724 RPM MWD050 OHMM 12.59 45.97 24.0689 2526 11461.5 12724 RPD MWD050 OHMM 14.05 43.32 24.8943 2526 11461. 5 12724 FET MWD050 HOUR 0.19 18.55 2.17827 2526 11461.5 12724 NPHI MWD050 PU-S 12.45 35.38 23.6966 2930 10891 12680.5 FCNT MWD050 CNTS 343.2 1266.4 687.864 2933 10891 12681 NCNT MWD050 CNTS 21920.9 38347.7 30732.3 2932 10891 12680.5 RHOB MWD050 G/CM 1.948 3.586 2.34999 2945 10899.5 12695 DRHO MWD050 G/CM -0.1 1.183 0.0855002 2945 10899.5 12695 PEF MWD050 BARN 0.39 5.64 2.23669 2945 10899.5 12695 . . First Reading For Entire File......... .10891 Last Reading For Entire File.......... .12770 File Trailer Service name..... ....... .STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation. . . . . . .05/09/26 Maximum Physical Record..65535 File Type.............. . . LO Next File Name. . . . . . . . . . .STSLIB.007 Physical EOF Tape Trailer Service name...... .......LISTPE Date.......... . . . . ... . . . .05/09/26 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. .... .. . . . . . . ... . ....05/09/26 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