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203-100
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 W-16A 203100 500292204501 2 9/23/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator©bp.com] Sent: Tuesday,August 20, 2013 12:56 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Welipad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS Well Pad SW; Regg, James B(DOA); Wallace, Chris D(DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: W Pad Producers with Sustained Casing Pressures during TAR All, The below producer wells are ready to be brought online Under Evaluation for further diagnostics after their IA exceeded MOASP during TAR: -16A(PTD#2031000) W-2 SCANNED 49 W-22 (PTD#1881100) W-36(PTD#1881060) W-37A (PTD#2021490) W-38A(PTD#2021910) Should a well fail the warm TIFL,an email will be sent to the AOGCC with a plan forward.The producer well below will be brought online Under Evaluation to evaluate OA over MOASP for further diagnostics. W-01A(PTD#2031760) The OART results will be relayed in a separate email. Please call with any questions. Regards, Laurie Climer t.ifterr7ute:Jack Dish, ) BP Alaska_- Well Integrity Coordinator ON mkt :It dr1 dt0'1 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 • • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Friday, January 14, 2011 10:34 PM ``jq `( 11c To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to pe orm a on eac o the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570) C -15A (PTD #2090520) E -17A (PTD #2042040) E -27A (PTD #1990590) F -04B (PTD #2100870) r . 2 iV 'TD : 031760) F I -16A (PTD # 031000) W -21A 'TD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 09 -34A (PTD #1932010) M -21A (PTD #1930750) N -22B (PTD #2061610) All the wells listed above will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start-up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 STATE OF ALASKA i7G~=0! ALAS~IL AND GAS CONSERVATION COMMI~N ~ J~L. 0 7 2009 REPORT OF SUNDRY WELL OPERATIONS 4~iaska ~il & Gas G~ns. ~orr~mission 1. Operations Abandon ~ Repair WeU ~ Plug PerForations ~ Stimulate~ Other ~ (,ChpC~¢~~ 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: tvame: De~elopment ~! Exploratory ~ 203-~000 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22045-01-00 7. KB Elevation (ft): 9. Well Name and Number: 90.48 KB PBU W-16A 8. Property Designation: 10. Field/Pool(s): ADLO-028263 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12904 feet Plugs (measured) None ~ true vertical 8944.46 feet Junk (measured) None Effective Depth measured 12870 feet true vertical 8945.63 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 37 - 117 37 - 117 1490 470 Liner 335 7" 26# IJ4S 10545 - 10880 8605 - 8826 Production 10769 9-5/8" 47# L-80 36 - 10805 36 - 8776 6870 4760 Surface 2637 13-3/8" 68# L-80 37 - 2674 37 - 2674 4930 2270 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ ; Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 34 - 10570 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker Model D Packer 10474 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): , , , ~;~'~.~~'~~'~~~' ~?~1~. F.` ~:~ Zo~c Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 213 387 461 276 Subsequent to operation: SI 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory 1~~ Development ~ Service 1~ Daily Report of Well Opera6ons X 16. Well Status after proposed work: Oil ~ Gas I~ 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 Preb Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2009 Form 10-404 Revised 04/2006 ~ ~~ J~L ~ 4~(~0~ fr,s/ Submit Origin~i~Jnly ~~ ~l1 ~ ~,,-~?'~~` ;~~~^''~C~ W-16A 203-100 PFRF oTTOCHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-16A 7/20/03 PER 11,470. 11,525. 8,971.13 8,959.27 W-16A 7/20/03 PER 12,780. 12,850. 8,949.33 8,946.69 W-16A 7/20/03 PER 12,360. 12,680. 8,906.67 8,938.57 W-16A 7/20/03 PER 12,710. 12,740. 8,942.58 8,946.38 W-16A 7/20/03 PER 11,848. 11,985. 8,911.89 8,903.22 W-16A 7/20/03 PER 11,720. 11,820. 8,928.44 8,915.44 W-16A 7/20/03 PER 12,018. 12,330. 8,902.16 8,904.9 W-16A 7/4/09 APF 11,350. 11,360. 8,992.76 8,991.1 W-16A 7/5/09 APF 11,043. 11,053. 8,938.88 8,945.68 W-16A 7/5/09 APF 11,022. ~/' 11,037. 8,923.86 8,934.69 W-16A 7/5/09 APF 11,063. 11,083. 8,952.21 8,964.39 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 • ~ ~ W-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 diesel 1 Total STATE OF ALASKA ~~~ 1 2p~9 ALAS OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL dm-t~E~~~ ~ "~'~~~'~~` ~~~ -s~~ 09 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~! ""°' `~ Other ~ MILL- Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ ~ ~ ~ .,,~` ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ y~'! 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r' - Exploratory ~ 203-1000 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-22045-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 90.48 KB ' PBU W-16A " 8. Property Designation: 10. Field/Pool(s): ADLO-028263 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12904 _ feet Plugs (measured) None true vertical 8944.46 ~ feet Junk (measured) .None Effective Depth measured 12870 - feet true vertical 8945.63 - feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 37 - 117 37 - 117 1490 470 Liner 335 7" 26# IJ4S 10545 - 10880 8605 - 8826 Production 10769 9-5/8" 47# L-80 36 - 10805 36 - 8776 6870 4760 Surface 2637 13-3/8" 68# L-80 37 - 2674 37 - 2674 4930 2270 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 34 - 10570 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker Model D Packer 10474 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): '~y ~~ ~'~~ '~ Y~ '~U~ Treatment descriptions including volumes used and final pressure: ~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 176 221 382 263. Subsequent to operation: 172 209 367 243 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~' - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas ~ WAG GINJ ~ WINJ WDSPL ~` 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 Ga Preb Title Data Management Engineer Signature Phone 564-4944 Date 3/30/2009 ., 4..- ~ e-ei Rc 4I y [.i1Wc'- Form 10-404 Revis d 04/2006 '~ ~.. 4! ~ Submit Origin On y ~} ~ ,,..~ W-16A 203-100 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas De th Base Tvd Depth Top Tvd Depth Base W-16A 7/20/03 PER 11,470. 11,525. 8,971.13 8,959.27 W-16A 7/20/03 PER 11,720. 11,820. 8,928.44 8,915.44 W-16A 7/20/03 PER 11,848. 11,985. 8,911.89 8,903.22 W-16A 7/20/03 PER 12,018. 12,330. 8,902.16 8,904.9 W-16A 7/20/03 PER 12,360. 12,680. 8,906.67 8,938.57 W-16A 7/20/03 PER 12,710, 12,740. 8,942.58 8,946.38 W-16A 7/20/03 PER 12,780. 12,850. 8,949.33 8,946.69 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • W-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/22/2009~CTU #6 w/1.75" CT. Drift /Mud Acid Stimulation. <InterACT publishing> MIRU CTU on ASRC flow-cross. Well flowing upon arrival. Makeup SLB 2.00" JSN. ;Begin flowing well through ASRC test seperator taking returns down well W- i ob continued on WSR 03/23/09 "** 3/23/2009 ASRC Test Unit #2, Acid flowback, *'"*Job in Progress"** 1 ._.._ ._..._....._ _-.._.u,_.~__ .~ ~.. CTU #6 w/1.75" CT. Drift /Mill Scale. *** Continued from WSR 03/22/09 '"`* <InterACT publishing> RIH with 2.00" JSN with well flowing. Tag at 12317'. Attempt to jet with no success. Shut in well and try to RIH with no sucess. i POOH to pickup motor andmill. MU Weathertord Milling BHA W/ 5-Blade 2.30" Concave mill and RIH. Tagged at 11030' and started milling taggin each collar. At the bottom of upp- er per-f. s, puTl~ overpull after milting ahead. _, e uce pentration rate to 120 ft/hr. Continued milling ahead perform shor trips j every 60' with long trip to liner top 3rd trip. pepth milled to at 11600' at end of *"* Job Continued on WSR 03/23/09 *"* 3/24/2009 CTU #6 w/1.75" CT. Mill Scale. """ Continued from WSR 03/23/09 *** <InterACT publishing > Continue milling. from 11600' with WFD 1.68" Even- IWall motor and a 2.30' - a e concave mill using 2% KCI with 0.6% SafeLube and Geovis sweeps. G/L rate at 2.2mm. Returns through ASRC ,averaged 1000 bpd gross fluid rate. Depth of milling at 12011' ctmd at lam. Continued milling to TD @ 12838' ctm pam ag a 820' and chased geovis pi su ace, mi sowed minimal face wear and passed a 2.30" gauge ring loosely. Perform pipe management. ***Job Continued on WSR 0_3/25/09 *** __ 3/24/2009 ASIC Test Unit #2, Acid flowback, """Job in Progress* 3/24/2009~LRS Unit T-96 Fluid support 3/25/2009 CTU #6 w/1.75" CT. Mud Acid Stimulation. "** Continued from WSR 03/24/09 ''** <InterACT publishing> Freeze protect surface lines through ASRC and to hardline to W-19 flowline with 60/40 meth. LRS rig up and load IA with dead jcrude. RIH tagged hard bottom at 12849' ctmd, correct depth and paint flag at 12850'. Displace well with Ammonium Chloride and 135 bbl diesel cap. Static WHP is 227psi. Pump acid job per program using 150 bbls of 12% HCI and 150 bbls of 9:1 Mud Acid. Pump 2 foam divert stages between 3 acid pumping stages. Initial infectivity was 1.8 bpm at 890 psi WHP. After first HCI pass, WHP dropped to 618 psi at 1.8 bpm, then rose during mud acid stage #1. After diversion, WHP rose to 1.8 bpm at 900 psi. First 2 stages werew completed by midnight. "**Job Continued on WSR 03/26/09 **" 3/25/2009ASRC Test Unit #2 assist CTU with mud acid stim (flowback) **job in progress** 3/25/2009 T/I/0= 150/1380/190 Temp= SI Assist CTU.. Pumped 5 bbls neat meth spear followed by 569 bbls 110'' crude down the IA. Final WHP's= 1862/40/160 "Coil has control of well on departure" 3/26/20091ASRC Test Unit #2, CTU RDMO, well POP. No flow, increase A/L to 1.0 mmscf/d, well currently flowing.. Sample returns for pH, divert liquids to tank ~ 3/26/2009~CTU #6 w/1.75" CT. Mud Acid Stimulation. "** Continued from WSR 03/25/09 *''* <InterACT publishing> Continue pumping 3rd interval treating from 11470' ,to 11820' ctmd. using 31 b s o o an s o mud acid. ver displace with 3% ammonium chloride. RIH pumping 3% ammonium chloride w/ i F103 with 4% U67. Overdisplace with 90 bbls of ammonium chloride. WHP +mcreased -200 psi after both foam diversions. While POOH, discovered damaged CT at 11880'. Final infectivity was 2.0 bpm at 1140 psi. Continue POOH pumping pipe displacement with 60/40 meth. At surface, blow down CT ~ reel with N2. Final T/I/O = 290/140/187. Well turned over to ASRC to begin acid flowback. "'`'`Job Complete "** FLUIDS PUMPED BBLS 1193 2% KCL W/SAFELUBE 229 60/40 METH 93 GEOVIS 134 DIESEL 540 3% AMMONIUM CHLORIDE W0.02% F103 25 3% AMMONIUM CHLORIDE W0.02% F103 W/5% U67 150 12% HCI 150 9:1 MUD ACID 18 FOAM WITH 4% OILSEEKER 2532 Total • • ~.._> MICROFILMED 03/01/2008 DO NOT PLACE ~.``, °,.~. ,.~~. w ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc · -; U:'\ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: M-38A PB1, N-01A, P-18 L1, S-18A, W-16A PB1, - - W-32A PBl. 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 ~ M-38A_PB1: U..\.. c.. 'do l- \3 d lL./'--/ to Digital Log Images: 50-029-22519-01,70 SCANÞtED FEB 0 1 2007 N-01A: 'd ()t../-¡13 ~ /4£.111 Digital Log Images: 50-029-20079-01 1 CD Rom 1 CD Rom P-18 L1: .;:>O~ - 03Cî 'fi-ILILID?r Digital Log Images: 50-029-22097-60 1 CD Rom S-18A: 6>OJ -I ~3 11 I ¿./L/ / d. Digital Log Images: 50-029-21156-01 1 CD Rom W-16A_PBl: Q0"3-/00 'tI. IL./4D9 Digital Log Images: 50-029-22045-01, 70 1 CD Rom W-32A_PB1: do8 -80~ jj t4L/l3 Digital Log Images: 50-029-21790-01,70 1 CD Rom 1- e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23,2004 /3&/3 RE: MWD Fonnation Evaluation Logs: W -16A PB 1, AK -MW -2548805 W-16A PBl: Digital Log Images: 50-029-21961-70 /)D8 -/DÒ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 /lDale;}1 ætDG 13 (~DJ1 Signe .... ~ ii GOt Jo ß (\ , - l ) e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2003 13lr l3 RE: MWD Fonnation Evaluation Logs: W-16A, AK-MW-22166 W-16A: Digital Log Images 50-029-21961-01 9°8-/00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ate: {j} 99 I DlD ~' Signe. b~l1= I I: ) Jf u¿ 13 JJy ~~.1 API No. 50-029-22045-01-00 ~ rj f~\.¡~if\ r;}-~. DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2031000 Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UNIT W-16A MD 12904 /' TVD 8944 /' Completion Date 7/20/2003 ~ Completion Status 1-01L Current Status 1-01L UIC N - ---------- - Mud Log No Samples No Directional s~"'_ __ REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RES, CNL, CCL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Log Log Run Scale Media No Received Comments ; i .Ãi J..J $ lED C 12142 LIS Verification 10383 12863 Case 9/20/2003 Compensated Neutron I Log - Memory i GRlCCUCNL ¡ ED C Pds 12142 Neutron 2 10383 12863 Case 9/20/2003 Compensated Neutron I Log· Memory i V ~ GRlCCUCNL 2 Blu 10383 12863 Case 9/20/2003 Compensated Neutron Log - Memory i GRlCCUCNL i lED C Pds 12142 Casing collar locator 2 10383 12863 Case 9/20/2003 Compensated Neutron Log - Memory GRlCCUCNL i I Log Casing collar locator 2 Blu 10383 12863 Case 9/20/2003 Compensated Neutron I Log - Memory i GRlCCUCNL Rpt Directional Survey 10870 12904 8/15/2003 I Rpt Directional Survey 10823 1 0994 8/15/2003 PB1 I k-ED D Las {2213 LIS Verification 10825 1 0974 10/10/2003 p~ 1 % LIS Verification 10825 10974 1 0/1 0/2003 rED D Las 12213 Rate of Penetration 10825 10974 10/10/2003 yz f> I I Rpt Rate of Penetration 10825 1 0974 10/10/2003 Y D Las f! 2212 LIS Verification 10790 12853 1 0/1 0/2003 Rpt / LIS Verification 10790 12853 10/10/2003 ED D ) 12212 Rate of Penetration 10790 12853 1 0/1 0/2003 --- ----- r~"C.b DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2031000 Well Name/No. PRUDHOE BAY UNIT W-16A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22045-01-00 MD 12904 R~ ~/ ~t ~. 8944 Completion Date 7/20/2003 /-f2212 Rate of Penetration Directional Survey Directional Survey Completion Status 1-01L Current Status 1-01L UIC N ------ ---- 10790 12853 1 0/1 0/2003 10870 12904 1 0/1 0/2003 10823 10994 1 0/1 0/2003 -~----- Sample Set Sent Received Number Comments -=-~ Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? T'"f1';f- Compliance Reviewed By: Analysis Received? Comments: Daily History Received? (jyN (9/N Formation Tops ~ - ------ --- ------ - ~ Date: 2¿ ~\~ ( STATE OF ALASKA t RECEIVED ALASKA OIL AND GAS CONSERVATION COf\,II\',1SSION . ""'" REPORT OF SUNDRY WELL OPERATIONSMAY 1 0 Z005 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D 2. Operator Name: 3. Address: Repair Well 0 Pull Tubing 0 Operation ShutdownO Stimulate ŒI Alaska Oil & Gað~g~Commissior. . . finchoraRew WalverD TIme ËX1:enslon [J Re-enter Suspended Well D 5. Permit to Drill Number: 203-1000 6. API Number 50-029-22045-01-00 Plug PerforationsD Perforate New Pool D Perforate D 4. Current Well Class: Development [!] BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 90.48 8. Property Designation: ADl-028263 11. Present Well Condition Summary: ExPloratoryD StratigraphicD ServiceD 9. Well Name and Number: W-16A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 12904 feet true vertical 8944.5 feet Effective Depth measured 12870 feet true vertical 8945.6 feet Casing Conductor Liner Production Surface Perforation depth: Length 80 335 10769 2637 Plugs (measured) Junk (measured) None None Size 20" 91.5# H-40 7" 26# IJ4S 9-5/8" 47# l-80 13-3/8" 68# l-80 MD TVD Burst Collapse 37 117 37.0 117.0 1490 470 10545 - 10880 8605.0 - 8825.7 36 - 10805 36.0 - 8775.5 6870 4760 37 - 2674 37.0 - 2674.0 4930 2270· Measured depth: 11470 -11525,11720 -11820,11848 -11985,12018 -12330,12360 -12680,12710 -12740,12780 -12850 True vertical depth: 8971.13 - 8959.27,8928.44 - 8915.44,8911.89 - 8903.22,8902.16 - 8904.9, 8906.67 - 8938.57,8942.58 - 8946.38 8949.33 - 8946.69 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 34 10570 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11470' -12850' Treatment descriptions including volumes used and final pressure: 555 Bbls 7% HCl, 560 Bbls 9:1 Mud Acid @ 3820 psig Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Þressure 1.2 97 210 1.1 81 280 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )!jaa ~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Signature Form 10-404 Revised 4/2004 4-1/2" Baker Model D Packer @ 10474 RBDMS 8Ft . MA Y 1 1 2005 Oil-Bbl 366 358 Tubing Pressure 275 251 ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil[!] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Development ŒJ Service D Title Production Technical Assistant Phone 564-4657 , r h~ t~\ J_ Date 5/9/05 (' (' W-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/29/05 CTU #5, ACID TREAT; CONT FROM WSR 3/28/05... CONTINUE PUMPING ACID TREATMENT AS PER PROGRAM SCHEDULE. COMPLETE TREATMENT. FINAL INJECTIVITY DURING LAST OVERFLUSH; 2 BPM @ 890 PSIG WHP. POOH. CONT ON WSR 3/30/05 ... 03/30/05 CTU #5, ACID TREAT; CONT FROM WSR 3/29/05... POOH. RD OS CTU #5. HAND WELL OVER TO ASRC TESTERS TO POP. NOTIFY PAD OPERATOR OF WELL STATUS. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 45 60/40 Methonal/Water 754 3% NH4CL 555 7% HCL 560 9: 1 Mud Acid 152 Diverter 2066 TOTAL Page 1 ]REE -:', . 4" crw WELLHEAD = MCEVOY A CTUA TOR = OTIS "··'".,.""'..,......."'._".~,,........^.."w...,..·.·."'.,..,,~,,...,,_. ..,....".""'........'~..,....'~,,~"'."',_ KB. ELEV = 90.48' BF. ELEV = 53,08' -~'"-_........-_.-......... KOP = 4311' -~~._~.~.~.I~.~_..._..._~~...~..~~~~.:. Datum MD = 10976' Datum TVD = 8800' SS f 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 2674' Minimum ID = 2.372" @ 11051' TOP OF 2-7/8" LINER ÆRFORA TION SUMMARY REF LOG: SÆRRY MWD-GR ON 07/09/03 ANGLEATTOPÆRF: 103 @ 11470' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 11470 - 11525 0 07/20/03 2" 4 11720 - 11820 0 07/20/03 2" 4 11848 - 11985 0 07/20/03 2" 4 12018 - 12330 0 07/20/03 2" 4 12360 - 12680 0 07/20/03 2" 4 12710 - 12740 0 07/20/03 2" 4 12780 - 12850 0 07/20/03 l 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID - 2.992" 1-1 10537' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 1-1 10570' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10805' I TOP OF WHIPSTOCK 1-1 10875' I STANDING V A LV E 1-1 11000' 1 I PBTD 1-1 11454' 7" LNR, 26#, 1J4S, .0383 bpf, ID = 6.276" 1-1 11558' I W-16A I!1!!!t. . ~ L I I ~ :8: I t )~ I I SAFEr fOTES: ***4-1/2" CHROME TBG*** 2122' H4 1/2" SSSV LAND NIP 1 GAS LIFT MANDRELS ST MD TVD DEV 1YÆ VLV LATCH 6 2974 2974 1 OTIS DOME RA 5 5385 5281 38 OTIS SO RA 4 7521 6725 48 OTIS DMY RA 3 8884 7592 53 OTIS DMY RA 2 9740 8099 51 OTIS DMY RA 1 10432 8534 52 OTIS DMY RA ~ PORT DA TE 16 01/05/05 20 01/05/05 o 01/05/05 o 01/05/05 o 01/05/05 o 01/05/05 10461' H4-1/2" PARKER SWS NIP, ID = 3.813" 10474' 10504' 10516' 10536' 10537' 10548' 10560' 10570' ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" DATE 07/21/90 02/22/92 07/21/03 08/07/03 01/05/05 REV BY COMMENTS JQ ORIGINAL COM PLETION RWO DAC/KK CTD SIDETRACK (W-16A) JCrvvTLP GL V C/O LWB/TLP MANDREL TVD CORRECTIONS DATE I r-4 ~ H 9-5/8" X 4-1/2" BA KER D W/SBE I 1& MOX PKR, ID = 4.750" 1-14-1/2" PARKER SWS NIP, ID = 3.813" 1-13.70" BKR DEPLOYMENT SLV, ID = 3.0" 1-13-1/2" HOWCO NIP, ID = 2.813" 1 - 3-1/2" X 3-3/16" XO, ID = 2.880" 1 - 4-1/2" PA RKER SWN NIP, MILLED ID = 3.80"(BEHIND CT LNR) 1-1 ELMD TT LOGGED 09/23/95 1 1-14-1/2" WLEG, ID = 3.875" (BEHIND CT LNR) MILLOUT WINDOW 10880' - 10886' 11050' 1-13-3/16" X 2-7/8" XO, ID = 2.440" 1 I 2-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.372" 1-1 12904' I REV BY COMMENTS PRUDHOE BA Y UNrr WELL: W-16A ÆRMrr No: 2030980 API No: 50-029-21961-01 SEC 21, T11 N, R12E, 801' FNL & 1183' FEL BP Exploration (Alas ka) f t eC)3 0- ,co WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage,Alaska October 02,2003 RE: MWD Formation Evaluation Logs W-16A, AK-MW-2548805 1 LDWG formatted Disc with verification listing. API#: 50-029-22045-01 18~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. J\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99508 Date: Sign;~0~~~~~~'- ~~~Iiy\~ { I, ( I~C)3 -) Cð WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7th Avenue, Suite lOO J\nchorage,Alaska October 02, 2003 RE: MWD Formation Evaluation Logs W-16A PBI, AK-MW-2548805 I LDWG formatted Disc with verification listing. } é) (). L3 API#: 50-029-22045-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed~'-~,l''';'< ~ ~~~ ~ '¡~\£r I,,;:: r): I~ ~! _"",,",,' ¡,6... ..~ {~¡ ¡I'\ It!, ..~ Or,··"" ! O{,JJ \J ~¡ l.;, I ,. ¿;, (;i)~'CJrr¡j~)5¡~1Wì ~~~\f\{\ ~ f STATE OF ALASKA ( ALASKA. OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 801' SNL, 1183' WEL, SEC. 21, T11 N, R12E, UM Top of Productive Horizon: 1946' SNL, 3345' EWL, SEC. 22, T11N, R12E, UM Total Depth: 1864' SNL, 1592' EWL, SEC. 22, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5959456 Zone- ASP4 TPI: x- 616596 Y- 5958380 Zone- ASP4 Total Depth: x- 614842 Y- 5958434 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: MWD, GR, ROP, RES, CNL, CCL One Other 5. Date Comp., Susp., or Aband. 7/20/2003 6. Date Spudded 7/13/2003 7. Date T.D. Reached 7/18/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 90.48' 9. Plug Back Depth (MD+ TVD) 12870' + 8946 Ft 10. Total Depth (MD+ TVD) 12904 + 8944 Ft 11. Depth where SSSV set (Nipple) 2122' MD 19. Water depth, if offshore N/A MSL 'w'.'" .·~·:,þI::R· ;'P:T'; ,'"" ',"." 'r',,' 1','1, . Conductor 68# 47# 26# 9.3# / 6.2# / 6.16# CASING, LINER AND CEMENTING RECORD '. . SETTINaDERTÅ,":' .:,Hb~~" ....>,':,:::',': ,...,;.' '.' '... ;.,.,...,' '.'.".' ,..,,:,: :iTbp'{,",'::' "I:", Bdm:¡joMil ,I' '1,,:''',;:8121:,,: "," ".; ': 'CEMENTltlJG .'REeoRþ:'·"." Surface 11 0' Surface 2674' Surface 10807' 10545' 10880' 10516' 12904' 22. GASiNê3 'SIZE, 20" 13-3/8" 9-518" 7" .';, 'GRt>¡pE' L-80 NT80-S L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4spf MD TVD MD TVD 11470' -11525' 8971' - 8959' 11720' - 11820' 8928' - 8915' 11848' - 11985' 8912' - 8903' 12019' - 12330' 8902' - 8905' 12360' - 12680' 8907' - 8939' 12710' - 12740' 8943' - 8946' 12780' - 12850' 8949' - 8947' 26. Date First Production: August 14, 2003 Date of Test Hours Tested PRODUCTION FOR 8/17/2003 4 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED ...... Press. 325 24-HoUR RATE""'" 17-1/2" 3840 cu ft Coldset III & II 12-1/4" 2378 cu ft Class 'G' 8-112" 294 cu ft Class 'G' 3-3/4" 157 cu ft Class 'G' 1 b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-1 00 303-199 13. API Number 50- 029-22045-01-00 14. Well Number PBU W-16A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ,ÄM'OtJNT PU~~ED . 3-1/2" x 3-3/16" x 2-7/8" , 'TUBI~G'REcbRD, SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 11116' PACKER SET (MD) 10474' ';,;,~cm~;: f:RÀCTÚRE" 'CEMENT SQUéEZE,ETC. I ""',1' .",,' ",,," ,1,1 1",·1""...;1, '" I' ' I,' "I,:, ,', :,,'11 I,. I', ',', I DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-Bsl 1,153 Oll-Bsl 6,918 GAs-McF 2,694 GAs-McF 16,164 W A TER-Bsl 312 GAS-Oil RATIO 2,336 CHOKE SIZE 1760 Oil GRAVITy-API (CaRR) 27. CORE DATA ~~~~~e:~:~~?p~~ ~t~~~~,Y~:~o.~~~~~~~:~,; ,apparent dips and presence of oil, gas or water (attach sepq(',Ùeshlet, jf "cessary) ~, '."" I I , ".. . I \...': ~ ' W A TER-Bsl 1,872 -, y'~!: / : .,L'L~/Æ.,J i~ .- _v[niJ-~ r 0 RIG' N A L ".'.'-.,:¿~::::'::,:J · None Form 1 0-407 Revised 2/2003 CONTINUED ON REVERSE SIDE RBDMS BFl (.9ç AUG 2 ~J ~nHß 28. 1,1f GEOLOGIC MARKEll I, 29. ~f FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Eileen 10968' 8884' None Sadlerochit 10992' 8901' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /a)^ ßJI iI LI (J~ ð_ Ttl T h I A t t D t í"'Q. þ J9 .7'\-:> Terrie Hubble .........(OJu~ ~ i e ec nica ssis an a e va ..{ -.-l J PBU W-16A 203-100 303-199 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Alistair Sherwood, 564-4378 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-Alternating-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 2/2003 OR/GINA.I ( f BP Exploration Operations Summary Report Page 1 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/8/2003 08:00 - 17:00 9.00 MOB N WAIT PRE Rig released from Z-23AL 1 @ 08:00Hrs on 7/8/2003. W.O. wind & removal ofW-16 well house. 17:00 - 17:15 0.25 MOB P PRE PJSM. Pull rig off well & clean up location. Conduct post operations pad inspection. 17:15 - 17:30 0.25 MOB P PRE Held pre-move safety meeting with crew, security & tool services. 17:30 - 18:00 0.50 MOB P PRE Move rig from Z-23. Access road shoulder gave way & rig got stuck ca. 150 yards from Z Pad. 18:00 - 00:00 6.00 MOB N MISC PRE SID rig move & set down. Re-grouped & evaluate situation. Crib rut & jack rig. 7/9/2003 00:00 - 02:00 2.00 MOB N MISC PRE Pull rig back onto hard surface with 2 D-8 Cats. 02:00 - 05:00 3.00 MOB N MiSe PRE W. O. Tool Service to plywood access road shoulders. 05:00 - 10:30 5.50 MOB P PRE PJSM. Continue moving rig from Z-23 to W-pad. 10:30 - 12:30 2.00 MOB P PRE Prep tree & check for pressures: WHPIIAP/OAP/FLP = 0/250/0/0 psi. FL is blinded. DSM install wellhead platform & depressurize lAP. Lay 6 rig mats in front of well to prevent sinking on soft pad. 12:30 - 12:45 0.25 RIGU P PRE PJSM for backing rig over well. Review procedure, hazards & mitigation. 12:45 -13:00 0.25 MOB P PRE Back rig over well & set down. 13:00 - 16:00 3.00 BOPSUR P PRE Accept rig @ 13:00hrs on 7/9/2003. PJSM. N/U BOPE. Meanwhile spot trailers & tanks. P/test hardline to flowback tank to 4000psi. 16:00 - 17:00 1.00 BOPSUR P PRE R/U for testing BOPE. Fill up rig water. 17:00 - 18:00 1.00 BOPSUR P PRE Perform initial BOPE pressure/function test. AOGCC test witnessed by Jeff Jones. Meanwhile fill rig pits with 2% KCL water 18:00 - 19:30 1.50 BOPSURP PRE Crew change. SID operations. Held CTD HSE review meeting with both crews & the BP/SLB peer review team. 19:30 - 19:45 0.25 BOPSUR P PRE TL mtg 19:45 - 00:00 4.25 BOPSUR P PRE Resume initial BOPE test. Fin fill pits w/ KCI 7/10/2003 00:00 - 00:30 0.50 BOPSUR P PRE Repair 3" manual choke and PT. Fix light indicators on BOP control panels 00:30 - 01 :00 0.50 BOPSUR P PRE Open well to 60 psi. Bleed gas off to flowback tank. Prespud mtg 01 :00 - 02:00 1.00 CLEAN P WEXIT RU dart catcher. Fill CT w/ KCI water and pump dart. Dart hit at 59.4 bbls. PT CTC at 35k, 3500 psi. PT inner reel valve 02:00 - 02:55 0.92 CLEAN P WEXIT Load window milling tools to floor. MU milling BHA 02:55 - 04:50 1.92 CLEAN· P WEXIT RIH w/ BHA #1 (3.80" D331 w/ 3.80" SR) circ at min rate while take gas, MeOH and crude to flowback tank 04:50 - 05:10 0.33 CLEAN P WEXIT 10000' 40k. RIH and tag XN at 10549' CTD. PUH 40k, start pump 1.6/830 05: 1 0 - 06:35 1.42 CLEAN P WEXIT Mill XN 1.7/980 while fin circ out wellbore fluids to flowback tank. Drift thru XN clean & made up/down passes with pumps - no motor work or O/pulls. 06:35 - 06:45 0.17 CLEAN P WEXIT RIH to 10950' circ @ 1.6bpm/840psi. 06:45 - 09: 1 0 2.42 CLEAN P WEXIT POOH with milling BHA #1. Meanwhile insert 2 RA pip tags in whipstock - distance from TOWS to RA tag = 10'. Got back 15bbls gassy returns. 09: 1 0 - 09:25 0.25 CLEAN P WEXIT PJSM for LID milling BHA. 09:25 - 10:00 0.58 CLEAN P WEXIT LID & inspect milling BHA#1. String reamer & DSM window mill gauge 3.78" go / 3.77" no go. 10:00 - 10:15 0.25 WHIP P WEXIT PJSM for M/U MWD whipstock setting BHA. Printed: 7/22/2003 8:55:07 AM / ,~ ( BP Exploration Operations Summary Report Page 2 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N 1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/1 0/2003 10:15 -11:05 0.83 WHIP P WEXIT M/U whipstock setting BHA #2 with Baker 7" Gen II W/S, setting adapter, J-hydraulic S/tool, FAIV, Sperry GR/MWD, orienter & DS MHA. Align setting tool to MWD scribe line. Ref depth to TOWS. GR to TOWS = 26.9'. Stab injector on well. 11 :05 - 13:45 2.67 WHIP P WEXIT RIH with whipstock setting BHA to 500'. SHT MWD - OK. RIH to 4200'. SHT orienter - OK. Continue RIH to 10850'. 13:45 - 14:00 0.25 WHIP P WEXIT Log GR and tie-into SLB CBT/GRI CCL log of 7/18/90. Added 2' to CTD. 14:00 - 14:10 0.17 WHIP P WEXIT Continue RIH @ 300fph to 10920' to acquire more GR data. 14:10 - 14:15 0.08 WHIP P WEXIT PUH @ 45k to 10900.5 (10904' - 3.5' for CT stretch). Check TF - 170R. 14:15 - 14:40 0.42 WHIP P WEXIT Orient TF around to 149R. 14:40 - 14:50 0.17 WHIP P WEXIT Ramp up to 3.1 bpm to actuate the FAIV. See pressure drop from 3500psi. Bleed off CT pressure (& get a click). Pressure back up to 1.6bpm/3200psi to set WIS. Bleed off & S/O 3k - holding. PUH @ 41.5k. W/S set @ 164 degs ROHS with TOWS @ 10904'. 14:50 - 17:00 2.17 WHIP P WEXIT POOH with W/S setting BHA. 17:00 - 17:15 0.25 WHIP P WEXIT PJSM for UD whipstock setting BHA. 17:15 - 18:00 0.75 WHIP P WEXIT UD whipstock setting BHA. 18:00 - 18:15 0.25 STWHIP P WEXIT PJSM for M/U window milling BHA. 18:15 -18:25 0.17 STWHIP N WAIT WEXIT W. O. crew change. Nordic driller went for random drug test & derrickman is acting driller with no back-up derrickman. Meanwhile night crew is stuck across Kuparuk river due to Caribou laying on the bridge..... 18:25 - 19:20 0.92 WHIP N WEXIT Night crew technical limit meeting. Safety mtg re: MU BHA 19:20 - 20:00 0.67 STWHIP P WEXIT M/U window milling BHA #3 with a 3.80" HC DSM, DSR, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg. M/U injector. Repl two hydraulic hoses on injector 20:00 - 21 :55 1.92 STWHIP P WEXIT RIH wI BHA #3. Set down at 10447'-no jewelry. PU 45k, RIH clean. No wt loss thru XN. RIH to WS and tag at 10915' CTD 21 :55 - 22:05 0.17 STWHIP P WEXIT PUH 45k wI 6k overpull. Start motor 2.6/1500 RIH to pinch pt at 10913' CTD and had motor work. Corr to 10908.6' and flag 22:05 - 00:00 1.92 STWHIP P WEXIT Mill window from 10908.6-10912.8' 2.6/1500 7/11/2003 00:00 - 02:00 2.00 STWHIP P WEXIT Continue milling window from 10912.8-10915.6' and exit window 2.5/1550 02:00 - 02:35 0.58 STWHIP P WEXIT Drill formation 10915.6-10925' 2.7/1600 02:35 - 03:05 0.50 STWHIP P WEXIT Backream and ream window area. Dry tag, clean Official depths (for now) TOWS 10904', TOW 10908.6', BOW 10915.6', TD 10925' 03:05 - 05:00 1.92 STWHIP P WEXIT POOH for drilling assy, circ to surface 05:00 - 05:50 0.83 STWHIP P WEXIT LD milling assy. Mill and SR are in gauge. Load out BOT tools 05:50 - 07:00 1.17 DRILL P PROD1 Cut off 7' CT. MU DS CTC. PT 35k, 3500 psi 07:00 - 07:15 0.25 DRILL P PROD1 Held pre-spud meeting. Reviewed well plan & potential changes to trajectory. HAlHM on drilling BHA M/U procedures. 07:15 - 08:00 0.75 DRILL P PROD1 M/U build section BHA #4 with 2.83deg bend SR motor, MWD/GR & Bit #3 [Smith M09]. M/U injector. 08:00 - 10:30 2.50 DRILL P PROD1 RIH with BHA #4. No SHT due to hi motor bend. RIH to 10875'. Meanwhile swap well to Flopro mud. Wt check: Up wt = 44k, Dwn wt = 25k. TF = 170R. Run thru window clean with pumps down & tag btm @ 10930'. P/U & retag with pumps @ 10934'. Correct depth to 10925'. Check TF - @ 145L. Establish freespin @ 2.7bpm/3300psi. Printed: 7/22/2003 8:55:07 AM ,I' \ f BP Exploration Operations Summary Report Page 3 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N 1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/11/2003 10:30 - 10:45 0.25 DRILL P PROD1 Orient TF around to 120R. 10:45 - 11 :00 0.25 DRILL P PROD1 Begin drilling build section with 110R TF, 2.7/2.7bpm, 2900/3480psi & 32fph ave ROP. Drill to 10933'. 11 :00 - 12:55 1.92 DRILL P PROD1 Orient 1 click & drill to 10994' with 90-100R TF, 2.7/2.7bpm, 3300/3680psi & 33fph ave ROP. 12:55 - 13:50 0.92 DRILL P PROD1 Orient TF around to 80-90R. TF flops. PUH above window & reorient to 80R. RBIH & tag @ 10910'. P/U & retag @ 10909', 10915',10911' & 10915'. P/U & check TF @ 160R. RBIH thru to 10930'. TF flops again. Re-orient to 60R & RBIH to btm. 13:50 - 15:00 1.17 DRILL N DPRB PROD1 Attempt to drill on but motor stalls once btm is tagged. Observe angle change from 41degs to 47degs @ same depth (10974'). Also AZM magnetics is erratic. P/U heavy & overpull @ 10985'. Pull free @ 80k. Looks like whipstock has moved down on us. 15:00 - 15:10 0.17 DRILL N DPRB PROD1 PUH to 10870'. 15:10 - 15:20 0.17 DRILL N DPRB PROD1 Orient TF around to 70L. 15:20 - 15:30 0.17 DRILL N DPRB PROD1 RIH @ 70L & tag TOWS @ 10994.8' 15:30 - 17:00 1.50 DRILL N DPRB PROD1 POOH with drilling BHA. Meanwhile review forward plan with ANC & BOT. Decide not to fish W/S due to fishing tip being on HS. Call out for another WS. 17:00 - 18:55 1.92 DRILL N DPRB PROD1 RBIH to tie-in while wo vac trucks and WS 18:55 - 20:10 1.25 DRILL N DPRB PROD1 Park at 10860'. Chk TF @ 2.2/2740/79L. Log down to catch Shublik top GR character to 10886' and not recognizable. PUH to 10840' and relog down. Corr +9'. Continue log down 2.4/2960/79L. Stall at 10914.8' 20:10 - 20:35 0.42 DRILL N DPRB PROD1 Orient around to HS (twice) 2.5/3080/44L. RIH at min rate to 10927', clean 20:35 - 21 :45 1.17 DRILL N DPRB PROD1 Resume log down from 10910' 2.6/3200/44L. Incl at 47.3 deg or higher which is similar to mother WB and GR tracks same too. Start displ to KC!. No motor work until tagging WS at 10995.7' 2.5/3000/62L 21 :45 - 22:00 0.25 DRILL N DPRB PROD1 PUH 39k to 10984' and wait for KCI to exit bit 22:00 - 23:35 1.58 DRILL N DPRB PROD1 POOH displacing mud to KCI 23:35 - 00:00 0.42 DRILL N DPRB PROD1 LD drilling BHA. Bit was 0-6-1 7/12/2003 00:00 - 00:15 0.25 WHIP N DPRB WEXIT Safety mtg re: MU WS #2 assy (Baker Gen II) 00:15 - 01:15 1.00 WHIP N DPRB WEXIT Load WS and tools to floor. Load 2 RA pips. MU WS assy w/ MWD w/ #12 jet 01:15 - 03:20 2.08 WHIP N DPRB WEXIT RIH w/ BHA #5. SHT @ 4200' 03:20 - 04: 1 0 0.83 WHIP N DPRB WEXIT Log down from 10840' 2.1 /2246/35R to 10900'. Corr -5.5' to modified geo intrepretation of BHCS and collars on CBT using marker at 10835.5' as reference 04:10 - 04:25 0.25 WHIP N DPRB WEXIT Orient to LRS at 135R. RIH to 10910', then PUH 41 k to set depth at 10894' (allowing 3.5' CT stretch) to set TOWS at 1 0880' 04:25 - 04:40 0.25 WHIP N DPRB WEXIT Check TF 2.1/2250/138R. Incr pump rate to 3.1/4800. Bleed off press. Incr press and sheared at 3300 psi. Chk orientation at 155R. Slack off weight to verify set and WS was gone. RIH 20' to just above previous window and did not take wt 04:40 - 06:20 1.67 WHIP N DPRB WEXIT POOH to PU CT fishing tools 06:20 - 06:45 0.42 WHIP N DPRB WEXIT PJSM for LID whipstock setting BHA. 06:45 - 07:45 1.00 WHIP N DPRB WEXIT LID whipstock setting BHA. Meanwhile call for a S/Line unit & PDS caliper. 07:45 - 08:00 0.25 FISH N DPRB WEXIT Close swab & W. O. HOWCO S/Line unit. 08:00 - 08:45 0.75 FISH N DPRB WEXIT Spot S/Line unit. Review downhole status with HOWCO reps. Printed: 7/22/2003 8:55:07 AM f { BP Exploration Operations Summary Report Page 4 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7120/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/12/2003 08:00 - 08:45 0.75 FISH N DPRB WEXIT Prep & mobilize tools. 08:45 - 09:00 0.25 FISH N DPRB WEXIT Held PJSM with HOWCO S/L crew for slickline operations. 09:00 - 09:45 0.75 FISH N DPRB WEXIT R/U HOWCO unit for S/L job. 09:45 - 11 :00 1.25 FISH N DPRB WEXIT M/U 3.75" LIB, with 3.60" decentralizer on 0.125" S/Line. 11 :00 - 12:20 1.33 FISH N DPRB WEXIT RIH LIB BHA on S/L & set down @ 10909' SLM (window). Pulled 500lbs bind 3x. Jarred & pulled free. 12:20 - 13:30 1.17 FISH N DPRB WEXIT POOH with S/Line tools. 13:30 - 13:45 0.25 FISH N DPRB WEXIT LID 3.75" LIB & 3.60" decentralizer. 13:45 - 14:00 0.25 EVAL N DPRB WEXIT Held PJSM with S/L & PDS logging crews on caliper job. 14:00 - 14:15 0.25 EVAL N DPRB WEXIT M/U PDS caliper tools on 0.125" S/L. 14:15 - 15:50 1.58 EVAL N DPRB WEXIT RIH with PDS memory caliper logging tools to 10900' SLM. 15:50 - 16:00 0.17 EVAL N DPRB WEXIT Log up @ 50fpm from 10900' to 10400' SLM. 16:00 - 17:15 1.25 EVAL N DPRB WEXIT POOH with PDS memory caliper logging tools. 17:15 - 18:00 0.75 EVAL N DPRB WEXIT LID PDS caliper tools. Download data - caliper log shows inside of the 7" liner to be in good condition with a maximum 10 of 6.348". RID slickline unit. 18:00 - 19:15 1.25 WHIP N DPRB WEXIT MI SWS e-line. Load 2 pips in WS 19:15 - 19:30 0.25 WHIP N DPRB WEXIT Safety mtg re: RU 19:30 - 20:30 1.00 WHIP N DPRB WEXIT Load tools to floor. RU e-line, MU WS #3 (Baker Gen 1) 20:30 - 23:40 3.17 WHIP N DPRB WEXIT RIH wI WS #3 on e-line. Set at 10875.4' TOWS at 5R by BHCS. POOH wI setting tools 23:40 - 00:00 0.33 WHIP N DPRB WEXIT LD setting tools. RD floor tools 7/13/2003 00:00 - 01:10 1.17 STWHIP N DPRB WEXIT Cut off 100' CT. MO SWS e-line unit. Install BOT CTC. PT 35k, 3500 psi 01:10 - 01:45 0.58 STWHIP N DPRB WEXIT Safety mtg. MU milling BHA 01 :45 - 04:00 2.25 STWHIP N DPRB WEXIT RIH wI BHA #6 (3.80" WM and SR). Tag pinch pt at 10878' CTD wI 3.5k. PUH 41 k wI 10k overpull. Start motor 2.5/1170. First motor work at 10877 .6'. Corr to 10880' and flag 04:00 - 06:30 2.50 STWHIP N DPRB WEXIT Mill window from 10880' 2.5/1200. Got fair btms up gas back (assume check valve in IBP still works). Divert 60 bbls to flowback tank. Mill to 10883.6'. 06:30 - 07:20 0.83 STWHIP N DPRB WEXIT Mill to 10884.8' with 2.5/2.5bpm, 1130/1375psi, 1-2k WOB & 2.5fph ave ROP. Pump 10bbls biozan sweep. P/U clean @ 37k & ease back into milling. 07:20 - 08:30 1.17 STWHIP N DPRB WEXIT Mill to 10886.4' with 2.5/2.5bpm, 1140/1430psi, 1-2k WOB & 2fph ave ROP. Pump 10bbls biozan sweep. P/U clean @ 37k & ease back into milling. See pressure rise & drop as SR exits BOW from 10885.4' to 10886.4'. TOW 08:30 - 09:30 1.00 STWHIP N DPRB WEXIT Control mill formation to 10888' with 2.5/2.5bpm, 1140/1260psi, <1 k WOB & 1fph ave ROP. 09:30 - 10:25 0.92 STWHIP N DPRB WEXIT Mill formation to 10896' with 2.5/2.5bpm, 1140/1420psi, 2k WOB & 20fph ave ROP. Pump 10bbls biozan sweep. Window depths: TOWS=10875.4', TOW=10880', BOW=10886', TD=10896'. 10:25 - 11:45 1.33 STWHIP N DPRB WEXIT Swap wellbore to 8.6 ppg flopro mud. Meanwhile backream/ream window & rat hole 3x - & drift without pumping. Window looks clean. 11 :45 - 13:45 2.00 STWHIP N DPRB WEXIT POOH window milling BHA#6 with EOP flag @ 10796.9'. 13:45 - 14:45 1.00 STWHIP N DPRB WEXIT PJSM. LID BHA#6 & inspect mills. DSM gauge 3.80" no-go while SR gauge same as run - 3.79" go I 3.78" no-go. Wear on DSM face indicates center crossed the 7" wall. 14:45 - 15:00 0.25 DRILL N DPRB PROD1 PJSM & HA/HM for M/U drilling BHA. 15:00 -16:15 1.25 DRILL N DPRB PROD1 M/U build section BHA #7 with 2.83 deg bend SR motor, Printed: 7/22/2003 8:55:07 AM ~: { BP Exploration Operations Summary Report Page 5 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N 1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/13/2003 15:00 -16:15 1.25 DRILL N DPRB PROD1 MWD/GR & used Smith M09 3-3/4" Bit #5. Rehead & M/U OS CTC. Pull & pressure test. Meanwhile OS Mecahnic checks/calibrates P-14 charge pressure on power pack. 16:15 -18:40 2.42 DRILL N DPRB PROD1 RIH with BHA #7 while calibrating power pack hydraulics. 18:40 - 19:05 0.42 DRILL N DPRB PROD1 See flag at 10867.6' (5' deep to calc). Chk TF at 178L. Orient to 6R. RIH thru window w/ nary a bobble and tag TO at 10902'. Corr to 10896'. Orient to drill 19:05 - 21 :30 2.42 DRILL N DPRB PROD1 Drill turn from 10896' 2.5/3130/1 OOR w/ slow penetration rate due to stacking and stalling while getting started in Shublik. Drill to 10933' and penetration rate picked up after BHA started following new hole Spill drill-discuss 21 :30 - 23:25 1.92 DRILL N DPRB PROD1 Drill turn from 10933' 2.6/3350/120R to 10968' 23:25 - 00:00 0.58 DRILL N DPRB PROD1 Orient around 7/14/2003 00:00 - 00:10 0.17 DRILL N DPRB PROD1 Survey at 10966' (marginal keeper) 00:10 - 01:20 1.17 DRILL N DPRB PROD1 Drill from 10968' 2.5/3320/100-11 OR 01 :20 - 01 :55 0.58 DRILL P PROD1 10995' 2.5/3340/120R Drill to 11010' Back to where we were at 1350 hrs 7/11/03 (59 hrs 30 min ago) 01 :55 - 02:30 0.58 DRILL P PROD1 Wiper to window. Log tie-in up from 10920-10889'. No corr 02:30 - 03:30 1.00 DRILL P PROD1 Orient around (twice, then a few more clicks. Having to go to window each time) 03:30 - 05:20 1.83 DRILL P PROD1 Drill from 11010' 2.5/3340/62R and penetration rate picking up. GR starting to show Eileen sand. Drill to 11099' and stacking 05:20 - 05:45 0.42 DRILL P PROD1 Wiper to window 05:45 - 06:50 1.08 DRILL P PROD1 Drill from 11099' 2.6/3380/50R. Drill to 11144'. Stacking wt. 06:50 - 07:00 0.17 DRILL P PROD1 Short 100' wiper. 07:00 - 08:00 1.00 DRILL P PROD1 Drill to 11185' with 45R TF, 2.7/2.7bpm, 3150/3720psi & 35fph ave ROP. May be in a fault zone. 08:00 - 08:30 0.50 DRILL P PROD1 Wiper to window while ANC team evaluate fault/structural situation. RBIH clean. Geo confirms that we're drilling parallel to fault zone & further drilling will be as per revised directional plan #7. 08:30 - 09:00 0.50 DRILL P PROD1 Orient TF around to 70L. Plan to exit the fault zone with hi-bend motor before tripping for lateral BHA. 09:00 - 09:25 0.42 DRILL P PROD1 Drill to 11206' with 65L TF, 2.7/2.7bpm, 3150/3720psi & 50fph ave ROP. ROP indicates we've exited fault zone. 09:25 - 09:30 0.08 DRILL P PROD1 Orient TF to 20L to avoid drilling into the POWC. 09:30 - 09:45 0.25 DRILL P PROD1 Drill & land section @ 11221' with HS TF, 2.7/2.7bpm, 3150/3720psi & 40fph ave ROP. 09:45 - 10:00 0.25 DRILL P PROD1 POOH for lateral BHA. POOH clean to window. 10:00 - 10:50 0.83 DRILL P PROD1 Log up GR from 10920' to 10905'. PUH above window & log up from 10865' to 10820'. Added 5' to CTD. Window & RA PIP tag depths remain unchanged. 10:50 - 12:40 1.83 DRILL P PROD1 Continue POOH for lateral BHA. 12:40 - 13:00 0.33 DRILL P PROD1 PJSM for BHA changeout. 13:00 - 14:30 1.50 DRILL P PROD1 C/O MWD tools & P/U RES tool. Adjust motor bend to 1.04degs. M/U used HYC DS49 Bit #6. M/U injector. 14:30 - 15:00 0.50 DRILL N SFAL PROD1 RIH with lateral MWD/RES BHA #8 with 1.04 deg motor & used DS49 Bit #6 to 250'. Observe CT reel drive shaft axle shear off from the ODS mounted drive plate. Evaluate situation. 15:00 - 15:30 0.50 DRILL N SFAL PROD1 POOH with lateral BHA to surface. 15:30 - 19:45 4.25 DRILL N SFAL PROD1 PJSM. Work on broken reel axle. Meanwhile circulate across Printed: 7/22/2003 8:55:07 AM ~ BP Exploration Operations Summary Report Page 6 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/14/2003 15:30 - 19:45 4.25 DRILL N SFAL PROD1 the WHD to keep hole full. 19:45 - 21 :50 2.08 DRILL P PROD1 RIH w/ BHA #8 (at 4000' geo's advise we need to avoid tip out of fault and instead of drilling left, will need to turn right. It will be close with this motor) 21:50 - 22:10 0.33 DRILL P PROD1 Precautionary ream 2.5/3550/35L to TD tagged at 11239.5' CTD. Corr to 11221'. Reset mode to log MAD pass 22: 10 - 00:00 1.83 DRILL P PROD1 Log up from TD to 10945' and Res shows wet. Swap to GR mode, then log tie-in to WS RA 7/15/2003 00:00 - 00:40 0.67 DRILL P PROD1 Continue log GR tie-in. Add 3.5' 00:40 - 00:50 0.17 DRILL P PROD1 RIH to drill 2.4/3220/73R 00:50 - 01 :25 0.58 DRILL N SFAL PROD1 Ream hole while Sperry reboots after power surge. Tag TD at 11222' (8915' TVD) 01 :25 - 02:00 0.58 DRILL P PROD1 Orient to drill right side. Go to window for clicks 02:00 - 02:30 0.50 DRILL P PROD1 Drill from 11222' 2.4/3250/50R to 11242' and stacking w/ overpulls 02:30 - 02:40 0.17 DRILL P PROD1 Ream TF change area 02:40 - 03:45 1.08 DRILL P PROD1 Drill from 11242' 2.4/3260/50R to 11284' 03:45 - 04: 1 0 0.42 DRILL P PROD1 Orient to continue turn 04:10 - 04:30 0.33 DRILL P PROD1 Drill from 11284' 2.5/3360/79R to 11305' and stacking 04:30 - 05:00 0.50 DRILL P PROD1 Wiper to window 05:00 - 06:00 1.00 DRILL P PROD1 Drill from 11284' 2.4/3290/79R. Sticky from 11305'. Drill to 11361' 06:00 - 06:25 0.42 DRILL P PROD1 200' wiper, clean 06:25 - 06:50 0.42 DRILL P PROD1 Drill from 11361' 2.3/3200/80R. Drill to 11379'. 06:50 - 07: 10 0.33 DRILL P PROD1 Drill to 11386' with 75R TF, 2.7/2.7bpm, 3700/4100psi & 20fph ave ROP. 07:10 - 07:30 0.33 DRILL P PROD1 Wiper clean to 10940'. 07:30 - 07:50 0.33 DRILL P PROD1 Log up GR & tie-into RA PIP tag [+10' CTD correction.] 07:50 - 07:55 0.08 DRILL P PROD1 PUH & park bit @10847'. 07:55 - 08:05 0.17 DRILL N RREP PROD1 DS Mechanic C/O filter on P-14 charge pump on power pack. 08:05 - 08:35 0.50 DRILL P PROD1 RBIH & tag WIS. PUH & orient to HS. Run thru window clean & RIH to btm. 08:35 - 08:45 0.17 DRILL P PROD1 Orient TF to 80R. 08:45 - 08:55 0.17 DRILL P PROD1 Drill to 11400' with 75R TF, 2.7/2.7bpm, 3700/4100psi & 40fph ave ROP. Differentially sticking. 08:55 - 09:10 0.25 DRILL P PROD1 Orient TF to 80L. 09:10 -10:10 1.00 DRILL P PROD1 Drill to 11424' with 70L TF, 2.7/2.7bpm, 3700/4100psi & 20fph ave ROP. Pump down fresh mud out of bit & take off drilling. 10:10 - 10:30 0.33 DRILL P PROD1 Drill to 11453' with 70L TF, 2.7/2.7bpm, 3700/4000psi & 90fph ave ROP. 10:30 - 10:55 0.42 DRILL P PROD1 Orient TF to 80L. 10:55 - 11 :25 0.50 DRILL P PROD1 Drill to 11501' with 85L TF, 2.7/2.7bpm, 3600/3900psi & 95fph ave ROP. 11 :25 - 11 :40 0.25 DRILL P PROD1 Orient TF around to 90R. 11:40 - 12:20 0.67 DRILL P PROD1 Drill to 11534' with 80-1 OOR TF, 2.7/2.7bpm, 3600/3900psi & 50fph ave ROP. 12:20 -12:35 0.25 DRILL P PROD1 Orient & drill to 11554' with 100-120R TF, 2.7/2.7bpm, 3600/3900psi & 80fph ave ROP. 12:35 - 13:20 0.75 DRILL P PROD1 Wiper clean clean to window. RBIH to btm. 13:20-14:15 0.92 DRILL P PROD1 Orient & drill to 11626' with 95R TF, 2.7/2.7bpm, 3600/3900psi & 80fph ave ROP. 14:15 -14:35 0.33 DRILL P PROD1 Orient TF to 80R. 14:35 - 15:05 0.50 DRILL P PROD1 Drill to 11686' with 80R TF, 2.7/2.7bpm, 3400/3900psi & Printed: 7/22/2003 8:55:07 AM ( BP Exploration Operations Summary Report Page 7 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/15/2003 14:35 - 15:05 0.50 DRILL P PROD1 100fph ave ROP. 15:05-15:50 0.75 DRILL P PROD1 Wiper to window 15:50 - 16:15 0.42 DRILL P PROD1 Orient around 16:15 - 17:45 1.50 DRILL P PROD1 Drill from 11686' 2.7/3440/90R to 11833' (8827' TVD) 17:45 - 18:15 0.50 DRILL P PROD1 Wiper to window 18:15 - 18:35 0.33 DRILL P PROD1 Log up from 10940'. Add 7.5' 18:35 - 19:10 0.58 DRILL P PROD1 RIH to TD and tag at 11836' 19:10 - 19:35 0.42 DRILL P PROD1 Orient around to drill left side 19:35 - 20:00 0.42 DRILL P PROD1 Drill from 11836' 2.5/3250/79L to reach 8810' TVD. Will decide then where to drill rest of well after seeing resistivity. Looking rather wet so far. . .(105' TVD). Drill to 11875' 20:00 - 20:20 0.33 DRILL P PROD1 Orient around 20:20 - 20:50 0.50 DRILL P PROD1 Drill from 11875' 20:50 - 21 :05 0.25 DRILL P PROD1 11905', Geo concerned we are near the top of Z4. Orient around to hold angle. Orient to 152 L, Inc=97 deg. 21 :05 - 21 :45 0.67 DRILL P PROD1 Resume drilling. Pit vol=298 bbls. IAP=780 psi, OAP=290 psi. 2.5/2.6/3230 psi free spin. Drilling at 3520 psi, 120 fph ROP. 21 :45 - 21 :50 0.08 DRILL P PROD1 11940', TVD=8814', Geo happy. Orient to hold 90 deg at the bit. 21 :50 - 22:10 0.33 DRILL P PROD1 Drill ahead. 22: 1 0 - 22:30 0.33 DRILL P PROD1 Need to orient all the way around to hold 90 deg. 22:30 - 23:10 0.67 DRILL P PROD1 Drill ahead. 23:10 - 00:00 0.83 DRILL P PROD1 12000', Wiper trip to shoe. 7/16/2003 00:00 - 00:10 0.17 DRILL P PROD1 Continue wiper trip back in hole. No problems up or back down on wiper. 00: 1 0 - 00:20 0.17 DRILL P PROD1 Orient to resume drilling at a 91 degree inc. 00:20 - 00:50 0.50 DRILL P PROD1 12000', Drill ahead 00:50-01:15 0.42 DRILL P PROD1 Orient to 130L to drop angle for invert section. 01:15 - 02:10 0.92 DRILL P PROD1 Resume drilling. 02: 1 0 - 02:25 0.25 DRILL P PROD1 12074', Pick up to orient. 02:25 - 03:00 0.58 DRILL P PROD1 Resume drilling. 03:00 - 04:00 1.00 DRILL P PROD1 12102' Orient. Having trouble with orienter. 04:00 - 06:10 2.17 DRILL N DFAL PROD1 Attempt to resume drilling. Orienter keeps flopping. Looks like the orienter is not locking properly. POH for new orienter. 06:10 - 08:15 2.08 DRILL N DFAL PROD1 Stand back injector, PJSM. Lay down BHA #8. Download res tool. Found seal failure in orientor 08:15 - 14:00 5.75 BOPSUR P PROD1 Weekly BOPE test. Witness waived by AOGCC 14:00 - 15:05 1.08 DRILL N DFAL PROD1 Fill hole w/ 6 bbls. MU drilling BHA. Upload resistivity 15:05 - 17:10 2.08 DRILL N DFAL PROD1 RIH w/ BHA #9 (1.04 deg motor) SHT 17:10 - 17:20 0.17 DRILL N DFAL PROD1 Log tie-in up from 10945' 2.6/3300/64R Corr -10' 17:20 - 18:00 0.67 DRILL N DFAL PROD1 Precautionary ream 2.4/3000 to TD and tag at 12110'. Had a little btms up gas 18:00 - 18:30 0.50 DRILL P PROD1 Orient around from 60R 18:30 - 18:45 0.25 DRILL P PROD1 12106', Resume drilling. Pit vol=236 bbls. IAP=83 psi, OAP=34 psi. Drilling ahead. 18:45 - 19:05 0.33 DRILL P PROD1 12129', Tool face flopped around 180 degrees. Orient back to 20L. It worked fine for 23', then started acting. It keeps flopping. Looks similar to previous failure mode on last run. Take 4 clicks off bottom, got 170 degrees of orienter rotation. (Should have been only 80 degrees). 19:05 - 19:40 0.58 DRILL P PROD1 Tag bottom, resume drilling. Free spin 3200 psi at 2.5 bpm. Drilling at 2.5/2.6/3524 psi. Pit vol=234 bbls. Have called for 80 bbls of used mud back to top off pits. Continuing to loose Printed: 7/22/2003 8:55:07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 7/16/2003 7/17/2003 Date I~ ~ BP Exploration Operations Summary Report W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task Code NPT Phase 19:05 - 19:40 19:40 - 20:00 20:00 - 22:10 22:10 - 23:05 23:05 - 23:15 23:15 - 23:30 23:30 - 23:50 23:50 - 00:00 00:00 - 00:05 00:05 - 00:45 00:45 - 01 :05 01 :05 - 02:40 02:40 - 04:15 04: 15 - 04:30 04:30 - 06:25 06:25 - 07:10 07:10 - 07:40 07:40 - 08:30 08:30 - 09:00 09:00 - 09:45 09:45 - 10:10 10:10 -10:45 10:45 - 11 :05 11 :05 - 11 :45 11 :45 - 12:20 12:20 - 14:00 14:00 - 14:15 14:15 -15:00 15:00 - 15:25 15:25 - 17:15 17:15 - 17:25 17:25 - 18:10 18:10 -18:20 18:20 -19:15 19:15 -19:25 19:25 - 21 :00 21 : 00 - 21 : 1 0 21 : 1 0 - 21 :45 21 :45 - 22:35 0.58 DRILL P 0.33 DRILL P PROD1 PROD1 2.17 DRILL P 0.92 DRILL P PROD1 PROD1 0.17 DRILL P 0.25 DRILL P 0.33 DRILL P PROD1 PROD1 PROD1 0.17 DRILL P 0.08 DRILL P 0.67 DRILL P PROD1 PROD1 PROD1 0.33 DRILL P 1.58 DRILL P 1.58 DRILL P PROD1 PROD1 PROD1 0.25 DRILL P 1.92 DRILL P 0.75 DRILL P 0.50 DRILL P 0.83 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 0.50 DRILL P 0.75 DRILL P 0.42 DRILL P PROD1 PROD1 PROD1 0.58 DRILL P PROD1 0.33 DRILL P 0.67 DRILL P PROD1 PROD1 0.58 DRILL N 1.67 DRILL N 0.25 DRILL N 0.75 DRILL P 0.42 DRILL N 1.83 DRILL N 0.17 DRILL N 0.75 DRILL N DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 0.17 DRILL P 0.92 DRILL P 0.17 DRILL P 1.58 DRILL P PROD1 PROD1 PROD1 PROD1 0.17 DRILL P 0.58 DRILL C 0.83 DRILL C PROD1 PROD1 PROD1 Page 8 of 12 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/911990 End: 7/20/2003 Description of Operations mud at about 2 bbl/hr. 12160', Orient around to hold angle at 90 deg. Orienter worked fine. Resume drilling. Getting 50 deg reactive torque. 12251', wiper trip to shoe. Slight overpull off bottom. Slightly sticky at 11470'. Tight spot at 12,000' when running back in hole. Ream tight spot. Orient to 65L. Resume drilling. 2.4/2.5/3670 psi. Pit vol=308 bbls after delivery of 80 bbls of used mud. ROP=80 fph. Orient around. Orient around. 12275', Resume drilling. 2.5/2.5/3840 psi. Free spin 3250 psi. Pit vol=306 bbls. IAP=146,OAP=92. ROP=80 fph. 12310', Orient around. Resume drilling. ROP=70 fph. 12378', Wiper trip to the shoe. Weight bobble at 12010' when RIH. Orient to 60R. Drilling ahead. 2.3/2.4/3600 psi. Taking on new mud. 12518', Wiper trip to shoe. Log tie-in from 10940'. Add 13.0' RIH w/ set down at 12000'. Ream thru, RIH and tag at 12520' PVT 310 Orient around from 138R Drill from 12520' 2.7/3500/75R to 12561' Wiper while determine where we are in relation to revised seismic intrepretation of fault in NW corner of polygon, and with the possibility of extending TD outside of the polygon by 1 00-200' Drill from 12561' 2.8/3600/81 R to 12592' Motor is starting to lose stator rubber Orient around to drill left side Drill from 12592' 2.7/3500/94L to 12613'. Motor is weak PVT 295 Wiper to window POOH for motor Change motor Rig evacuation drill-H2S. Discuss MU BHA RIH w/ BHA #10 (1.04 deg motor) Log up from 10945' 2.2/2660/93R Corr -13' Precautionary ream to TD tagged at 12615' 2.7/3300/145L. No set downs, but a few bobbles Orient to drill PVT 267 Drill from 12615' 2.7/3300/80L 1 OO'/hr continuing slow drop 12675', 100' wiper. Free spin=3000 psi at 2.5 bpm. Resume drilling. 2.5/2.6/3276 psi. Pit vol=260 bbls. IAP=218, OAP=140. ROP=65 fph. 12747', Orient to high side to bring INC to 90 deg. Continue drilling. (AFE'd TD was 12750') 12798', Wiper trip to shoe. 10k overpull off bottom. May be Printed: 7/22/2003 8:55:07 AM ( ~ BP Exploration Operations Summary Report Page 9 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/17/2003 7/18/2003 W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 From - To Hours Task Code NPT Phase Description of Operations 21 :45 - 22:35 0.83 DRILL C PROD1 differential sticking. Pit vol=248 bbls. 22:35 - 22:50 0.25 DRILL C PROD1 Log tie in pass accross GR spike near window. Make +8'. 22:50 - 23:45 0.92 DRILL C PROD1 RIH to finish wiper trip. Saw weight bobbles and motor work at 11495', and 12350' while RIH. 23:45 - 00:00 0.25 DRILL C PROD1 Resume drilling. We appear to have entered the water leg on this well. Plan forward is to build angle back up into the oil. 00:00 - 00: 15 0.25 DRILL C PROD1 Continue drilling ahead. IAP=280 psi, OAP=229 psi. Pit vol=241 bbls. Drilling at 2.5/2.5/3200. 00: 15 - 00:20 0.08 DRILL C PROD1 12823', Orient to 90R to hold 95 deg build angle. 00:20 - 00:50 0.50 DRILL C PROD1 Drill build back up into oil leg. 00:50 - 01 :00 0.17 DRILL C PROD1 12850', Orient TF down to change build angle down to 90 deg. 01 :00 - 01 :20 0.33 DRILL C PROD1 Resume drilling. Pit vol=234 bbls. 01 :20 - 01 :50 0.50 DRILL C PROD1 Sticky off bottom. Make 500' wiper trip to clean up hole a little. 01:50 - 02:10 0.33 DRILL C PROD1 Resume drilling. 02:10 - 02:15 0.08 DRILL C PROD1 Orient to 90R to hold horizontal. 02: 15 - 02:30 0.25 DRILL C PROD1 Resume drilling. Sending 100 bbls of new mud downhole to see if it improves sliding. 02:30 - 03:30 1.00 DRILL P PROD1 12900', We appear to be back into the water as we drill up. Call this TD. Wiper trip to window for tie in. 03:30 - 03:55 0.42 DRILL P PROD1 Log tie in pass over Gamma Ray spike near window. Make a +11.5' correction. 03:55 - 04:40 0.75 DRILL P PROD1 RIH for final tag. Weight bobble at 11950'. 04:40 - 07:30 2.83 DRILL P PROD1 Tag bottom at 12904'. POOH. Slick up thru window. Continue POH. Flags at 8400' and 10400' EOP 07:30 - 07:40 0.17 DRILL P PROD1 Safety mtg re: LD drilling BHA 07:40 - 09:00 1.33 DRILL P PROD1 LD drilling BHA. Download resistivity data Kick drill 09:00 . 09:30 0.50 DRILL P PROD1 Load out drilling tools 09:30 - 10:00 0.50 CASE P PROD1 Load liner tools to floor 10:00 -10:15 0.25 CASE P PROD1 Safety mtg re: liner 10:15-10:30 0.25 CASE P PROD1 RU to run liner 10:30-12:10 1.67 CASE P PROD1 MU 60 jts 2-7/8" 6.16# L-80 STL liner wI pups and float equipment. 12:10 - 12:30 0.33 CASE P PROD1 Safety mtg re: DS crew chglliner 12:30 - 14:00 1.50 CASE P PROD1 MU 17 jts 3-3/16" 6.2# L-80 TC11 liner, XO's, X nipple. MU BOT CTLRT 14:00 - 14:35 0.58 CASE P PROD1 Cut off CTC. Install BOT CTC. PT @ 35k, 3500 psi 14:35 - 16:00 1.42 CASE P PROD1 RIH wI liner assy. See flag at 1 0815'·did not correct -21' 16:00 - 16:55 0.92 CASE P PROD1 Set down at 11275' several times. Bend pipe to fit hole, then RIH wI multiple set downs each at 11396', 11840', 11884', 12355',12550',12710'. See flag at 12796' and did not corr -15'. RI H wI liner to TD tagged at 12916' CTD. Recip 40' at 60k. Corrto 12904'. Circ 10 bbls at 1.2/2140 TOL @ 10516', PBD 12870' 16:55 - 17:30 0.58 CASE P PROD1 Load 5/8" steel ball and circ to seat. 2.5/2700, 0.8/1870 Ball seat sheared at 4380 psi. PUH 32k and released from liner 17:30 -19:15 1.75 CASE P COMP Start displacement to KCI 2.5/2700 19:15 - 20:15 1.00 CASE P COMP Finished swapping well to KCL. Got KCL returns to surface. 2.4/2.0/1690 psi. Loosing returns with KCL in place. 83% returns. Blow remainder of KCL into pits. Mix biozan pill for cement cleanup. 20:15 - 20:35 0.33 CEMT C COMP Safety meeting prior to pumping cement. Attended by cementers, Nordic and SWS rig hands, Veco vac truck driver, Printed: 7/22/2003 8:55:07 AM \ {" BP Exploration Operations Summary Report Page 10 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/18/2003 20:15 - 20:35 0.33 CEMT C COMP SWS TL, BP Co. Man. Discuss process of job. Hazards, and mitigations. 20:35 - 21 :30 0.92 CEMT C COMP Circulating KCL waiting on cementer to batch up. Pumping 1.3/1.0/500 psi. 21 :30 - 22:30 1.00 CEMT C COMP On line with cementers. Pump 3 bbls of water to warm and fluid pack lines. SI at rig. PT hardlines to 4000 psi. Passed ok, no leaks. Open to coil. Pump 28 bbls of 15.8 ppg class G cement, 4 hours thickening time, rest of parameters as specified in proceedure. Displacing cement at 2.0/1.7/1220 psi. sr. drop dart, suck lines back to cement pumper via vac truck. Come on line with biozan using rig pumps. Displace biozan at 2.8/2.5/1350 psi. Cement to shoe at 45.9 bbls behind dart. Land dart at 59.5 (Calculated 59.4). Displace cement. Getting 80% returns until 17 bbls away, 1 for 1 after that. Pumped 28 bbls cement, lost 2.8 to formation, got 25.2 bbls behind pipe. Calculated annular vol was 24.9 bbls, should have 0.3 bbls over the top of the deployment slv. Perfect cement job. CIP at 22:30. 22:30 - 00:00 1.50 CEMT P COMP Pressure up on coil, pull out of CTLRT. PU weight was 34 klbs. Pump 2 bbls of bio, then POH replacing displacement with biozan. 7/19/2003 00:00 - 00:15 0.25 CEMT P COMP Continue POH with CTLRT. 00:15 - 01:00 0.75 CEMT P COMP Tag up at surface. Stand back injector. Lay down cementing eq. All recovered ok. 01 :00 - 01: 15 0.25 EVAL C COMP PU SWS MCNL logging eq, rig up depth encoder to injector. 01: 15 - 01 :30 0.25 EVAL C COMP PJSM prior to picking up MCNL and running CSH work string. 01 :30 - 03:30 2.00 EVAL C COMP Make up MCNL tool to first joint of CSH. Install radioactive logging source. RIH with 78 joints of CSH work string. 03:30 - 03:55 0.42 EVAL C COMP Make up SWS MHA and injector. 03:55 - 05:20 1.42 EVAL C COMP RIH with MCNL tool. 05:20 - 06:45 1.42 EVAL C COMP Log down from 10400', pumping at 2.0 bpm, 3300 psi. Logging at 30 fpm. Got positive indication of cement when we got bottoms up from the liner top. Good indication that we have a good cement job. 06:45 - 07:30 0.75 EVAL C COMP Tag PBD at 12877' CTD. Wait for pill to exit noz. Start saving returns-dumped 70 bbls cement contaminated KCI. Begin log up at 60'/min while leaving fresh hi LSRV mud in liner 07:30 - 09:00 1.50 EVAL C COMP POOH w/ CT 09:00 - 09:15 0.25 EVAL C COMP Safety mtg re: CSH 09:15 -11:00 1.75 EVAL C COMP LD 20 jts CSH. Satndback 29 stds 11 :00 - 11: 15 0.25 EVAL C COMP Safety mtg re: source 11: 15 - 11 :30 0.25 EVAL C COMP LD CNL tools and load out 11 :30 - 12: 15 0.75 PERF C COMP Load perf guns in pipeshed. Cmt compr str=300 psi. Fax log for analysis TOL @ 10509', PBD @ 12865' ELMD 12:15 - 14:45 2.50 PERF C COMP WO revised perf intervals and/while WOC 14:45 - 16:15 1.50 PERF C COMP WOC 16:15 - 17:00 0.75 PERF C COMP Cement compressive str=2000 psi PT wellbore to 2000 psi w/1.5 bbls for 30 min Initial WHP 1986 psi, IA 34, OA 20 5 min 1970, 39, 20 30 min 1935, 39, 20 Bleed off press Printed: 7/22/2003 8:55:07 AM ( ( BP Exploration Operations Summary Report Page 11 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/19/2003 17:00 - 18:15 1.25 PERF C COMP WO perf guns. Make final adjustments to perf gun running order 18:15 - 18:45 0.50 PERF C COMP Crew change/safety mtg 18:45 - 19:00 0.25 PERF C COMP Safety meeting prior to picking up perf guns. 19:00 - 21 :30 2.50 PERF C COMP Begin deploying perf guns. Kick drill on gun #2. Deployed safety joint and secured well properly and safely. Stand down from drill, discuss drill. Resume deploying guns. 21 :30 - 21 :45 0.25 PERF C COMP Toolbox talk prior to running CS hydril work string. 21 :45 - 22:15 0.50 PERF X SFAL COMP Begin making up CS Hydril work string. Little jerk tongs are not working. Shutdown operations. LockouUtagout powerpack. Bleed hydraulics to LJ tongs. Disconnect hydraulic hoses. Repair tongs. 22:15 - 23:00 0.75 PERF C COMP Tongs repaired, continue RIH with CSH work string. 23:00 - 23: 15 0.25 PERF C COMP Make up SWS MHA and injector. 23:15 - 00:00 0.75 PERF C COMP RIH with perf guns on coil tubing. 7/20/2003 00:00 - 00:55 0.92 PERF C COMP Continue RIH with perf guns on CS hydril work string and coil tubing. 00:55 - 01 :40 0.75 PERF C COMP Tag bottom. Set depth on up weight to ELM PBTD of 12865'. Made a -1.5' correction. Pull up into ball drop position. Pump 9 bbls of Flopro mud. Drop 5/8" steel ball. Chase with 10 bbls Flopro while RIH back to firing depth of 12850.7'. Chase mud with KCL. Ball on seat at 56.5 bbls (Coil vol=59.4). Good indication of fire. Guns moving at fire. Interval perforated is; 11470-11525 11720-11820 11850-11985 12020-12330 12360-12680 12710-12740 12780-12850 01 :40 - 03:30 1.83 PERF C COMP POH with coil tubing. 03:30 - 03:45 0.25 PERF C COMP Tag up at surface. PJSM prior to standing back injector and laying out CS hydril. 03:45 - 05:00 1.25 PERF C COMP Stand back injector, layout 58 joints of CS hydril work string. 05:00 - 05:20 0.33 PERF C COMP Safety meeting prior to rigging down SWS perf guns. 05:20 - 06:20 1.00 PERF C COMP Lay down SWS perf guns. 06:20 - 07:00 0.67 PERF C COMP Safety mtg re: spent perf guns 07:00 - 09:15 2.25 PERF C COMP Fin LD perf guns-all shots fired 09:15-10:15 1.00 PERF C COMP Clear floor of tools. Load out perf guns Wave at DS/N #2 10:15-11:45 1.50 WHSUR P COMP MU nozzle BHA. RIH and freeze protect wellbore w/ MeOH from 2000'. POOH 11 :45 - 13: 15 1.50 RIGD P POST MIRU DS N2 pumper from Kuparuk. PJSM. PT 3000 psi. Blow down CT w/ N2 and bleed off. Vac pits 13:15 - 13:30 0.25 RIGD P POST Safety mtg re: unstab CT 13:30 - 15:00 1.50 RIGD P POST Cut off CTC. Install clamps. Pull CT to reel and chain off. 15:00 - 17:00 2.00 RIGD P POST Rig Released at 1500 hrs 7/20/2003 Remove gooseneck. Prep injector for removal. Breakdown hardline in reel house 17:00 - 18:00 1.00 RIGD P POST Hazard Recognition Training 18:00 - 18:30 0.50 RIGD P POST TL meeting/crew XO 18:30 - 21 :30 3.00 RIGD P POST Continue with nippling down stack, cleaning pits. 21 :30 - 23:30 2.00 RIGD P POST Stand down rig for safety training. Review the lifting video of Printed: 7/22/2003 8:55:07 AM ( ( BP Exploration Operations Summary Report Page 12 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-16 W-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/8/2003 Rig Release: 7/20/2003 Rig Number: N1 Spud Date: 5/9/1990 End: 7/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/20/2003 21 :30 - 23:30 2.00 RIGD P POST the 8 golden rules, followed by discussion. 23:30 - 00:00 0.50 RIGD P POST Prepare rig to move off well. Further telex entries will be entered into Nordic 1 2003 Summer Shutdown. Printed: 7/22/2003 8:55:07 AM ( ~ If r903-' Ice) 08-0ct-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Redistribution due to API change Re: Distribution of Survey Data for Well W-16A PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 10,823.20 I MD Window / Kickoff Survey: 10,904.00' MD (if applicable) Projected Survey: 10,994.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) r" \,~) ~~ C-.- ~.~~ '{\~VJ Sperry-Sun Drilling Services ~ North Slope Alaska BPXA PBU WOA W Pad W-16APB1 Job No. AKMW0002548805, Surveyed: 11 July, 2003 Survey Report 6 October, 2003 ~~C3'- )aJ JEF N -V: ~'··';i ,e:; E ~ \f'i~' ~j. OCT 1 n 'v r, -'",- ,.-.'-' (. \),;.) J~i£~s~a :~j~'i E; (.;;u~~~ ~~~.:r~;;~. (,-;c<'~-lmí3g~Cn /ind!0r1:TU ~, Your Ref: API 500292204570 Surface Coordinates: 5959455.89 N, 612049.21 E (70017' 53.4404" N, 149005' 33.2886" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959455.89 N, 112049.21 E (Grid) Surface Coordinates relative to Structure Reference: 2229.65 N, 2167.29 E (True) Kelly Bushing: 90.48ft above Mean Sea Level Elevation relative to Project V Reference: 90.48ft Elevation relative to Structure Reference: 90.48ft SpE!I'r'"'Y-5UFl DRILLING' SERViCes A Halliburton Company ---..... ~ ..., Survey Ref: svy4080 DrillQuest 3.03.02.005 Page 2 of3 6 October, 2003 - 15:44 Tie On Point Window Point Projected Survey 4444.73 E 4496.80 E 4539.17 E 1060.09 S 1090.02 S 1132.74S 8787.78 8841.83 8907.59 10823.20 10904.00 10994.00 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) ~ Comments Based upon Minimum Curvature type calculations, at a Measured Depth of 10994.00ft., The Bottom Hole Displacement is 4678.38ft., in the Direction of 104.012° (True). Magnetic Declination at Surface is 25.584°(09-Jul-03) The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). 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. Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-16APB1 Your Ref: API 500292204570 Job No. AKMW0002548805, Surveyed: 11 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10823.20 47.820 119.930 8697.30 8787.78 1060.09 S 4444.73 E 5958462.18 N 616509.25 E -4444.73 Tie On Point MWD Magnetic 10846.70 48.170 119.870 8713.03 8803.51 1068.80 S 4459.87 E 5958453.71 N 616524.52 E 1.501 -4459.87 10870.10 48.120 119.820 8728.64 8819.12 1077.47 S 4474.98 E 5958445.26 N 616539.76 E 0.266 -4474.98 r---- 10893.59 47.850 119.930 8744.36 8834.84 1086.17 S 4490.12 E 5958436.79 N 616555.02 E 1.201 -4490.12 10904.00 47.810 119.980 8751.35 8841.83 1090.02 S 4496.80 E 5958433.04 N 616561.76 E 0.524 -4496.80 Window Point 10935.92 43.350 126.380 8773.70 8864.18 1102.44 S 4515.89 E 5958420.91 N 616581.03 E 19.995 -4515.89 10971.51 41.230 149.810 8800.19 8890.67 1119.93 S 4531.72 E 5958403.65 N 616597.12 E 44.517 -4531.72 10994.00 41.230 149.810 8817.11 8907.59 1132.74 S 4539.17 E 5958390.95 N 616604.77 E 0.000 -4539.17 Projected Survey DrillQuest 3.03.02.005 Page 3 of3 6 October, 2003 - 15:44 .--.. 8787.78 BP High Accuracy Gyro (W-16) 8907.59 MWD Magnetic (W-16APB1) 0.00 10823.20 8787.78 10994.00 0.00 10823.20 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) ",.- Survey tool program for W-16APB1 North Slope Alaska BPXA Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-16APB1 Your Ref: API 500292204570 Job No. AKMW0002548805, Surveyed: 11 July, 2003 ') AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Redistribution due to API changt? Re: Distribution of Survey Data for Well W-16A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 10,870.10 I MD Window / Kickoff Survey: 10,875.00 I MD (if applicable) Projected Survey: 12,904.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager .c~[) nr'·...... ,)\." ¡ '1 0 ::~GC) Attachment(s) ~~:\~\'\\~ ) f)03- ! ~ 08-0ct-03 ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well W-16A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 10,870.10 I MD Window / Kickoff Survey: 10,875.00 I MD (if applicable) Projected Survey: 12,904.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) R~~i~b ) $CJ3~- ,/00 08-Aug-03 , , I.~ Sperry-Sun Drilling Services --. North Slope Alaska BPXA PBU WOA W Pad W-16A Job No. AKMW0002548805, Surveyed: 16 July, 2003 Survey Report 6 October, 2003 "~ Your Ref: API 500292204501 Surface Coordinates: 5959455.89 N, 612049.21 E (70017' 53.4404" N, 149005' 33.2886" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959455.89 N, 112049.21 E (Grid) Surface Coordinates relative to Structure Reference: 2229.65 N, 2167.29 E (True) Kelly Bushing: 90.48ft above Mean Sea Level Elevation relative to Project V Reference: 90.48ft Elevation relative to Structure Reference: 90.48ft speral'y-sufl DRILLING SERVIc:es A Halliburton Company ~~~~ _" C ~o3-- \ŒJ D,-.,-.c ~r!~r V-: ~_I. '. '=; '_ ..-.. ~, I ~'-~:'- ::: '~:... /-':1 .;......; ;.=-- ': t-O~' ~ \f ~~..:, ~.,.J o"'! ,......... ....'.. OCT ¡ 0 ¿UU) l_.;t": (-.: ~"".- .~/ ::,. ':¿ t.. r :~::~7:tC·1 /~nGf~:)r-E~.f;~f~ Survey Ref: 5vy4081 ..., Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-16A Your Ref: API 500292204501 Job No. AKMW0002548805, Surveyed: 16 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10870.10 48.120 119.820 8728.64 8819.12 1077.478 4474.98 E 5958445.26 N 616539.76 E -4474.98 Tie On Point 10875.00 48.070 119.840 8731.91 8822.39 1079.29 8 4478.15 E 5958443.49 N 616542.95 E 1.065 -4478.15 Window Point 10899.33 49.520 128.230 8747.96 8838.44 1089.538 4493.28 E 5958433.48 N 616558.24 E 26.608 -4493.28 10928.73 50.930 138.380 8766.79 8857.27 1105.008 4509.67 E 5958418.25 N 616574.86 E 26.948 -4509.67 ,~ 10946.46 48.750 144.390 8778.23 8868.71 1115.57 8 4518.13E 5958407.81 N 616583.47 E 28.667 -4518.13 10975.79 43.610 160.920 8798.61 8889.09 1134.18 S 4527.90 E 5958389.35 N 616593.52 E 44.170 -4527.90 11001.43 39.740 180.650 8817.84 8908.32 1150.81 S 4530.71 E 5958372.76 N 616596.57 E 53.164 -4530.71 11033.73 44.580 201.620 8841.90 8932.38 1171.79 S 4526.39 E 5958351.72 N 616592.57 E 45.896 -4526.39 11066.83 51.100 215.540 8864.16 8954.64 1193.158 4514.58 E 5958330.19 N 616581.08 E 36.797 -4514.58 11094.63 57.710 227.350 8880.37 8970.85 1209.97 S 4499.60 E 5958313.15 N 616566.35 E 41.879 -4499.60 11124.63 65.110 235.450 8894.74 8985.22 1226.32 S 4479.01 E 5958296.49 N 616546.01 E 34.188 -4479.01 11159.68 74.360 249.550 8906.92 8997.40 1241.33 8 4449.91 E 5958281.05 N 616517.14 E 45.994 -4449.91 11191.29 82.030 253.430 8913.38 9003.86 1251.13 S 4420.59 E 5958270.81 N 616487.97 E 27.072 -4420.59 11221.51 90.480 250.780 8915.35 9005.83 1260.39 S 4391.93 E 5958261.12 N 616459.44 E 29.296 -4391.93 11260.83 93.830 252.550 8913.88 9004.36 1272.75 S 4354.64 E 5958248.21 N 616422.34 E 9.634 -4354.64 11290.11 96.920 255.540 8911.13 9001.61 1280.76 S 4326.62 E 5958239.78 N 616394.44 E 14.653 -4326.62 11326.24 99.030 263.120 8906.11 8996.59 1287.39 S 4291.48 E 5958232.63 N 616359.41 E 21.581 -4291.48 11357.51 99.650 266.640 8901.04 8991.52 1290.14 S 4260.76 E 5958229.42 N 616328.73 E 11.283 -4260.76 11389.29 99.380 269.110 8895.78 8986.26 1291.308 4229.44 E 5958227.79 N 616297.43 E 7.712 -4229.44 11426.86 100.530 265.760 8889.29 8979.77 1292.96 S 4192.48 E 5958225.59 N 616260.50 E 9.300 -4192.48 ~. 11460.91 102.200 264.700 8882.58 8973.06 1295.73 S 4159.21 E 5958222.32 N 616227.28 E 5.777 -4159.21 11498.83 102.470 257.300 8874.46 8964.94 1301.528 4122.65 E 5958215.98 N 616190.81 E 19.077 -4122.65 11532.86 102.560 264.000 8867.08 8957.56 1306.92 S 4089.89 E 5958210.10 N 616158.13 E 19.222 -4089.89 11567.76 101.230 268.580 8859.88 8950.36 1309.128 4055.82 E 5958207.39 N 616124.10 E 13.395 -4055.82 11609.68 98.680 274.400 8852.63 8943.11 1308.04 S 4014.57 E 5958207.85 N 616082.84 E 14.965 -4014.57 11645.74 97.800 277.210 8847.46 8937.94 1304.438 3979.07 E 5958210.93 N 616047.29 E 8.089 -3979.07 11685.11 97.090 285.850 8842.35 8932.83 1296.63 S 3940.86 E 5958218.16 N 616008.96 E 21.835 -3940.86 11718.11 97.360 288.670 8838.20 8928.68 1286.92 S 3909.60 E 5958227.41 N 615977.56 E 8.517 -3909.60 11751.33 97.800 295.190 8833.81 8924.29 1274.638 3879.07 E 5958239.24 N 615946.85 E 19.500 -3879.07 11782.31 97.090 297.660 8829.80 8920.28 1260.96 S 3851.56 E 5958252.50 N 615919.14E 8.231 -3851.56 11808.04 97.530 303.820 8826.52 8917.00 1247.92 8 3829.64 E 5958265.21 N 615897.03 E 23.808 -3829.64 11839.29 97.270 305.760 8822.50 8912.98 1230.24 8 3804.19 E 5958282.51 N 615871.32 E 6.212 -3804.19 11890.41 96.040 301.710 8816.57 8907.05 1202.05 S 3761.97 E 5958310.06 N 615828.68 E 8.229 -3761.97 11923.58 92.330 299.770 8814.15 8904.63 1185.15 S 3733.54 E 5958326.54 N 615800.01 E 12.614 -3733.54 11947.91 91.100 297.130 8813.42 8903.90 1173.56 S 3712.16 E 5958337.81 N 615778.46 E 11 .966 -3712.16 6 October, 2003 - 15:44 Page 2 of 4 DríllQuest 3.03.02.005 DrillQuest 3.03.02.005 Page 3 of4 6 October, 2003 - 15:44 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-16A Your Ref: API 500292204501 Job No. AKMW0002548805, Surveyed: 16 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11973.61 90.930 293.430 8812.97 8903.45 1162.59 8 3688.93 E 5958348.43 N 615755.06 E 14.410 -3688.93 12004.13 91.890 291.490 8812.22 8902.70 1150.93 8 3660.74 E 5958359.66 N 615726.70 E 7.090 -3660.74 12025.99 92.860 289.370 8811.31 8901.79 1143.31 8 3640.27 E 5958366.98 N 615706.12 E 10.657 -3640.27 12054.93 89.690 288.840 8810.67 8901.15 1133.84 S 3612.93 E 5958376.04 N 615678.65 E 11.106 -3612.93 .~ 12077.04 88.110 287.960 8811.09 8901.57 1126.878 3591.96 E 5958382.71 N 615657.57 E 8.179 -3591.96 12105.11 85.900 285.500 8812.56 8903.04 1118.80 S 3565.12 E 5958390.37 N 615630.61 E 11.772 -3565.12 12136.13 87.310 285.500 8814.39 8904.87 1110.528 3535.28 E 5958398.20 N 615600.65 E 4.545 -3535.28 12173.01 88.810 281.090 8815.64 8906.12 1102.05 8 3499.42 E 5958406.14 N 615564.67 E 12.624 -3499.42 12203.79 88.810 277.740 8816.28 8906.76 1097.01 8 3469.06 E 5958410.72 N 615534.24 E 10.881 -3469.06 12233.66 90.310 273.340 8816.51 8906.99 1094.13 S 3439.34 E 5958413.16 N 615504.48 E 15.562 -3439.34 12262.68 92.070 270.340 8815.91 8906.39 1093.20 8 3410.35 E 5958413.66 N 615475.48 E 11.983 -3410.35 12293.93 91.890 268.580 8814.83 8905.31 1093.49 S 3379.12 E 5958412.90 N 615444.26 E 5.658 -3379.12 12325.41 89.780 266.4 70 8814.37 8904.85 1094.85 S 3347.68 E 5958411.07 N 615412.84 E 9.478 -3347.68 12355.56 84.850 261.530 8815.78 8906.26 1098.00 8 3317.74 E 5958407.48 N 615382.95 E 23.132 -3317.74 12383.01 82.730 259.070 8818.75 8909.23 1102.59 S 3290.85 E 5958402.48 N 615356.13 E 11 .790 -3290.85 12424.01 84.140 266.4 70 8823.45 8913.93 1107.718 3250.47 E 5958396.76 N 615315.83 E 18.257 -3250.47 12461.68 84.580 270.170 8827.15 8917.63 1108.81 8 3213.00 E 5958395.11 N 615278.39 E 9.844 -3213.00 12495.96 84.850 275.280 8830.31 8920.79 1107.19 S 3178.92 E 5958396.22 N 615244.28 E 14.864 -3178.92 12528.61 84.760 280.560 8833.27 8923.75 1102.71 8 3146.73 E 5958400.22 N 615212.03 E 16.107 -3146.73 12570.79 85.200 284.970 8836.96 8927.44 1093.43 8 3105.76 E 5958408.89 N 615170.92 E 10.467 -3105.76 .~ 12601.36 84.760 288.140 8839.64 8930.12 1084.75 S 3076.57 E 5958417.13 N 615141.61 E 10.430 -3076.57 12631.81 83.700 283.910 8842.70 8933.18 1076.39 8 3047.46 E 5958425.06 N 615112.38E 14.253 -3047.46 12660.26 83.790 280.560 8845.80 8936.28 1070.40 8 3019.82 E 5958430.64 N 615084.66 E 11.709 -3019.82 12690.56 82.380 274.570 8849.45 8939.93 1066.44 S 2990.02 E 5958434.15 N 615054.80 E 20.169 -2990.02 12714.21 81.850 273.160 8852.70 8943.18 1064.86 8 2966.65 E 5958435.38 N 615031.41 E 6.316 -2966.65 12760.16 85.460 269.460 8857.77 8948.25 1063.82 8 2921.01 E 5958435.74 N 614985.76 E 11.214 -2921.01 12791.61 89.960 266.820 8859.03 8949.51 1064.84 8 2889.61 E 5958434.25 N 614954.38 E 16.585 -2889.61 12823.56 93.830 267.350 8857.98 8948.46 1066.46 8 2857.73 E 5958432.15 N 614922.52 E 12.226 -2857.73 12853.33 93.830 270.700 8855.99 8946.47 1066.97 8 2828.03 E 5958431.21 N 614892.83 E 11 .228 -2828.03 12869.08 91.980 274.920 8855.19 8945.67 1066.20 8 2812.32 E 5958431.74 N 614877.12 E 29.223 -2812.32 12904.00 91.980 274.920 8853.98 8944.46 1063.20 8 2777.55 E 5958434.22 N 614842.31 E 0.000 -2777.55 Projected 8urvey Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-16A Your Ref: API 500292204501 Job No. AKMW0002548805, Surveyed: 16 July, 2003 BPXA North Slope Alaska 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 270.000° (True). .---. Magnetic Declination at Surface is 25.584°(09-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12904.00ft., The Bottom Hole Displacement is 2974.09ft., in the Direction of 110.946° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10870.10 10875.00 12904.00 8819.12 8822.39 8944.46 1077.47 S 1079.29 S 1063.20 S 4474.98 E 4478.15 E 2777.55 E Tie On Point Window Point Projected Survey Survey tool program for W-16A ~. From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10823.20 0.00 8787.78 10823.20 12904.00 8787.78 BP High Accuracy Gyro (W-16) 8944.46 MWD Magnetic (W-16APB1) 6 October, 2003 - 15:44 Page 4 of 4 DrillQuest 3.03.02.005 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ï¡JGft. 11u l~oo3 .fR 7(U/0 1. Type of Request: 0 Abandon o Alter Casing II Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. o Suspend 0 Plugging 0 Time Extension 0 Perforate o Repair Well 0 Pull Tubing 0 Variance II Other / o Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Well Name Change 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 181 Development D Exploratory D Stratigraphic D Service 6. Datum Elevation (OF or KB) RKB = 90.48 7. Unit or Property Name Prudhoe Bay Unit x = 615010, Y = 5958416 8. Well Number W-16A 9. Permit Num~- 203-100 10. API Number 50- 029-22045-01 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool /' 4. Location of well at surface 801' SNL, 1183' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval 1931' SNL, 3378' EWL, SEC. 22, T11 N, R12E, UM (As Planned) At effective depth NIA At total depth 1886' SNL, 1759' EWL, SEC. 22, T11 N, R12E, UM (As Planned) 12. Present well condition summary Total depth: measured x = 612049, Y = 5959456 x = 616629, Y = 5958395 / true vertical Effective depth: measured true vertical 11558 feet 9274 feet 11 068 feet 8952 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 110' 20" 2674' 13-3/8" 3840 cu ft Coldset III & II 10807' 9-5/8" 2378 cu ft Class 'G' 1013' 7" 294 cu ft Class 'G' 110' 2674' 10807' 110' 2674' 8777' 10545' - 10880' 8605' - 8826' Perforation depth: measured 11018'-11024', 11030'-11058', 11072'-11102', 11126'-11190', 11212'-11222' r:;"'~ ~ .;: true vertical 8919' - 8923', 8927' - 8945', 8955' - 8975', 8991' - 9033', 9048' - 90$'4:'. I Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing to 11116' .JUt. 1 g 7003 .fi ~: ,I " "I , - Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker 0 WISBE Packer at 10474',!'4~1/2"- SSSV La~diág nipple at2t22' 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing opera~ July 18, 2003 16. If proposal was verbally approved ./ Winton Aubert /' 7/18/2003 Name of approver Date Approved Contact Engineer NameINumber: Alistair Sherwood, 564-4378 17. I hereby certify that the}cy;egOin. ~'s tr~e~n,~ carre -to the best of my knowledge Signed M E d Ytt 1A/!f~ v¡ :/·1, " Title CT Drilling Engineer ary n acott ¡; f . ~ ,"":':;',: ,": ,.' ".' " " '"" ,: '~:"',',' ,.',:">\)":.'::I::~::I,~":¡::':"':,':::,::,,,I::<:,. "',':.< '~I~":~~~í';', ,,'/,.""'L:~,'L ':I'i":'~I:'.~'~'~"·~'I'" ':", .~'!,:' '"I;""",:", ......' , '. .") '/'. ··!!,:,:,:O"~':/!'!!!'.I:;""""Q~"'''~II..~~,!,.....:!g~1 Yi,'I"I' " Conditions of Approval: Notify Commission 50 representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ ~4bsequent lorm required 1 Q-. ~ 0 "7 A (( P"ro IF 'l,o ~ j ð 0 So B- p ~Ltc· t'i't c;,,' ot.f P I~ ' Approved by order of the Commission {l/4 _ ~ ~ ~ Form 10-403 Rev..._06../,~5/8~,.... n.\ì n~.. ''.D (, )-il', 'I 0 R , G 1 N A l 'R~q~U.~~~~\~" J\llVIL ,", ..~ ~.. J _ D Detailed Operations Program D BOP Sketch 15. Status of well classifications as: 181 Oil 0 Gas D Suspended Service Prepared By NameINumber: Sondra Stewman, 564-4750 Date 7jN Jò 3 I Approval No. 3D..,.. m-- ~o"'- ~/t.-þ-~ j!. Commissioner Date //2I¡Ö3 Submit In Triplicate ) ) BP W-16A CTD Sidetrack CTD Operational Ammendment: Nordic 1 CTD rig is currently rigged up on W-16 and is drilling a 3%" OH sidetrack. The origin~tent with W-16L 1 was to preserve the parent well production and commingle it with that of the sidetrack. As part of the CTO well prep, an IBP with check from above was installed in the 7" liner. This was to prevent mud loss during the drilling operations & with an uncemented 20" liner would allow parent production, post drilling. However there is a need to change the liner completion from 20" solid & pre-drilled, to solid, cemented & selectively perforated because of what's been seen drilling the sidetrack. Driving this change is two things; #1, a fault was crossed in the build section and the associated fractures present a prefer~al gas & water / production conduit. #2 the Resistivity log indicates water fingering in the target formation. In this situation, production is best managed by selectively perforating the low Sw intervals. The resulting cement job ,will effectively P&A the parent well. The name of the resulting well will change from W-16L 1 to W-16A../" The following are revisions to the Permit to Drill documentation, Form 10,401. Permit # 203-100. Casing Program Revision: The production completion will be solid 3 3/16" TC II x 2 7/8" ST -L liner from TD @ 13,000' to approx. 10,525' MO (8500'ss) in the 4% tbg tailpipe. The X-O between 3 3/16" x 2 7/8" will~e rox. 11,030' MD (8840'ss), in the 46P sands below TSAO. The liner will be cemented inplace w· 2~ Class G. The TOe is planned to be at 10,550' which is just below the 7" liner hanger /' ~,- Logging Program Revision / . A memory CNL/GR/CCL log will be run in the cased hole to identify the GOC. ./ 1$" TREE =~ WaLHEAD = '.,,".,'" ,,,..,,."'''''''''''" ACTUA TOR = ..~. . ,,,,' .. .,' '. ,,' "."" ..,'.., ,.'" ~ KB. aEV = .. ...""........,,,..,,... BF. aEV = KOP= Max AnQle= . Datum MD = Datum TV 0 = 4" CrN MCEVOY OTIS "--. ,.,.,','.,............,"..--.",'",',.. 90.48' 53.08' 4311' 54 @ 9316' 10976' 8800' SS I 13-3/8" CSG, 68#, L-80, 10 = 12.415" 1--1 2674' ~ Minimum ID = 3.725" @ 10548' 4-1/2" PARKER SWN NIPPLE W-16 SA' !NOTES: CAUTION: 13CR TBG, DO NOT ACh.m:::.E <I> 2122' 1-141/2" SSSV LAND NIP I ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 6 2974 2883 1 OTIS RA 5 5385 5191 38 OTIS RA 4 7521 6634 48 OTIS RA 3 8884 7502 53 OTIS RA 2 9740 8009 51 OTIS RA 1 10432 8444 52 OTIS RA L I 10461' 1-14-1/2" PARKER SWS NIP, 10 = 3.813" I ~ ~ 10474' I- 9-5/8" X 4-1/2" BAKER DW/SBE & MOX PKR, 10 = 4.750" 10504' 1-14-1/2" PARKER SWS NIP, 10 = 3.813" 10548' 1"'4-1/2" PARKER SWN NIP, milled 10 = 3.80" I t j 4-1/2" TBG, 12.6#, L-80, TDS, -1 10570' N-IPC, .0152 bpf, 10 = 3.958" 1 TOP OF 7" LNR 1-1 10545' I I I 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 10805' ~ .. PERFORATION SUMMARY REF LOG: BHCS ON OS/24/90 ANGLE AT TOP PERF: 48 @ 11018' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11018 - 11024 0 05/13/94 5" 4 11030 -11050 0 07/18/90 3-3/8" 6 11034 - 11058 0 05/13/94 5" 4 11072-11102 0 07/18/90 5" 4 11126 - 11190 0 07/18/90 3-3/8" 4 11212 - 11222 0 09/21/91 1 PBTD 1-1 11454' 7" LNR, 26#, U4S, 0.0383 bpf, 10 = 6.276" 1-1 11558' DATE 07/21/90 02/22/91 02/09/01 03/05/01 09/05/01 07/17/03 REV BY COIVtÆNTS JQ ORIGINAL COf\.R.ETION R#O SIS-QAA CONVERTED TO CANVAS SIS-LG FINAL RN1TP CORRECTIONS MSE em sited rack update DATE I 10570' 1-14-1/2" TBG TAIL, 10 = 3.875" 1 10560' 1-1 aMD TT LOGGED 09/23/95 I III.. .Ia.. fa ~..... 110880-10886 1-1 Window I r 10875' 1-1 Baker Gen II whipstock - eline set I /' I 10887' 1-1 Baker Gen II whipstock - released I 1109oa-109331-iWindow + 10' to 18' formation drilled I 10995' 1-1 Baker Gen II whipstock - fell I 11000' 1-1 Standing Valve element I I 1m.. REV BY COMMENTS PRUDHOE BAY UNIT WaL: W-16 ÆRMIT No: 1900560 API No: 50-029-21961-00 SEC21, T11N, R12E. 801' FNL & 1183' Fa. BP Exploration (Alaska) -~\_. TREE = 4" CWV W8..LHEAD = MCEVOY ÃCTuÄ Ï"OFf";··..·....·-·....·..·..-·oTiS KB. 8..EV = ·90.48' . BF:-Ëi..E\Ï-:;;··-··--··..·-·..S3:Õ"ã' î<öp^="W 4311' Max Angìe;--'-'''''54-@-9316Î Datûm MD ~ . ...." .. 10976; Datum 1VD = 8800' SS ) W-16 A SA )~ NOTES: CAUTION: 13CR TBG, DO NOT ACIDllE Proposed CTD Sidetrack I 13-3/8" CSG, 68#, L-80, ID = 12.415" l-i 267 4' ~ Minimum ID = 3.725" @ 10548' 4-1/2" PARKER SWN NIPPLE 4-1/2" TBG, 12.6#, 13-CR, IDS, -1 10570' N-IPC, .0152 bpf, ID = 3.958" 1 TOP OF 7" LNR 1-1 10545' - 2122' r-14 1/2" SSSV LAND NIP 1 ~ GAS LIFT MANDRB.S ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 6 2974 2883 1 OTIS RA 5 5385 5191 38 OTIS RA 4 7521 6634 48 OTIS RA 3 8884 7502 53 OTIS RA 2 9740 8009 51 OTIS RA 1 10432 8444 52 OTIS RA L I 10461' r-14-1/2" PARKER SWS NIP, ID = 3.813" I g :8 10474' r- 9-5/8" X 4-1/2" BAKER DW/SBE & MaX PKR. ID = 4.750" I I 8 10504' - 4-1/2" PARKER SWS NIP, ID = 3.813" 10525' - Top of 3-3/16" Liner 1 10535' 3-1/2" X NIP, ID = 2.813" I ~ 10548' - 4-1/2" PARKER SWN NIP, ID = 3.725" 10570' - 4-1/2" TBG TAIL,ID = 3.875"1 10560' 1-1 B.MD TT LOGGED 09/23/95 1 I~ , ~ PERFORATION SUMMARY REF LOG: BHCS ON OS/24/90 ANGLE AT TOP PERF: 48 @ 11018' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11018 - 11024 0 05/13/94 5" 4 11030 -11050 0 07/18/90 3-3/8" 6 11034 - 11058 0 05/13/94 5" 4 11072 - 11102 0 07/18/90 5" 4 11126 -11190 0 07/18/90 3-3/8" 4 11212 - 11222 0 09/21/91 1 PBID 1-1 11454' 7" LNR, 26#, U4S, 0.0383 bpf, D = 6.276" H 11558' DATE 07/21/90 02122191 02109/01 03105101 09/05/01 07/17/03 REV BY COMMENTS JQ ORIGINAL COMPLETION ~O SIS-QAA COt-NERTED TO C'At-N AS SIS-LG FINAL RNITP CORRECTIONS MSE Proposed cOrT"4>letion DATE ~ 1 10550' ~ 1 11050' ..".. ,.: ,..~,"..,..,., .. \" .. ,. .... i 1j..,.}<rfl.~:':~Ä;J ..' > ,' . . . 1-13-3/16 x 2-7/8 X-over I , /' 1 3-3/16" X 2-7/8" cemented & perf'd 1-1 12750' I..~ I 10887 HSakerGen IIwhipstock- released I "[ 11.......° 1 1090S·10933 1-1 Window + 10' to 18' formation drilled 1 ( 1 10995' H Baker Gen II whipstock.. fell 1 ..-J ~ 11000' HStanding Valve element ... REV BY PRUDHOE BAY UNIT W8..L: W-16 PERMIT No: 1900560 API No: 50-029-21961-00 SEC21, T11N, R12E. 801' FNL & 1183' Fa. COtvNENTS BP Exploration (Alas ka) , .r 1,-1, I Lt~ rñj \ \~ r~) ......._......1 FRANK H. MURKOW5KI, GOVERNOR A'IfASKA. OIL Alft) GAS CONSERVATION COMMISSION 333 W. ']TH AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit W-16L1 BP Exploration (Alaska), Inc. Permit No: 203-100 Surface Location: 801' SNL, 1183' WEL, Sec. 21, T11N, R12E, UM Bottomhole Location: 1886' SNL, 1759' EWL, Sec. 22, T11N, R12E, UM Dear Mr. Sherwood, Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ ~andy R'uedrich Commissioner BY ORDER OF THE COMMISSION DATED this~ day of June, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section iN4Æ- lRl sf z..,()tP~ ALASKJ." STATE OF ALASKA )L AND GAS CONSERVATION COML ~SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 90.48 Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028263 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /I~PV W-16JAI-f - 9. Approximate xrcr gàte 710jJ)S Amount $200,000.00 14. Number '·es in property 15. Proposed depth (MD and TVD) 2560 /12750' MD I 8939' TVDss o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Maximum surface 2344 psig, At total depth (TVD) 88001 I 3400 psig Setting Depth Top Bottom Quantity of Cement LenQth MD TVn MD TVD (include staç¡e data) 2225' 105251 8500' 127501 89391 Uncemented Slotted Liner /' Multilateral 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 612049, Y = 5959456 801' SNL, 11831 WEL, SEC. 21, T11 N, R12E, UM At top of productive interval x = 616629, Y = 5958395 19311 SNL, 3378' EWL, SEC. 22, T11 N, R12E, UM At total depth x = 615010, Y = 5958416 1886' SNL, 1759' EWL, SEC. 22, T11 N, R12E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well , ADL 047452,3394' MD No Close Approach /' ~6. To be completed for deviated wells Kick Off Depth 10904' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Hole CasinQ Weiaht Grade CouDlina 3-3/4" 3-3/16" x 2-7/8" 6.2#/6.16# L-80 ST-L 101 Casing 11558 feet 9274 feet 11 068 feet 8952 feet Length Plugs (measured) RCccrVED JUN 0 4 2003 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Junk (measured) TD Tagged at 11 068' ~~~;b& Gas Con~,. Commission Am:horage Cemented MD TVD Size Structural Conductor Su rface Intermediate Production Liner 1101 20" 1101 110' 26741 13-3/8" 3840 cu ft Coldset III & II 26741 2674' 10807' 9-5/8" 2378 cu ft Class 'GI 1 0807' 8777' 1013' 7" 294 cu ft Class IG' 10545' - 11558' 8605' - 9274' Perforation depth: measured 11018' - 11024', 110301 - 11058" 11072' - 11102', 11126' - 111901, 11212' - 112221 true vertical 8919' - 89231, 8927' - 89451, 8955' - 89751, 89911 - 9033', 9048' - 9054' 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number. Alistair Sherwood, 564-4378 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fO~, " C1, ·n"" ,g, "is t~,. e, 'a" nd corr,ect t, .,>, . th"e, b" e" , S,t 'a, f my", "k,"n,, .,0, WI"e, d, g""e"", . Signed Alistair Sherwood r ~ú \\k ~.CVt.-. ",~-p ell ',Title. CT Drilling Engineer " ,', "':"'.,CO,l11miSSIQl\USe,()l1ly Permit Number API Number.ßÞLJ Approval Date See cover letter ZrJ.? - /00 50- 029-22045-.6ÔO~ for other requirements Conditions of Approval: Samples Required 0 Yes f2(No Mud Log Required 0 Yes B'No Hydrogen Sulfide Measures ¡:;ryes 0 No Directional Survey Required o;rYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Te.st- E :.leE to ~çoc ~,~r, by order of Approved By ~~ ~þ~ ~Oc('it}rr)s~n!3r.N A -he commission Form 10-401 Rev. 12-01-85 ) ",' r\ : LJ _ Date 6)4- ·C~ Date ¿ /h[O-Z Su6mit·ln Triplicate ) ) BP W-16L 1 CTD Sidetrack Summary of Operations: /"'" A CTO through tubing sidetrack is pl~ed for W-16. The coil sidetrack, W-16L 1, will exit the 7" liner in the Sh ublik formation and target Zone 4. W-16L 1 will retain production from the parent well, W-16, by completing the new sidetrack with an un-cemented, pre-drilled liner. A retrievable inflatable standing valve will be installed between the whipstock and the existing perfs to isolate and protect the existing perfs while drilling the sidetrack. No fault crossings are anticipated while drilling the proposed sidetrack, however there are a number of parallel faults in the nearby facinity. Lost circulation is not expected but possible. Real time GR/Resistivity logging will be used for Sw information. Phase 1: Prep work. Planned to start '·{]3 (Form 10-403 is not required for this work) 1. Perform an MIT-IA and ~'~fter all GLV's are dummied off. 2. Use e-line to set an inflatable standing valve at 11,000' MO (8808'ss). 3. Use e-line to set a retrievable whipstock at 10904' MD (8751 'ss). /' Phase 2: Mill window, Drill and Complete sidetrack: Planned for Jul1 0, 03. Drilling coil will be used to mill the window in the 7" liner then drill and complete the directional hole as per attached plan. Maximum hole angle will be 100°. Mud Program: · Phase 1 &2: Seawater and 8.6 ppg Flo-Pro · Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) /' Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: /i The production liner will be an un-cemented 3 3/16" TC II solid x 2 7/8" ST -L pre-drilled liner from TO to approx. 10,525' MD (8500'ss). The X-O between 33/16" x 27/8" will be at approx. 11,250' MD (8850'ss). Well Control: · BOP diagram is attached. /' · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 100°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWO/GR/Resistivity will be run in open hole. Hazards /' · Maximum recorded H2S on W Pad is 10 ppm - W36 on the 10/9/01 . · Faulting in the target polygon is unlikely and the risk of a lost circulation event is low. There is a slight chance of losses to the Shublik. This could prevent cement from the liner job reaching the top of the liner. This in turn could cone gas in from the Shublik with the well on production. If losses are encountered here then a fully cemented liner may be required. Reservoir Pressure Rs is estimated to be 3400 psi at 8800'ss (7.4 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2344 psi. / TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= 4"CIW MCEVOY OTIS 90.48' 53.08' 4311' .. ?~(Q2 ~31..?' 1 0976' 8800' SS ) W-16/ SAFF'""'tJ0TES: CAUTION: 13CR. TBG, DO NOT ACID, J I 13-3/8" CSG, 68#, L-80, ID = 12.415" l-i 2674' ~ Minimum ID = 3.725" @ 10548' 4-1/2" PARKER SWN NIPPLE :8: 4-1/2" TBG, 12.6#, L-80, TDS, -i 10570' N-IPC, .0152 bpf, ID = 3.958" I TOP OF 7" LNR l-i 10545' 1 "I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 10805' ~ ÆRFORA TION SUMrvtARY REF LOG: BHCS ON OS/24/90 ANGLEATTOPÆRF: 48 @ 11018' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11018 - 11024 0 05/13/94 5" 4 11030 - 11050 0 07/18/90 3-3/8" 6 11034 - 11058 0 05/13/94 5" 4 11072 - 11102 0 07/18/90 5" 4 11126-11190 0 07/18/90 3-3/8" 4 11212 - 11222 0 09/21/91 I PBTD l-i 11454' 41) 2122' 1-141/2" SSSV LAND NIP 1 ~ GAS LIFT rvtANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DATE 6 2974 2883 1 OTIS RA 5 5385 5191 38 OTIS RA 4 7521 6634 48 OTIS RA 3 8884 7502 53 OTIS RA 2 9740 8009 51 OTIS RA 1 1 0432 8444 52 OTIS RA L I I 10461' 1-14-1/2" PARKER SWS NIP, 10 = 3.813" :8 10474' I- 9-5/8" X 4-1/2" BAKER 0 W/SBE & MOX PKR, ID = 4.750" ~ 10504' 1-14-1/2" PARKER SWS NIP, 10 = 3.813" 10548' 1-i4-1/2" PARKER SWN NIP, 10 = 3.725" 10570' 1-i4-1/2" TBG TAIL, 10 = 3.875" I 10560' l-i ELMO TT LOGGED 09/23/95 I . .. t I I I I I ~ 7" LNR, 26#, IJ4S, 0.0383 bpf, 10 = 6.276" l-i 11558' DATE 07/21/90 02/22/91 02/09/01 03/05/01 09/05/01 REV BY COMMENTS JQ ORIGINAL COMPLETION RWO SIS-QAA CONVERTED TO CANVAS SIS-LG FINAL RN/TP CORRECTIONS REV BY DATE COMMENTS PRUDHOE BAY UNIT WELL: W-16 PERMIT No: 1900560 API No: 50-029-21961-00 SEC21, T11N, R12E, 801' FNL & 1183' FEL BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = 'KB.ËLEV; BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4" CrN MCEVOY OTIS 90.48' 53.08' 4311' 54 @ 9316' 10976' 8800' SS ) I 13-3/8" CSG, 68#, L-80, ID = 12.415" l-i 2674' ~ Minimum ID = 3.725" @ 10548' 4-1/2" PARKER SWN NIPPLE 4-1/2" TBG, 12.6#, 13-CR, TDS, -i 10570' N-IPC, .0152 bpf, 10 = 3.958" I TOP OF 7" LNR l-i 10545' W-16 L 1 SAFF"""'foTES: CAUTION: 13CR. TBG, DO NOT ACI[j. , Proposed CTD Sidetrack 2122' ~14 1/2" SSSV LAND NIP 1 I1IIIIII11111 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2974 2883 1 OTIS RA 5 5385 5191 38 OTIS RA 4 7521 6634 48 OTIS RA 3 8884 7502 53 OTIS RA 2 9740 8009 51 OTIS RA 1 1 0432 8444 52 OTIS RA L I I 1 0461' ~14-1/2" PARKER SWS NIP, ID = 3.813" ;g: Z 10474' ~ 9-5/8" X 4-1/2" BAKER D W/SBE & MOX PKR, ID = 4.750" I I /' 10504' - 4-1/2" PARKER SWS NIP, 10 = 3.813" 8 10525' - Top of 3-3/16" Liner 1 10535' ___3-1/2" X NIP, ID=2.813" I , \ 1 0548' - 4-1/2" PARKER SWN NIP, ID = 3.725" 10570' - 4-1/2" TBG TAIL, ID = 3.875" I 10560' l-i ELMO TT LOGGED 09/23/95 I IIII1I111 I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 10805' ~ I \ \ ~ 11250' 1-13-3/16 x 2-7/8 X-over I Mechanical Whipstock 1-1 10904' 1- _ ~ ~ ÓO,IIO II 0 " I 3-3/16" blank X 2-7/8" pre-drilled l-i 12750' PERFORA TION SUMMARY REF LOG: BHCS ON OS/24/90 ANGLE AT TOP PERF: 48 @ 11018' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11018 - 11024 0 05/13/94 5" 4 11030-11050 0 07/18/90 3-3/8" 6 11034 - 11058 0 05/13/94 5" 4 11072 - 11102 0 07/18/90 5" 4 11126-11190 0 07/18/90 3-3/8" 4 11212-11222 0 09/21/91 I PBTD l-i 11454' 7" LNR, 26#, LJ4S, 0.0383 bpf, ID = 6.276" l-i 11558' DATE 07/21/90 02/22/91 02/09/01 03/05/01 09/05/01 REV BY COMMENTS JQ ORIGINAL COMPLETION RWO SIS-QAA CONVERTED TO CANVAS SIS-LG FINAL RNfTP CORRECTIONS DATE -¡ '-0 18 ~---1 11000' l-i Standing Valve 1/ I ~ REV BY PRUDHOE BAY UNIT WB..L: W-16 ÆRMIT No: 1900560 API No: 50-029-21961-00 SEC21, T11N, R12E, 801' FNL & 1183' FB.. COMMENTS BP Exploration (Alaska) ------------------ ,.,.,,1 Wotlpolh: T&. Oft MD: ---~ Rig: II.,. Dotu"': y "ectlon Angle BP Amoco WUtPATH DETAILS Plan" W·11L1 5002922OUao W·I. 10813.58 ,. I 1I1IiII,no 00:00 1O.4Ift °t.J ~ ~~~ :=~D 0.00 0.00 REFERENCE INFORMATION ~~e~~I~~~: ~e I~:~~~ ~~North Section (VS) Reference: src;: - 16 (O.OON ,O.OOE) Measured Depth Reference: 19: 16 51911990 ()():()() 90.48 CalcUation Me1hod: MinimLfTI CUlVature 1 10183.eo 47." 11'.13 :z 10t04.DO C7 ..1 1t1.H :3 10124.00 ".12 120.'3 4 10M4.oo )S.24 143.08 5 11031.00 47.23 1t2.27 e 11UO.43100.00 273.11 1 1U1I.43100A2 ,".n . 115a-1.43 100.08 260.41 . 1nee."3100.01 218.10 10 un....43 ....1 214.14 11 12034.43 10.11 2I2.U 12 12U·4_43 10.1-3 217.'3 12 124".43 lO.sa 210." 1412750.00 to.f' ZlI.17 RNNOTATIONS TVD ND &7.w.J' 101.3... SUI.3. ,_ S7as.oo 10.24.00 '7I5M 1-..&.00 SI53.22 11031.00 "17.71 1123.AJ "03.12 1 UtlAJ ....... 1 UIIAJ 1Iu.a1 1 nllAJ SIOI... 1,.34.43 SI17.44 12034.43 l1SO..7 12234.43 ....... 12AMAJ _ _ 03..211 12760.00 8300 8350 8400 _8450 C ~ 8500 1!!.8550 .c t. 8600 G» ca 8650 '5 8700 i 8750 > G» 8800 2 I- 8850 8900 8950 W-16 (W.16¡ 9000 9050 arCTION DI!T"U .E..... D.... The. T.....t :~:t~ "15.00 ~[fi 112".01 ~:: :::t:: ":31.21 4488." 0.00 0.00 44H." Æ.5 137.20 "501.21 14.0.00 4U'.7. .00 US.GO ..ne.n ;c.s.OO 10_00 ueo." 4.5.00 78.50 4311.&0 45.00 ".00 4107.21 12.00 272.00 H11.... 12.00 272.00 3129.14 12.00 118.00 3IAO.n 12.00 141.00 3441.02 12.00 2fIa.oo 31.7.... 12.00 .3.00 2'M4.02 12.00 217.00 --4-411." ........... ~.2. 0.4528.7' ""3&.12 -431G.H -4318.80 ....,07.21 ·:wH.... iª ---------- ---- MM. BAKEIt ' ....... iINTE(l LEGENC K221112 {K221112}¡ - '1'1-lô(W-1ô} , Plan#6 W-16L 1 Plan #6 T ^M -1OM.14 ·1oa.... ·1087.3. ·1'I14.U ·1"0.17 ·1244.38 ·12t1.13 ·11 n.OI ·1122..14 ij~~ ',; J" i-----.. ; ---- ------ Azimuths to True North ¡ Plan: Plan #6 (W-16IPIan#6 W-16L 1) Magnetic North: 25.62" ¡~at~ .~y~ Bnj P~~u _~~t~:~~~~oo~__ Magnetic Field i Contact Inforrnation Strength: 57522nT ¡ Dip Angle: 80.77" i Direct (907) 267-6613 Date: 5/19/2003 ¡ E-fT1.aiL bnjpotnls@inteq com Model: BGGM2002 I Baker Hughes INTEO r90ïì 267-6600 ~--~---~- ~-~~-~-~-~~=-~-~--~~ A'''lotatlon TIP KO. S 4 I . 7 I . 10 11 12 13 TD T'w-O 4""-5 +E1..w S'tiIpe 0·.-.·. b- ·L--P e- ~jj~¡~' o IX! -959)9 2'901 11 Pdygon 000 -12'iCOð "m~ ~ 000 ·n~"u 2e~61 ~ ~~ :Jillg ~lî ~ , . --~-------~--~----- ~:::-ç_ -~~~~--~~~~ _- -~ __~ ~____= _=~=----~~_ _.__~~~~~____-- .__~__u~-u~-~~~=--------- -600--::- - --..-----_ ---- -.- --- --------- ----~--~- ----~~-~--- 3J'=.~ ....-J<..QP" I T 4. I I '\ 5 6 W-f6L1!61 -- -------- --------- - --~-- ----~--- ------ ------- -700 --=--==::.. ~---===-_ ---:::=-...:::-:-::..=::.==-~::.-=--====-==--=====---=-.::.::____ ~___-==:~~==--===~=-=====--:---:.==-:::==-===~: -800~- ----- -W-16UPol onôf ~-~-~- -~~ -~--=------------- ------~ 1_::~~'CC:c-"c::c-~ .~ ,~.1d~,- _ .."-' - . ___=cc--=~ W:"",",'m =-"~=:;~~<~-cc ~~~;; _'~ ~--__ 0-1100-=-. _________.,f-~~__. 13 _---...13...~~...:'.~~-10-----cI---.--JJ::..--. '" ~_T W-1611Fault2 l:. =.::.::::.~._~====-_~ W-16L1 T6.3.==_-·~--=-=======_ +-1200 ~:~~=-:-.:~=====~--======._~.-_. - .c - 1:: -1300-_-~~--_·-· o - ! -1400 ....~~...:_ _=~~ ·-W-16:'1. FaUît3 _-=~.u =--=_ - ::.=-~~: - . - .c -1500-::-:------------· ... :I _ o -1600·-------·---~- en ~~::...::.==-=-~-=-====-. -------- -~ ~ ·~W-16L1T6.1 --K221112(K22"111.- ~. .. n_~---:. -~ - -- - ---~j~----~ ----------------:------ -.--~---.. W-16l1 Fault 1 -~---------'--- --- '" --~--W=16 <W-16} -- --- - ------------- -----~ ------ -1700-_- ---------------~----- ------~------~ -1800-=-- -~-~--- -------- ---- ----~~--~--- --------------- ----------~-----"----~- ------_.---------~----- ------- ------------------- - -- --~------.- -1900· ------ ----- ~-------------- -2000-------::--.---:-- n --------~ ----~--- ----~-- ------_._--,------~ -~------------------ ---~---- -2100--=-=-~--=-....::.:-.....-=-~-===- ~-------- -------- ----------------- -'-~- --------- ------- ------~-- 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 West(-)/East(+) [100ft/in] -. --------~------- ------ ------- ---- - - -------- ---------------------- -----------~-,-------------~----- ---------------------- -- ------ ----.--- ------ ----------------- --~---- --------------- -- -----------~------ --~---~--- ---------.-- ~- -------- -----------_.~----- ·1i~·- -----~----------- .-----=--=-=-__==__:_ cI.:-:-..:: __. ~ -------- ------- -------------~ --~----------- ----- ~----------- I , PIan#6 W-1611 ·------::·=-m-...:.:::=.:::::=-=::-:= ·12 -----------~-~-----~- --~------ --~------------ - ----"- -- -----~ - ------- -------- - ------ -----._-"----------~-------- --- _ __~L___ _. ----- -----------------, ~W-16h.1 T6.3 --------- ---- ------------- -------- ---------------- ~-- - ------ ---------- g2]112 L~IJ..11l ---------- ---- ---------------------- ------------ ----~--- ---------- -"---------------------~ --- -----"---- ---- ---,-------- - ------ --------- ----- ----- - ----- --------~- ---------- ---~~ ------- -------- -- -- -------- ------- -- -- ------ - --- ----- ----- -.- - - - ----- -4700 -4650 -4600 -4550 -4500 -4450 -4400 -4350 -4300 -4250 -4200 -4150 -4100 -4050 -4000 -3950 -3900 -3850 -3800 -3750 -3700 -3650 -3600 -3550 -3500 -3450 -3400 -3350 -3300 -3250 -3200 -3150 -31 00 -3050 -3000 -2950 -2900 -2850 -2800 Vertical Section at 270.000 [50ft/in] - .5t'1-9t2Oro-~ PM -- --- -- ------------- -------- ------------- -------------------- i, bp ) BP ) Baker Hughes INTEQ Planning Report II.N'·'("EQ ..,.._. '""'........".. ."'...._".. ...~ ,.,',.._...._.~ ..._" ..,.. ..' __ "'_"'" .. .".."..",_~...".., ,~." '~""': "~_'._. _. '_M,.'''_' H~_""'.U'~~_ _~'_....___..~'_.,~.._.~'"..._...~.. ...' ....~..... .~._....,,_....,,_._~,.~. ....,"~ ,.........,....__._."~.,.,,,.,,....... Company: BP Amoco Field: Prudhoe Bay Site: PB W Pad Well: W-16 Wellpath: Plan#6 W.;16L 1 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 Date: ..' 5/19/2003 Tim~: 14:12:32 Page: Co-ordinate(NE)Reference: Well:W-16, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.OON,0.00E,270.00Azi) . ..... ,,_ ", ~~~eYE~I~~la!~~!':.~~t~~_d:. .... Minimu.m. ~u.~~ture Db: Oracle N" ,._,"". Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB W Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 47.83 ft 5957194.18 ft 609919.18 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 31.506 N 149 6 36.343 W True 0.84 deg Well: W-16 Slot Name: 16 W-16 Well Position: +N/-S 2230.48 ft Northing: 5959455.85 ft Latitude: 70 17 53.440 N +E/-W 2163.01 ft Easting : 612049.16 ft Longitude: 149 5 33.290 W Position Uncertainty: 0.00 ft Well path: Plan#6 W-16L 1 Drilled From: W-16 500292204560 Tie-on Depth: 10893.59 ft Current I)atum: 19 : 16 5/9/1990 00:00 Height 90.48 ft Above System Datum: Mean Sea Level Magnetic Data: 5/19/2003 Declination: 25.62 deg Field Strength: 57522 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TV D) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 270.00 Targets . "",,,,,~--,~,...,-...,..~,,,- ... n'" .,. ....~..'_ Map Map <--- 'Latitude --> <-- "Longitude'--> Name Description TVD +N/-S +E/-W Northing Easting DegMin Sec Deg Min Sec Dip. Dir. ft ft ft ft ft ,P'"'''-''.''-''''''-''-'.'"''' W-16L 1 Polygon6.1 0.00 -959.39 2907.11 5958540.00 614970.00 70 17 43.999 N 149 4 8.558 W -Polygon 1 0.00 -959.39 2907.11 5958540.00 614970.00 70 17 43.999 N 149 4 8.558 W -Polygon 2 0.00 -1156.38 2904.17 5958343.00 614970.00 70 17 42.062 N 149 4 8.645 W -Polygon 3 0.00 -1194.86 4142.84 5958323.00 616209.00 70 17 41.677 N 149 3 32.544 W -Polygon 4 0.00 -1338.33 4440.76 5958184.00 616509.00 70 17 40.265 N 149 3 23.863 W -Polygon 5 0.00 -1355.21 4633.55 5958169.99 616702.00 70 17 40.098 N 149 3 18.245 W -Polygon 6 0.00 -1215.76 4739.65 5958311.00 616806.00 70 17 41.468 N 149 3 15.150 W -Polygon 7 0.00 -1016.40 4382.55 5958505.00 616446.00 70 17 43.431 N 149 3 25.554 W W-16L 1 Fault 1 0.00 -1290.08 4290.46 5958230.00 616358.00 70 17 40.740 N 149 3 28.243 W -Polygon 1 0.00 -1290.08 4290.46 5958230.00 616358.00 70 17 40.740 N 149 3 28.243 W -Polygon 2 0.00 -1459.94 4479.96 5958062.99 616550.00 70 17 39.069 N 149 3 22.723 W W-16L 1 Fault 3 0.00 -1314.44 2838.81 5958184.00 614907.00 70 17 40.507 N 149 4 10.552 W -Polygon 1 0.00 -1314.44 2838.81 5958184.00 614907.00 70 17 40.507 N 149 4 10.552 W -Polygon 2 0.00 -1534.24 3895.74 5957980.00 615967.00 70 17 38.341 N 149 3 39.751 W -Polygon 3 0.00 -1789.43 4576.07 5957735.00 616651.00 70 17 35.827 N 149 3 19.928 W -Polygon 4 0.00 -1534.24 3895.74 5957980.00 615967.00 70 17 38.341 N 149 3 39.751 W W-16L 1 Fault 2 0.00 -1211.46 4853.74 5958317.00 616920.00 70 17 41.510 N 149 3 11.825 W -Polygon 1 0.00 -1211.46 4853.74 5958317.00 616920.00 70 17 41.510 N 149 3 11.825 W -Polygon 2 0.00 -655.09 3628.79 5958854.99 615687.00 70 17 46.989 N 149 3 47.519 W W-16L 1 T6.2 8810.00 -1127.85 3740.77 5958384.00 615806.00 70 17 42.339 N 149 3 44.262 W W-16L1 T6.1 8921.00 -1244.00 4420.17 5958278.00 616487.00 70 17 41.193 N 149 3 24.462 W W-16L 1 T6.3 8940.00 -1078.68 2925.34 5958421.00 614990.00 70 17 42.826 N 149 4 8.028 W 'O""···:'b.·P II 'II , BP .., ) ) Baker Hughes INTEQ Planning Report 1l1i.1 BAK,I" HUGIIIS ..."""""".".,..,,,,,,..,,.,,,,,,,,,,,.,,,,,,...,,,,,,..,,,...,,,,,,,,,,,,,..,,....."..."'......,.." IN'TEQ ".~_,.,_,__ ,_ ...,~~__.___.·.'._.~.h_.··~·_'",,··. .."" .,'~,,_. ......." .,." ,__ Company: BP Amoco Field: Prudhoe Bay Site: PB W Pad Well: W-16 Wellpath: Plan#6 W-16L 1 Annotation MD TVO ft ft 10893.59 8744.36 TIP 10904.00 8751.35 KOP 10924.00 8765.00 3 10964.00 8795.45 4 11039.00 8853.22 5 11239.43 8917.79 6 11319.43 8903.12 7 11559.43 8859.49 8 11759.43 8824.08 9 11934.43 8808.99 10 12034.43 8817.44 11 12234.43 8850.87 12 12499.43 8895.99 13 12750.00 8939.28 TO Plan: Plan #6 Identical to Lamar's Plan #6 Principal: Yes Plan Section Information Date: 5/19/2003 Time: ·14:12:32 Co-ordinåte(NE) Reference: Well:W-16, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,270.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle I)age: 2 .. ._"-,..,,..... ..,...,,' .,... Date Composed: Version: Tied-to: 5/19/2003 3 From: Definitive Path MI) Incl Azim TVO +N/-S tE/,;,W DLS Build Turn TFO Target ft deg deg ,ft ft ft deg/100ftdegl1 OOftdeg/1 OOft deg . "'-""".' 10893.59 47.85 119.93 8744.36 -1086.14 4489.99 0.00 0.00 0.00 0.00 10904.00 47.81 119.98 8751.35 -1089.99 4496.68 0.52 -0.38 0.48 137.20 10924.00 46.12 120.83 8765.00 -1097.39 4509.28 9.00 -8.44 4.27 160.00 10964.00 35.24 143.08 8795.45 -1114.15 4528.76 45.00 -27.20 55.63 135.00 11039.00 47.23 192.27 8853.22 -1159.67 4536.12 45.00 15.98 65.58 90.00 11239.43 100.00 273.15 8917.79 -1244.39 4390.56 45.00 26.33 40.35 76.50 11319.43 100.42 309.75 8903.12 -1216.13 4318.60 45.00 0.53 45.75 86.00 11559.43 100.08 280.47 8859.49 -1117.09 4107.21 12.00 -0.14 -12.20 272.00 11759.43 100.01 256.10 8824.08 -1122.94 3911.94 12.00 -0.03 -12.19 272.00 11934.43 89.81 274.54 8808.99 -1136.88 3739.14 12.00 -5.83 10.54 118.00 12034.43 80.51 282.17 8817 .44 -1122.47 3640.73 12.00 -9.30 7.62 141.00 12234.43 80.53 257.83 8850.87 -1122.49 3445.02 12.00 0.01 -12.17 268.00 12499.43 80.38 290.09 8895.99 -1104.72 3187.94 12.00 -0.05 12.17 93.00 ¡ 12750.00 80.18 259.57 8939.28 -1084.18 2944.92 12.00 -0.08 -12.18 267.00 Survey MD Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg .._~".,__.__,.__h.__ . ____..._"._._..___._ ......_w,..'. ... 10893.59 47.85 119.93 8744.36 -1086.14 4489.99 5958436.87 616554.46 -4489.99 0.00 0.00 TIP 10900.00 47.83 119.96 8748.67 -1088.51 4494.11 5958434.56 616558.61 -4494.11 0.52 137.20 MWD 10904.00 47.81 119.98 8751.35 -1089.99 4496.68 5958433.11 616561.20 -4496.68 0.52 137.18 KOP 10924.00 46.12 120.83 8765.00 -1097.39 4509.28 5958425.91 616573.91 -4509.28 9.00 160.00 3 10925.00 45.80 121.28 8765.70 -1097.76 4509.90 5958425.54 616574.54 -4509.90 45.00 135.00 MWD 10950.00 38.55 134.14 8784.25 -1107.87 4523.19 5958415.63 616587.98 -4523.19 ~5.00 134.69 MWD 10964.00 35.24 143.08 8795.45 -1114.15 4528.76 5958409.44 616593.63 -4528.76 45.00 125.12 4 10975.00 35.54 151.62 8804.42 -1119.50 4532.18 5958404.14 616597.14 -4532.18 45.00 90.00 MWD 10981.88 36.03 156.85 8810.00 -1123.12 4533.93 5958400.55 616598.94 -4533.93 45.00 83.04 W-16L 1 T 11000.00 38.35 169.81 8824.46 -1133.57 4537.03 5958390.15 616602.19 -4537.03 45.00 78.80 MWD 11025.00 43.55 185.08 8843.38 -1149.84 4537.64 5958373.89 616603.04 -4537.64 45.00 68.45 MWD 11039.00 47.23 192.27 8853.22 -1159.67 4536.12 5958364.04 616601.67 -4536.12 45.00 56.88 5 11050.00 48.57 198.70 8860.60 -1167.53 4533.94 5958356.15 616599.61 -4533.94 45.00 76.50 MWD 11075.00 52.82 212.18 8876.48 -1184.89 4525.60 5958338.67 616591.53 -4525.60 45.00 72.19 MWD 11100.00 58.42 224.01 8890.62 -1201.03 4512.86 5958322.34 616579.03 -4512.86 45.00 63.62 MWD 11125.00 64.99 234.41 8902.49 -1215.33 4496.19 5958307.80 616562.58 -4496.19 45.00 56.91 MWD 11150.00 72.20 243.69 8911.63 -1227.23 4476.25 5958295.60 616542.82 -4476.25 45.00 51.97 MWD 11175.00 79.81 252.24 8917.68 -1236.29 4453.79 5958286.21 616520.50 -4453.79 45.00 48.56 MWD 11200.00 87.63 260.38 8920.42 -1242.15 4429.68 5958279.99 616496.49 -4429.68 45.00 46.49 MWD bp Company: BP Amoco Field: Prudhoe Bay Site: PB W Pad Well: W-16 WeUpath: Plan#6 W-16L 1 Survey MD ft 11225.00 loci deg 95.50 11239.43 100.00 11250.00 100.30 11275.00 100.71 11300.00 100.71 11319.43 100.42 11325.00 100.44 11350.00 100.53 11375.00 100.58 11400.00 100.61 11425.00 100.60 11450.00 100.57 11475.00 100.51 11500.00 100.41 11525.00 100.29 11550.00 100.14 11559.43 100.08 11575.00 100.14 11600.00 100.21 11625.00 100.26 11650.00 100.27 11675.00 100.26 11700.00 100.22 11725.00 100.15 11750.00 100.06 11759.43 100.01 11775.00 11800.00 11825.00 11850.00 11875.00 11900.00 11925.00 11934.43 11950.00 11975.00 12000.00 12025.00 12034.43 12050.00 12075.00 12100.00 12125.00 12150.00 12175.00 12200.00 12225.00 12234.43 12250.00 12275.00 12300.00 12325.00 99.13 97.70 96.25 94.79 93.32 91.85 90.37 89.81 88.36 86.03 83.70 81.38 80.51 80.45 80.38 80.33 80.31 80.31 80.34 80.40 80.49 80.53 80.43 80.31 80.20 80.13 Azim deg 268.43 273.15 277.98 289.41 300.86 309.75 309.07 306.02 302.97 299.92 296.87 293.81 290.76 287.71 284.67 281.62 280.47 278.58 275.53 272.48 269.43 266.38 263.34 260.29 257.24 256.10 257.77 260.43 263.08 265.71 268.33 270.95 273.56 274.54 275.72 277.61 279.51 281.43 282.17 280.27 277.23 274.19 271.14 268.10 265.06 262.01 258.97 257.83 259.72 262.76 265.80 268.85 ) BP ) BaKer Hughes INTEQ Planning Report SSTVD ft 8919.73 8917.79 8915.92 8911.35 8906.69 8903.12 8902.11 8897.56 8892.98 8888.39 8883.78 8879.19 8874.62 8870.08 8865.58 8861.15 8859.49 8856.76 8852.34 8847.90 8843.44 8838.98 8834.54 8830.11 8825.73 8824.08 8821.49 8817.83 8814.80 8812.39 8810.62 8809.49 8809.01 8808.99 8809.24 8810.47 8812.71 8815.95 8817.44 8820.01 8824.18 8828.37 8832.57 8836.78 8840.99 8845.17 8849.32 8850.87 8853.45 8857.63 8861.87 8866.14 N1S ft -1244.58 -1244.39 -1243.38 -1237.57 -1227.16 -1216.13 -1212.65 -1197.67 -1183.76 -1170.94 -1159.26 -1148.74 -1139.42 -1131.32 -1124.46 -1118.87 -1117.09 -1114.55 -1111.53 -1109.81 -1109.40 -1110.30 -1112.50 -1116.01 -1120.80 -1122.94 -1126.41 -1131.09 -1134.65 -1137.08 -1138.37 -1138.53 -1137.54 -1136.88 -1135.49 -1132.59 -1128.88 -1124.38 -1122.47 -1119.49 -1115.74 -1113.28 -1112.14 -1112.30 -1113.77 -1116.55 -1120.62 -1122.49 -1125.48 -1129.23 -1131.69 -1132.84 .. ,. ".".... . ".".-., .,.",-.. ',' .'-, -....."..,_.~ .,.,,,..,,~,,, ....,.,-...,..- ... BAN.. RUGHI. II.N'l'.EQ Date: 5/19/2003 Time: 14:12:32 I)age: 3 Co-ordinate(NE) Reference: Well: W-16, True North Vertical (TVD) Reference: System: Mean Sea Level Section(VS) Reference: Well (0.00N,O.00E,270.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ,""w.." _.'0... . _, "'~""'H~"..''''_ E/W ft 4404.85 4390.56 4380.21 4356.37 4334.17 4318.60 4314.37 4294.88 4274.63 4253.66 4232.05 4209.84 4187.10 4163.89 4140.28 4116.32 4107.21 4092.10 4067.68 4043.14 4018.55 3993.97 3969.47 3945.11 3920.98 3911.94 3896.99 3872.71 3848.15 3823.39 3798.49 3773.52 3748.54 3739.14 3723.63 3698.83 3674.21 3649.84 3640.73 3625.66 3601.30 3576.78 3552.17 3527.53 3502.93 3478.44 3454.13 3445.02 3429.96 3405.60 3381.09 3356.49 MapN ft 5958277.19 5958277.17 5958278.02 5958283.47 5958293.55 5958304.35 5958307.76 5958322.45 5958336.06 5958348.56 5958359.92 5958370.10 5958379.08 5958386.83 5958393.34 5958398.57 5958400.22 5958402.53 5958405.18 5958406.54 5958406.58 5958405.32 5958402.75 5958398.88 5958393.73 5958391.45 5958387.76 5958382.72 5958378.80 5958376.00 5958374.34 5958373.81 5958374.42 5958374.95 5958376.11 5958378.63 5958381.97 5958386.11 5958387.88 5958390.64 5958394.03 5958396.11 5958396.89 5958396.36 5958394.53 5958391.39 5958386.95 5958384.95 5958381.73 5958377.62 5958374.80 5958373.28 -"._..",~"."".,-"."."..,,",--- MapE ft 616471.70 616457.41 616447.04 616423.12 616400.77 616385.04 616380.75 616361.05 616340.59 616319.44 616297.66 616275.30 616252.42 616229.10 616205.39 616181.35 616172.22 616157.06 616132.61 616108.05 616083.45 616058.89 616034.43 616010.13 615986.07 615977.07 615962.17 615937.96 615913.47 615888.74 615863.87 615838.90 615813.92 615804.51 615788.98 615764.15 615739.48 615715.04 615705.90 615690.80 615666.38 615641.83 615617.21 615592.57 615568.00 615543.56 615519.31 615510.24 615495.22 615470.92 615446.45 615421.87 VS ft -4404.85 -4390.56 -4380.21 -4356.37 -4334.17 -4318.60 -4314.37 -4294.88 -4274.63 -4253.66 -4232.05 -4209.84 -4187.10 -4163.89 -4140.28 -4116.32 -4107.21 -4092.10 -4067.68 -4043.14 -4018.55 -3993.97 -3969.4 7 -3945.11 -3920.98 -3911.94 -3896.99 -3872.71 -3848.15 -3823.39 -3798.49 -3773.52 -3748.54 -3739.14 -3723.63 -3698.83 -3674.21 -3649.84 -3640.73 -3625.66 -3601.30 -3576.78 -3552.17 -3527.53 -3502.93 -3478.44 -3454.13 -3445.02 -3429.96 -3405.60 -3381.09 -3356.49 DLS deg/100ft 45.00 45.00 45.00 45.00 45.00 45.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 TFO Tool deg 45.59 MWD 45.81 6 86.00 MWD 86.85 MWD 88.94 MWD 91.08 7 272.00 MWD 271.88 MWD 271.32 MWD 270.76 MWD 270.20 MWD 269.64 MWD 269.08 MWD 268.52 MWD 267.97 MWD 267.42 MWD 266.88 8 272.00 MWD 271.67 MWD 271.13 MWD 270.59 MWD 270.04 MWD 269.50 MWD 268.96 MWD 268.42 MWD 267.88 9 118.00 MWD 118.28 MWD 118.67 MWD 118.99 MWD 119.24 MWD 119.43 MWD 119.55 MWD 119.60 10 141.00 MWD 140.98 MWD 140.89 MWD 140.72 MWD 140.47 11 268.00 MWD 268.31 MWD 268.82 MWD 269.33 MWD 269.84 MWD 270.35 MWD 270.87 MWD 271.37 MWD 271.88 12 93.00 MWD 92.69 MWD 92.18 MWD 91.66 MWD O'~'" "::, , bp I II "I I Company: Field: Site: Well: Wellpath: Survey MD ft 12350.00 12375.00 12400.00 12425.00 12450.00 12475.00 12499.43 12500.00 12525.00 12550.00 12575.00 12600.00 12625.00 12644.56 12650.00 12675.00 12700.00 12725.00 12750.00 BP Amoco Prudhoe Bay PBW Pad W-16 Plan#6 W-16L 1 Incl deg 80.09 80.07 80.08 80.11 80.18 80.27 80.38 80.38 80.23 80.12 80.03 79.97 79.93 79.93 79.93 79.95 80.00 80.08 80.18 Azim deg 271.89 274.94 277.98 281.03 284.07 287.11 290.09 290.02 286.98 283.93 280.89 277.84 274.80 272.41 271.75 268.70 265.66 262.61 259.57 , BP ", BaJr Hughes INTEQ Planning Rep¿rt SSTVD ft 8870.43 8874.74 8879.05 8883.36 8887.64 8891.88 8895.99 8896.09 8900.30 8904.56 8908.87 8913.22 8917.58 8921.00 8921.95 8926.32 8930.67 8935.00 8939.28 ." . 0- "_,~__._ _.._.' .__ ...~ .,", _"... ""_'"0_"" ,~. ,.. ._._._,._." ._,. ."". .... ,_w' "n,.," .""'" ~.'~' '~"'''_.''_ ""~_'~"~~'h~", ".." .,~"",", _ "'" ~_.. ~ N/S ft -1132.68 -1131.21 -1128.44 -1124.37 -1119.02 -1112.40 -1104.72 -1104.53 -1096.71 -1090.15 -1084.85 -1080.85 -1078.14 -1076.93 -1076.73 -1076.64 -1077.85 -1080.36 -1084.18 tAI,iI, '.1 BAlla .. . """.,..".,"."'_."',"..,,..,,.....,..",,''''"~..".. I.N""I"'EQ Date: 5/19/2003 Time:.14:12:32 Page: 4 Co-ordinate(NE) Reference: Well: W-16, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,270.00Azi) S~.~~~~~l~u"~~~.~~~~~~~:..._._",.~i~i~um Curvature Db: Oracle - ", ...~ - _, . "",...' n" .. E/W ft 3331.86 3307.28 3282.82 3258.53 3234.49 3210.76 3187.94 3187.41 3164.05 3140.31 3116.26 3091.97 3067.51 3048.29 3042.93 3018.32 2993.74 2969.25 2944.92 MapN ft 5958373.07 5958374.17 5958376.58 5958380.28 5958385.27 5958391.54 5958398.88 5958399.06 5958406.53 5958412.74 5958417.67 5958421.32 5958423.66 5958424.58 5958424.70 5958424.43 5958422.85 5958419.97 5958415.80 ~'....... ·.~._~_.._.·.·..·._·'..H_..'. ,.,.,_._ MapE ft 615397.25 615372.65 615348.15 615323.81 615299.69 615275.87 615252.94 615252.41 615228.93 615205.10 615180.98 615156.63 615132.13 615112.90 615107.55 615082.94 615058.37 615033.92 615009.66 VS ft -3331.86 -3307.28 -3282.82 -3258.53 -3234.49 -3210.76 -3187.94 -3187.41 -3164.05 -3140.31 -3116.26 -3091.97 -3067.51 -3048.29 -3042.93 -3018.32 -2993.74 -2969.25 -2944.92 DLS deg/100ft 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.04 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 TFO deg 91.14 90.62 90.10 89.57 Tool MWD MWD MWD MWD 89.05 MWD 88.52 MWD 88.01 13 267.00 MWD 267.01 MWD 267.52 MWD 268.04 MWD 268.57 MWD 269.10 MWD 269.63 W-16L 1 - 270.05 MWD 270.16 MWD 270.69 MWD 271.22 MWD 271.75 TD I' ) BOP-Tree ) Rig Floor I. 1"""'Y,,, J ~ ::: ': !;!i:' ,¡:::, ¡ ::I:l;~: I¡: ¡ ::: ""I"':""""""; w::"'",:"""""""'",, ""''':''''' ,,: '"", 'i·.;çm¡~;~· '1'" KB Elevation i:,:l I Lubricator I D = 6.375" with 6" Otis Unions I I~.OO" 5000 psi I: "i I,: I " I: , , :: "I, ~ :' I ' I ',"I~::~ I: 1/16"5000 psi BOP's. ID=7.06" I L~1:,,:\,,~~r;" 171/16" 5000 psi. RX-46 I " , ~""" ,'," , '/ 1",1,,:1':';'::, .. F 7'1,1/4 Turn L T Valve I J\ \' \ I ,l' , ~} 7 1/16" 5000 psi RX-46 I I II~I I ,I .. 1_1""1" ,I II r I , I I' '~', ..~\~' I Kill Line t \' ': I"'~ / ,),_' , .- 121/16" 5000 psi, RX-24 I .,1 '/ ,I ,f', 'I , I \ I' I "I ,1 7 1/16" 5000 psi (RX-46) or " -+-- 41/16" 5000 psi (RX-39) ;,1 1,.,1 :<-:1:::::::,1 , ::';:'j::,::":' ,"'1 L1Lw Choke Line ~ I' It, Swab Valve I -+ SSV I Master Valve I Base Flanje I Page 1 p055064 DATE 4/4/2003 --. INVOICE / CREDIT MEMO DESCRIPTION INV# CK0401 03N THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORAT10N, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE:, AK99519-6612 PAY: /...'-" TO THE ORDER OF: GROSS PERMIT TO DRILL FEE LtJj\ to G\ NATIONAL CITY BANK Ashland. Ohio . .~ Ii. f.) .~~~[·(~:'u(~, :!~~;~: ~=~~~f . .-.- - --. . . . . -- -.. .-. .--.. -- -.- --- - --.p. :---- --- ----.-.- ---.. ':.:"- - . ALASKA OIL & GAS CONSERV.f\TION CC)MMISSION 333 W 7THAVENUE SUITE 100 ANCHORAGE,AK 99501-3539 III 0 5 SOb ... III I: 0... . 2 0 ~ B ~ 5 I: o. 2 7 B ~ b liD DATE 4/4/2003 CHECK NO. 055064 VENDOR DISCOUNT NET H 56-389 412 No. P 055064 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *******$100.00******* NOTVALl9.'~.~~'~..~'~~.~~:'~N· ,.-;"AT- ..--AV;' '.. .. ~~:.=" ..::'~:..~:: ~.~;:.:. :.:... .::.~..:. .:~.:::;;/..}~:..:}~~}\/ ::,:,:.:;:,:, ì . '. ~~.. ::.. ...... ..... ...... ....... ····1 j~'/~T ~~¡~\,':::~~'::;¡i~;i;:;:;"~i~ Rev: 07/10/02 ajody\templates \ ,I ) . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well _ . Permit No, API No. Production. should continue to be reported as a function· of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated . in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~~hl±ig~J!¡j.tl~~~:~Ç,I~Jci Company BP EXPLQRATION (ALASKA) INC Well Name: Effi)DHOE BAY UNIT W-16L1 Program JU;:V Well bore seg PTD#: 2031 000 Field & Pool PRUDHO~UDHOE OJ~64.0J 50 Initial Classrrype -DEV /1-0IL GeoArea _8.90 Unit 11650 On/Off Shore ~ Annular Disposal Administration 1 P~(mil fee attache.d _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . Y~s _ _ _ _ _ . . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - - - - . - . - - - - - - - - - - - - . . - - , 2 .Leas~_n!,Jmber _appropriale. . . _ . . _ _ _ . _ . _ . _ . . . . _ . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ . . _ _ _ _ ,. _ _ _ _ . . _ _ _ _ _ _ _ _ . . . . - _ - - . . . - . - - - - - - - . . . - - - - - - - . 3 _U_nique well_n_a!.11~_a!:1d OlUlJb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ .. _ _ _ _ _ _ _ _ _ _ _ _Y~$ .. .. .. _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - - .. - - - - - - - - - - .. - - - - - - - 4 We.llJQcaled in_a_d_efil1e.d_PPQI. _ . _ . _ _ _ .. . _ _ _ _ _ _ _ _ . _ . _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ . . _ . _ . _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ .. _ . _ _ _ _ _ _ _ _ . - . . . - - - - . . . . - - 5 .WellJQcaled prpper _distance_ from driJling unitb.ound_al)'. _ . . _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _. .Y~s _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ .. _ _ . _ _ _ . _ _ _ _ . .. _ _ . _ _ _ _. . . _ . - - . - - - - .. . . - - - - - .. . .. . - . . - - - - - - - 6 .We.IIJQcated pr9per .dlstance. from. Qtb~r Wßlls. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - - - - - - - - .. - - - - - - - - - - - - - - - - - - - 7 .S_ufficient .acreag.e.ayailable in_dritli09 unjL _ _ _ _ _ _ _ _ . _ . _ _ _ . . . _ . _ . . . _ . _ . _ _ _ . Yes _ . . _ _ _ _ _ . _ . . _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ .. . . ., _ . _ _ _ .. _ - - - - - - .. . . . . . . - . - - . . . . . 8 Jf.d~viatec!, js. weJlbQre plat..il1cJu.dec! _ _ . _ _ . _ . . . . _ . . . . . . . . _ .. . . _ . . _ . . . . . . . Y~$ . . . . _ . . . . . . _ _ _ _ . . . . _ . . . . _ .. . . . . . . . . _ _ _ . . .. .. . . . _. . . . .. . . . . . . . . . . . . . . - - .. . - . . . . . . 9 .Qper:.ator only- affected party _ . _ _ . . . . . .. _ . _ _ _ _ _ _ . . _ _ .. . . _ . . . . . . _ _ . ., _ _ _ . Y~s . . _ . . . . . _ _ _ . _ . _ . . _ _ _ _ _ . _ . . ,. . _ ., . _ _ _ . . . - . . . . . - - . . . - . . . . .. - . . - - - . . - - - . - . . . . . . - . 10 _Qper_ator bas_apprppriate. bond in .force _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - . - - - - - .. - - - - . - - - - - - - - - 11 P~(mil c.an be iS$ueçl wjtbQut com~erva.tion Qrder _ _ _ _ _ . _ . _ . _ . . _ _ _ . . . _ _ . . . . . . _ Y~$ _ . _ _ _ _ . . . _ . _ . . _ _ _ _ _ _ _ . . . _ . _ _ . _ _ _ _ _ _ _ . . _ . - . - . . - .. . - - - - . . - - . . - . . - - - - - . .. . . . . . - . 12 P~(mil c.an be issueçl wjtbQut admil1istr:.ative.a,pprpvaJ _ . . _ _ _ . . . _ _ . . . _ . _ _ _ _ _ _ . _ . Y~s _ _ _ _ _ . . _ . . . . . . _ _ _ _ _ .. _ . . . _ . . _ _ _ _ .. .. . _ _ _ _ . . _ _ - _ _ - . . . . - - - - - . . . . . - - - - - - - . . . . - . . - P~ ~\ 6/5/2003 13 Can permit be approved before 15-day wait Yes l 14 .WellJQcaled within area an.d_strata _authQri~ed by.lojectipo Ord~r # (pullO# in.cP01m.eotS).(For_ _NA . .. . . . _ . . _ . .' . .. . . . _ . . . - - . . . .. . . . . . . . . - . , . . . . . - . . . - .. . . . . . . . - - . . . . . ., . - - . . - . . . . . . 15 _AJI weUs_ wit!1i.n ..1l4_ruile _area_of reyiew jd.eot!fied (Fpr $.ervjc.e well OI1Iy-).. _ _ _ _ _ _ _ _ _ . _ .. . _ _NA _ _ _ _ _ _ . _ _ _ _ _ .. _ _ _ _ _ _ _ . . . . _ _ _ . _ _ .. _ _ _ _ _ _ _ _ _ _ _ . _ - - . - - .. - . - . . . . . . . .. - - - - - - - . - . . . . . 16 Pre-produ.Gedinjector; .duratio_n.ofpre-:pro.ductipl1l~ss.t/1an.3montbs.(For.ser:vi.cewell Qn.ly) .. NA. _ _ _. _..... _ _. _........... _ _.'.'" _ _ _ _ _ _. _..... - - _.... _... - - -'.' -... - - - - - -'.- 17 A.cMP. fin.djng _of CQn.$i.$t.ency_ h.as bee.n J$.sued. for.tbis pr.oJect. . _ . . _ .. _ _ _ . . . _ . . . . . . _NA . . _ _ _ _ _ _ . . _ _ _ _ .. . _ . . . . . . . . _ _ _ _ _ . _ . . . _ _ _ . . . - . . . . . - - . . - . . . . - - . - . - . . - . - . - . - . - - , 18 .C.onc!u_ctor strin.g_prQvided . . _ . _ _ _ _ . _ ., _ _ _ . . _ _ _ . . _ . _ _ _ _ _ .. _ . . _ . . . . . . . . _NA. _ _ . _ . . . _ . _ _ _ _ _ . . . _ . _ _ . _ . . _ . . . . _ . . . _ _ _ _ . . . . . . . . . _ . . - . . . . . - . . . . - - . . . - . - - . . . - . 19 _S_ur:fac.e .ca$.ing. protec.t$. all.known. USDWs . . . . . . . . . . . . . . . _ . . _ . _ . _ _ .. . _ . . . . .NA . . _ _ _ . _ . . . . . . . _ . _ _ . _ . . _ . . . . . . _ _ . . . - . . . - - - - - .. . - . . . - - .. . . . . . . . - - . . . - . . - . . . - - - . 20 .CMT.v_ol.adequ.ate.to circ.ul.ate.on.cond_uctor.& Su.rf_c.$g . _ _ . _ . . . . . _ _ . . . . _ _ _ . _ _ _ _ _NA _ _ _ _ . . . . . _ _ _ _ _ _ . . . . _ . _ . . . _ _ . _ _ _ . . . . . . _ _ _ _ _ _ _ _ . . . . . . _ .. . . . . . . - - . . . . . . . . . - . . . . 21 _CMT v.ol. adequate.to tie-i.nJQng .string to.sur:f c$.9- . _ . . . . . . . . . . _ _ . _ _ . _ _ _ . . . _ . . .NA _ . . . _ _ . . . . . . . _ _ _ _ _ _ _ .. . . . . . . . . _ . . . _ . . . _ . . _ _ . _ . . . . . . - . - . . . . . . . - - . . . . . . - . . . 22 .CMTwil! Goyer.all !<oo.w.n.Pfo.ductiye bQri~Qn.s. _ . _ . . _ . . . . . . . . _ . _ _ _ _ . . . . _ . . . . NA . _ _ _ _ . _ Slotte.d, . _ _ _ _ . . . . _ . . . . . . _ . . . . . . _ . . _ _ _ . _ . . . . . . . _ _ _ . . . . . - . . . .. - . . . . . . . . . . . 23 .C_asing designs adeç¡ua.te fpr C,.T., B _&. permafr_ost _ _ _ . . _ _ . _ . . _ . . . _ _ . _ _ . . . . _ _ .Yes. _ _ . _ . . _ _ _ . _ _ . _ . . . . . . . . . . . . . . . _ . _ . . . _ _ . " _ _ . .. . _ . . - - . - . . - . . . - . . . - . . . . . - 24 Adequate.tan.kage.or re.serye pit _ _ . . _ . _ . . _ . _ _ _ . _ _ _ . . _ . _ _ _ _ . . . _ . . _ _ . . . Y~s _ . . _ _ . . CTDU.. _ _ _ _ . . . . _ . . . . . _ _ ' . . . . . . . . _ _ . . . _ - . . . - - - - . - . . . . - - . . . . . . - - . 25 Jf.a_ re-d(iII~ bas.a. 1.0:-4.03 fOJ abê:!,ndonment be.eo apprQved . _ . _ . . . _ _ _ . . _ . . . _ _ _ . _ _ _NA _ _ _ . _ _ . Multilater_aL . . . _ . . . . . _ _ . _ . . _ . _ . . _ . _ _ _ _ . . . . . - - . . - . . . . . . . . . - . . . . . . - - - - - - - . . 26 .A.dequate.w:ellbore $.eparatio.n .propO$.e.d _ . _ _ _ _ _ _ _ _ . . . . _ . . . _ _ _ _ _ _ .. _ _ .. _ . _ . . .Y.e$ _ _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ _ . . _ _ . _ _ _ _ _ _ _ _ _ .. _ _ _ _ . _ _ _ . _ .. _ _ _ _ _ _ . _ . - . - - - - - - - . - - . - - - - . - 27 Jf.djverter req.uired, dQes jt .meet reguJa.tiOl1s_ . . . . _ _ . . . . . . . _ . _ _ _ . _ _ _ _ . . . . _ . . .NA. _ _ _ . _ . _ . . . . . . . . _ _ _ _ _ . . _ . . . . . . . . _ . . . . . . _ _ . _ _ - . - . . . - - . - . . . . . . . . . - . - - .- . . . . . . . . Appr Date 28 .Drilliog fluid. prQg.ram sc.hematic.&. eq.uip Jistadequale. . . . . . . . _ . . . . . _ . _ . . . . . _ . . Y.es . _ _ . _ . . Max MW.8, 7. ppg~ _ _ _ _ _ . _ . . . . . . . _ _ . . . . . . _ . _ _ _ _ _ . . . . . . . . - . . . . . - . - . . - - . . . . . . . W~A.. 6/5/2003 29 _BOPE$,.dp .they .meel reguJa_tiOI1 . . . . . . . _ . . . _ . _ . . . . _ . _ . _ . . . . . . _ . . _ . . . . Y.es _ _ . _ . . . _ . . . _ _ . _ . . . _ _ _ . . _ . . . . . _ . . . . _ _ . . _ _ . _ . . . . . . _ _ _ . . . . . . . . . . . . . . _ . . . . _ . , . . 1,,' I 30 .BOPE.pres$ ratiog appropriate;.test to.(pu.t psig in.comments). . . . . . . _ . _ . . . . . . . . . . Y~$. . _ . . . _ T~st tp_35QO.psi. _M$~ 23.4~ psi.. . . . . _ . . . . . . _ . . ._ _ _ . . ' . . . . . . . . _ _ . . . 31 _C.hoke.ruanjfold CQmpJies. w/API.RP-53 (May 84). . . _ . . . . . _ . _ . _ _ . .. . _ . . . . . . . Yes. . . . _ . . _ . _ . . . , . . _ _ . . _ . _ . . . . . . . . . . _ . . . . . . . . . _ _ _ _ - . . - - . . . . . . . . . - . . . . . . . . 32 _WQrk will PGC.ur withput.operation .sbutdo.w.n. _ _ _ . . _ . . . . . . . . _ . _ . _ . . . . . . . , . . . Y~s _ . _ _ . . . . . . . . . . . . _ . . . . . . . . . . . . _ _ . . . _ . _ . _ . . _ . . . _ . . . . -. . . . . . , . . . . - . - . - . . . . , 33 .Is. pres.ence. Qf H2S gas. prob.able. , . . . _ . . _ _ _ _ _ . . . . _ No. . . . . _ . , . . . . . . _ . . . . . , . . . . . . . . . . . _ . . _ . . . . . . 34 MecIJa.ni.cal.cpodJUo!:1ptwellswithinAORyerified(For_s_ervicewelJon.Iy-).. _ _........ _. NA. _........., ..... _.. _... _... ,_........ _..... - _. - - -..... Appr Date Engineering Geology Appr RPC Date 6/5/2003 Geologic Commissioner: - - - - - - - - - 35 P.e(mil can be i.ssueçl wto. hydr:ogen. s.ulfide measjJres. . . . . , . . . . , . . . , , No. . . . . . _ . . . 36 _D.ata.preseoted on. pote.ntiê:!1 pve.rpres.s\,Jr.e ,zone.$. . _ . _ _ . . .. .. . . . . . . . . . . . .NA. _ . _ _ _ . . . . . . . . . _ _ . . _ _ . . . . 1137 .Sei.smic.analysjs. Qf sIJa.llow gas.zPlJes. . . . _ . . _ . . . . . _ . . . . . . . . _ . NA _ _ . . . . . . . . . . . . . . . . . . 38 .Seabed .condjtiPIJ survey .(if off-sh.ore) . . . . _ . . . . . . . . . . . . . , . NA. _ . . _ _ . . . . . . . . . . . . . . . . . . . . . . . 139 . CQnta.ct nam.elp/1on.eJor.w:eekly progress,reports [explQratpry .only]. . . . . . . . _ .. .,... NA. _ _ . . . _ . _ . . . . . _ _ _ _ . . _ _ _ , _ . . . . . . . _ . . . _ . . . . . - - - - - ~ . - - - - - - - - - - - - - - - . - - - - - - - - - - - - ~ . - - . - - - - . - . - - - - - - - - - - . . - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - . - - - Date: Engineering Commissioner: Public commiSSi~ ~ Date ~ ~~~ ~ o Welll-iistol)' File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sinlplify 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 infornlation. ,¡- Sperry-Sun Dr~ _ng Services LIS Scan utility { fj03-¡OÙ $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 06 13:10:31 2003 ; ~\ d- Reel Header Service name............ .LISTPE Date.................... .03/10/06 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. . . . . . . . . . . . . . . . . . . . .03/10/06 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 W-16A 500292204501 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 30-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002548805 B. JAHN SEVCIK/EGBEJ MWD RUN 4 MW0002548805 B. JAHN SEVCIK/EGBEJ MWD RUN 5 MW0002548805 B. JAHN SEVCIK/EGBEJ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0002548805 S. LATZ SEVCIK/SARBE MWD RUN 7 MW0002548805 S. LATZ SEVCIK/SARBE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 11N 12E 801 1183 i¡:;~:' f~E iV' '" E' ""'... . 1;1ffm.'f1 ~!.o:tV ~fAn I I OCT 1 0 ?OO:;} 90.48 # WELL CASING RECORD ß;·j';'¡:~i~;.:;~ ~U:'t ,;;i;';;::::;::; . C:Ufnmissiol1 j~ncllm~~ge OPEN HOLE CASING DRILLERS ~~~tY\& 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT s1 3.750 (IN) SIZE (IN) DEPTH (FT) 7.000 10875.0 ( # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE W-16 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 10876'MD/8733'TVDSS. 4. MWD RUN 1 WAS DIRECTIONAL AND GAMMA MODULE (GM, UTILIZING GEIGER-MUELLER TUBE DETECTORS) TO SET THE FIRST WHIPSTOCK. 5. MWD RUN 3 COMPRISED DIRECTIONAL AND GM. UPHOLE (BEHIND CASING, 10789.5'- 10825') SGRC DATA WERE ACQUIRED WHILE RIH FOR RUN 3. THESE DATA ARE MERGED WITH RUN 1 MWD DATA. THE PURPOSE OF THIS RUN WAS TO POSITION THE SECOND WHIPSTOCK. 6. MWD RUN 4 COMPRISED DIRECTIONAL AND GM. THE PURPOSE OF THIS RUN WAS TO KICK OFF THE WHIPSTOCK AND BUILD TO THE INVERSION POINT. 7. MWD RUNS 5-7 COMPRISED DIRECTIONAL¡ GM¡ SUPERSLIM ELECTRO-MAGNETIC WAVE RESISTIVITY - PHASE 4 (SSEWR). 8. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN IN W-16 ON 7/16/2003. THESE DATA WERE PROVIDED TO SSDC BY D. SCHNORR, BP EXPLORATION (ALASKA), INC., ON 9/16/03. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 1, 3 - 7 REPRESENT WELL W-16A WITH API#: 50-029-22045-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12904'MD/8854'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY ( DEEP $ File Header Service name............ .STSLIB.001 service Sub Level Name..( Version Number......... ..1.0.0 Date of Generation.... ...03/10/06 Maximum Physical Record. .65535 F i Ie Typ e . . . . . . . . . . . . . . . . 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 FET RPD RPM RPS RPX ROP $ 1 ~. and clipped curves; all bit runs merged. .5000 START DEPTH 10790.0 10881.5 10881.5 10881.5 10881.5 10881.5 10900.0 STOP DEPTH 12853.5 12866.0 12866.0 12866.0 12866.0 12866.0 12897.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 10790.0 10790.5 10792.5 10799.0 10803.5 10819.5 10836.0 10845.5 10854.0 10878.0 10885.5 10900.0 10911.0 10915.5 10934.0 10940.0 10941.0 10945.5 10950.5 10953.5 10960.0 10968.5 10980.5 10983.0 10998.5 11002.0 11006.0 11018.5 11037.5 11056.0 11061.5 11090.5 11102.0 11109.5 11135.5 11152.0 11169.0 11174.0 11181.0 GR 10789.5 10790.0 10792.0 10798.0 10802.5 10818.5 10835.5 10844.5 10853.0 10875.5 10883.0 10896.5 10909.5 10912.5 10932.0 10938.5 10940.0 10943.5 10947.5 10951.0 10955.0 10963.0 10973.5 10977.0 10991.0 10994.0 10997.5 11011.0 11030.0 11049.5 11054.5 11082.5 11093.5 11100.5 11126.0 11144.0 11157.0 11165.0 11174.0 ( 11179.~ 11200.0 11215.5 11238.5 11261.5 11302.0 11317.0 11379.0 11394.0 11397.5 11399.5 11415.0 11448.0 11466.5 11487.0 11489.0 11490.5 11494.5 11513.0 11521.0 11536.0 11553.5 11575.0 11592.5 11628.0 11641.5 11653.0 11672.0 11679.0 11701.0 11709.0 11778.5 11828.5 11849.5 11863.5 11894.0 11906.5 11917.5 11947.0 11995.5 12009.5 12018.0 12021.5 12040.0 12062.5 12084.0 12091.0 12107.0 12116.5 12130.5 12147.0 12172.0 12182.5 12196.5 12255.0 12264.5 12325.5 12333.5 12351.5 12364.0 12384.0 12410.0 12430.5 12462.0 12473.0 12547.0 12585.5 12600.0 11187.0 11210.5 11223.0 11245.0 11264.5 11307.5 11322.5 11376.5 11396.5 11400.0 11402.5 11415.5 11449.5 11469.5 11488.0 11492.0 11494.0 11496.5 11513.5 11523.0 11539.0 11558.0 11577.5 11596.0 11629.0 11642.5 11653.0 11673.0 11681.0 11702.0 11710.5 11779.5 11828.0 11849.5 11863.0 11893.0 11905.5 11917.0 11946.5 11998.5 12012.5 12020.5 12025.0 12044.5 12065.0 12083.0 12090.5 12107.5 12116.0 12131.5 12147.0 12172.5 12184.5 12197.0 12257.0 12266.0 12328.0 12336.0 12356.0 12370.0 12390.0 12415.5 12434.5 12467.0 12476.5 12551.5 12583.5 12601.0 Last Reading 12897.5 12897.5 12853.5 12866 12866 12866 12866 12866 First Reading 10790 10900 10790 10881.5 10881.5 10881.5 10881.5 10881.5 Nsam 4216 3996 4128 3970 3970 3970 3970 3970 First Reading For Entire File......... .10790 Mean 11843.8 94.474 55.8764 13.6718 15.3871 18.4974 17.5335 5.45511 Max 12897.5 2142.86 498.56 1948.09 1886.18 2000 1993.28 106.61 Min 10790 0.36 22.26 0.47 0.69 0.53 0.64 0.23 Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Name DEPT ROP GR RPX RPS RPM RPD FET 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 { # 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...O MERGE BASE 10863.0 11221.0 12106.0 12613.0 12903.5 MERGE TOP 10789.5 10863.5 11221.0 12106.0 12613.0 MERGED MAIN PASS. $ BIT RUN NO 1 4 5 6 7 12624. ~ 12666.5 12675.5 12689.0 12694.5 12700.5 12719.0 12740.5 12743.5 12784.5 12802.0 12808.5 12819.0 12827.5 12831.5 12851.5 12903.5 # REMARKS: # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ 12622.0 12668.0 12675.0 12687.0 12693.5 12698.0 12716.0 12736.0 12738.5 12778.5 12795.5 12801.5 12812.0 12821.5 12826.5 12845.5 12897.5 $ Last Reading For Entire Fill ........ .12897.5 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record. .65535 F i 1 e Type........ . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record..65535 F i 1 e 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 GR $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10789.5 STOP DEPTH 10863.0 # 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: 10-JUL-03 Insite 4.3 Memory 10896.0 10789.0 10896.0 47.8 47.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 93091 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 2674.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): KCL Brine 8.40 .0 .0 10000 .0 RESISTIVITY (OHMM) AT( 1PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: f .000 .000 .000 .000 .0 155.5 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..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 Name Service Order DEPT GR MWDOI0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 Name Service Unit DEPT FT GR MWD010 API Min 10789.5 38.72 Max 10863 403.79 Mean 10826.3 73.1332 Nsam 148 148 First Reading 10789.5 10789.5 Last Reading 10863 10863 First Reading For Entire File......... .10789.5 Last Reading For Entire File.......... .10863 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record..65535 File Type............. ...LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/10/06 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 if header data for each bit run in separate files. 4 .5000 START DEPTH 10863.5 10896.5 STOP DEPTH 11190.0 11221.0 # 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 GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing........ ............ .60 .1IN Max frames per record............ .Undefined 14-JUL-03 Insite 4.3 Memory 11221..0 10896.0 11221.0 39.7 82.0 TOOL NUMBER 93091 3.750 10570.0 Flo Pro 8.60 62.0 9.0 23000 10.8 .000 .000 .000 .000 .0 169.6 .0 .0 ,4 Absent value............ ( ..... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10863.5 11221 11042.3 716 10863.5 11221 ROP MWD040 FT/H 1.64 834.62 65.5067 650 10896.5 11221 GR MWD040 API 24.16 498.56 104.834 654 10863.5 11190 First Reading For Entire File......... .10863.5 Last Reading For Entire File.......... .11221 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record. .65535 File Type....... . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/06 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 RPD RPM RPS RPX FET GR ROP $ 4 header data for each bit run in separate files. 5 .500'0 START DEPTH 10879.0 10879.0 10879.0 10879.0 10879.0 11190.5 11221.5 STOP DEPTH 12078.0 12078.0 12078.0 12078.0 12078.0 12065.5 12106.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 16-JUL-03 Insite 4.3 DATA TYPE (MEMORY OR REA~ ~ME): 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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.....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 Memory 12106.0 11221.0 12106.0 f 88.1 102.6 TOOL NUMBER 82758 126589 3.750 10904.0 Flo Pro 8.60 62.0 8.5 19000 7.2 .090 .030 .240 .180 68.0 187.0 68.0 68.0 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 First Last Name Service Unit Min ( Max Mean Nsam i{ .ding Reading DEPT FT 10879 12106 11492.5 2455 10879 12106 ROP MWD050 FT/H 0.54 2142.86 107.462 1770 11221.5 12106 GR MWD050 API 22.42 171.18 48.9781 1751 11190.5 12065.5 RPX MWD050 OHMM 0.47 1948.09 13.064 2399 10879 12078 RPS MWD050 OHMM 0.69 1886.18 14.9338 2399 10879 12078 RPM MWD050 OHMM 0.53 2000 19.5673 2399 10879 12078 RPD MWD050 OHMM 0.64 1993.28 17.5179 2399 10879 12078 FET MWD050 HOUR 0.23 106.61 7.65007 2399 10879 12078 First Reading For Entire File......... .10879 Last Reading For Entire File.......... .12106 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/10/06 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/10/06 Maximum Physical Record. .65535 F i 1 e 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 RPX RPS RPM FET RPD ROP $ 5 header data for each bit run in separate files. 6 .5000 START DEPTH 12066.0 12078.5 12078.5 12078.5 12078.5 12078.5 12106.5 STOP DEPTH 12569.0 12581.0 12581.0 12581.0 12581.0 12581.0 12613.0 # 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: 17-JUL-03 Insite 4.3 Memory 12613.0 12106.0 12613.0 82.7 MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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.....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 92.1 ( TOOL NUMBER 82758 126589 3.750 10904.0 Flo Pro 8.70 65.0 8.5 19000 7.6 .100 .040 .310 .150 68.0 188.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12066 12613 12339.5 1095 12066 12613 ROP MWD060 FT/H 0.36 607.93 79.7426 1014 12106.5 12613 GR MWD060 API 22.26 128.82 42.1723 1007 12066 12569 RPX MWD060 OHMM 8.27 23.25 14.4593 1006 12078.5 12581 RPS MWD060 OHMM 9.32 24.4 16.0568 1006 12078.5 12581 RPM MWD060 OHMM 9.79 25.78 16.9074 1006 12078.5 12581 RPD MWD060 OHMM FET MWD060 HOUR 11. 7~' 0.26 26.35 16.32 17.4297 1006 ( 078.5 1.9819 1006 ~2078.5 12581 12581 First Reading For Entire File......... .12066 Last Reading For Entire File.......... .12613 File Trailer Service name............ .STSLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .03/10/06 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..... ..03/10/06 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 GR RPD RPM RPS RPX FET ROP $ 6 header data for each bit run in separate files. 7 .5000 START DEPTH 12569.5 12581.5 12581.5 12581.5 12581.5 12581.5 12613.5 # 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: # STOP DEPTH 12859.5 12872.0 12872.0 12872.0 12872.0 12872.0 12903.5 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 18-JUL-03 Insite 4.3 Memory 12904.0 12613.0 12904.0 81.9 93.8 TOOL NUMBER 82758 126589 # ( BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 3.750 10904.0 Flo Pro 8.70 65.0 8.5 19000 7.8 .080 .030 .270 .180 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD070 FT/H MWD070 API MWD070 OHMM MWD070 OHMM MWD070 OHMM MWD070 OHMM MWD070 HOUR Max 12903.5 1116.29 167.81 18.8 20.7 20.37 21.33 7.65 Min 12569.5 1.07 22.31 3.45 3.97 4.42 6.08 0.29 First Reading For Entire File......... .12569.5 Last Reading For Entire File.......... .12903.5 Mean 12736.5 110.735 38.3441 10.4037 11.8247 12.6536 13.3125 1.61794 Nsam 669 581 581 582 582 582 582 582 ( 68.0 191.0 68.0 68.0 First Reading 12569.5 12613.5 12569.5 12581.5 12581.5 12581.5 12581.5 12581.5 Last Reading 12903.5 12903.5 12859.5 12872 12872 12872 12872 12872 ( ( File Trailer Service name. ........... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .03/10/06 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/10/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .03/10/06 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 Sperry-Sun Dri( ng Services LIS Scan 0tility f ~G3'-)~) $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 06 13:08:11 2003 ) ;Z~I ) Reel Header Service name...... . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/10/06 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. . . . . . . . . . . . . . . . . . . . .03/10/06 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 W-16A PB1 500292204570 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 30-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002548805 B. JAHN SEVCIK/EGBEJ MWD RUN 2 MW0002548805 B. JAHN SEVCIK/EGBEJ # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 11N 12E 801 1183 90.48 # WELL CASING RECORD ~"""'i! X""" ~..." E "VED' "'1£' iF'"'' ¡ ~1 \lî\",,~Jj , ,,' , 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 10904.0 Orn,"" -1 (\ r:JOO·1. ....,j "/L\.J , . i""'" i""<', n..., . f-' .v"m'loceiOn .?~(.)$~.a 1Ji'¡& 'i..~b::;ï í..rom~. \",rOm .~-n ¿;\nchorage # ~~b~\~ REMARKS: ( ( 1. ALL DEPTHS ~E MEASURED DEPTH (MD) UNLESS OTh~RWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE W-16 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 10904'MD/8851'TVDSS. 4. MWD RUN 1 WAS DIRECTIONAL AND GAMMA MODULE (GM, UTILIZING GEIGER-MUELLER TUBE DETECTORS) TO SET THE WHIPSTOCK. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH GM. 6. AFTER DRILLING ONLY 691MD THE WHIPSTOCK WAS LOST DOWNHOLE. 7. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN IN W-16 ON 7/16/2003. THESE DATA WERE PROVIDED TO SSDS BY D. SCHNORR, BP EXPLORATION (ALASKA), INC., ON 9/16/03. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 & 2 REPRESENT WELL W-16A PBl WITH API#: 50-029-22045-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10994'MD/8818ITVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/06 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 $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10825.0 10926.0 STOP DEPTH 10974.5 10999.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10825.0 10829.0 GR 10825.5 10829.5 File Trailer First Reading For Entire File......... .10825 Last Reading For Entire File.......... .10999 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10825 10999 10912 349 10825 10999 ROP MWD FT/H 1.17 275 45.1778 147 10926 10999 GR MWD API 38.72 493.21 152.393 300 10825 10974.5 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Order DEPT ROP MWD GR MWD # 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 MERGED MAIN PASS. $ # REMARKS: MERGE BASE 10894.0 10994.0 MERGE TOP 10825.5 10894.5 BIT RUN NO 1 2 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ 10835.« 10846.5 10848.0 10853.0 10872.0 10876.0 10882.5 10885.0 10892.5 10897.0 10901.5 10908.5 10913.0 10918.5 10930.0 10932.5 10937.0 10940.0 10941.0 10943.5 10948.5 10954.5 10961.5 10964.0 10966.0 10994.0 10835.5 10847.5 10849.5 10853.5 10872.0 10877.0 10882.0 10885.5 10894.0 10899.5 10903.0 10910.5 10915.5 10920.0 10931.0 10934.0 10939.5 10944.0 10945.5 10948.0 10953.5 10960.0 10966.5 10969.5 10971.5 10999.0 $ service name............( )LIB.001 service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR $ 2 ( header data for each bit run in separate files. 1 .5000 START DEPTH 10825.5 STOP DEPTH 10894.0 # 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 GM Dual GR $ # 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: 10-JUL-03 Insite 4.3 Memory 10925.0 10904.0 10925.0 47.8 47.8 TOOL NUMBER 93091 3.750 10904.0 KCL Brine 8.40 .0 .0 10000 .0 .000 .000 .000 .0 155.5 .0 MUD CAKE AT MT: .000 ( # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 Name Service Unit DEPT FT GR MWD010 API Min 10825.5 38.72 Max 10894 403.79 Mean 10859.8 84.212 Nsam 138 138 First Reading 10825.5 10825.5 Last Reading 10894 10894 First Reading For Entire File......... .10825.5 Last Reading For Entire File.......... .10894 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/10/06 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/10/06 Maximum Physical Record..65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ( .5000 START DEPTH 10894.5 10925.0 STOP DEPTH 10969.0 10994.0 # 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 GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 11-JUL-03 Insite 4.3 Memory 10994.0 10925.0 10994.0 41.2 43.4 TOOL NUMBER 93091 3.750 10904.0 Flo Pro 8.60 62.0 9.0 20000 .0 .000 .000 .000 .000 .0 163.0 .0 .0 End Of LIS File Physical EOF Physical EOF Reel Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/10/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/10/06 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 First Reading For Entire File......... .10894.5 Last Reading For Entire File.......... .10994 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10894.5 10994 10944.3 200 10894.5 10994 ROP MWD020 FT/H 1.17 275 46.2728 139 10925 10994 GR MWD020 API 67.31 493.21 212.281 150 10894.5 10969 Name Service Order Units s! Nsam Rep Code Offset Channel ( DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3
