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Home My WebLink About203-219 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,August 14, 2016 8:38 AM To: AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad Z; Peru, Cale; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;Grey, Leighton;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE: Producer Z-30A(PTD#2032190)Tubing Integrity Restored All, Producer Z-30A(PTD#2032190) passed an MIT-T to 2500 psi on 08/13/16,following an orifice gas lift valve change-out. The well had previously passed a CMIT-TxIA to 2500 psi on 02/04/15.These passing tests confirm two competent well barrier envelopes.The well is reclassified as Operable. Work Completed: 1. Slickline: Change out orifice gas lift valve—Completed 08/12/16 2. Fullbore: MIT-T—Completed 08/12/16; passed to 2500 psi 3. Slickline: Pull tubing tail plug—Completed 08/13/16 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 SCANNED JAM ,�r C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator • • Sunday, March 17, 2013 9:42 PM To: AK, •;C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Con • - ; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lea., RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Longden, Kaity; 'jim.regg@alaska.gov'; 'Schw. r Guy L(DOA)'; Weiss,Troy D; AK, OPS Well Pad Z Cc: AK, D&C DHD Well Integrity En•'•-er; Holt, Ryan P; Walker, Greg (D&C) Subject: NOT OPERABLE: Producer Z-30' 'TD #2032190)TxIA Communication All, Producer Z-30A(PTD#2032190)failed a cold TIFL on 2/16/2013. A •.. and kill was pumped on 03/12/2013 and pressures were bled to less than 500 psi. The well cannot be placed on pr.: ction to perform a warm TIFL due to production constraints and is reclassified as Not Operable. Plan forward: 1. DHD: Monitor for IA repressurization 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ¡J 03 - a 1 c;¡ Well History File Identifier Organizing (done) D Two-sided ""111111111"111I RESCAN D,TAL DATA V6 Diskettes, No. I D Other, NolType: D Color Items: D Greyscale Items: D Poor Quality Originals: D Other: NOTES: Date 3/' / ()fo BY: G::J Project Proofing BY: ~ Date 3/' /Db I X 30¡=~O Date3¡1 J Ðb Scanning Preparation BY: l Maria) Production Scanning D Rescan Needed 111111111111 "" III OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: mr 1111111111111111111 mP /5/ /5/ + J 1 = TOTAL PAGES l/-q (Count does not include cover shee~/lII.. n /5/ r rtf 111111111111111111I Stage 1 Page Count from Scanned File: .50 (Count does include cover sheet) VYES BY: Page Count Matches Number in Scanning Preparation: ~- Date ð III oft, If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: YES NO /5/ V11 P NO /5/ 1111111111111111111 11I1111111111111111 /5/ Quality Checked 11/1111111111111111 10/6/2005 Well History File Cover Page.doc NOT OPERABLE: Z -29 (PTD #18906 & Z -30A (PTD #2032190) Sustainedsing Pressure ... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com) Sent: Thursday, July 14, 2011 8:05 PM { ref ( 711 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; Kirchner, Carolyn J; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, CPS Well Pad SW; AK, OPS Prod Controllers; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad Z Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Reynolds, Charles (ALASKA) Subject: NOT OPERABLE: Z -29 (PTD #1890650) & Z -30A (PTD #2032190) Sustained Casing Pressure on IA All, Producer Z -29 (PTD #1890650) was found to have sustained casing pressure above MOASP on the IA. The tubing / IA/OA = SSV/2360/460 on 07/11/2011. Producer Z -30A (PTD #2032190) was found to have sustained casing pressure above MOASP on the IA. The tubing /IA/OA = SSV/2100/180 on 07/13/2011. Both wells are currently shut in for turnaround activity and have been reclassified as Not Operable. When operations is ready to bring thee w is back online, they will be reclassified as Under Evaluation and a TIFL - will be conducted to evaluate integrity. Please let me know if you have any questions. Thank you, 4; fi*1 JUL 1 8 201' Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 7/15/2011 Producers with sustained casing pressuon IA and OA due to proration . Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] Sent: Wednesday, January 12, 2011 10:42 PM g it To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: King, Whitney; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead Subject: Producers with sustained casing pressure on IA and OA due to proration Jim /Tom /Guy, The following producers were found to have sustained casing pressure on the IA during the proration January 10 -12. The immediate action is to perform a TIFL on each of 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. 03-28 (PTD #1840720) 12 -15 (PTD #1830320) 12 -36 (PTD #1951580) TD #1921020) NE ' i/ I` f ci Z -30A (PTD #2032190) The following producers was found to have sustained casing pressure on the OA during the proration January 10 -12. 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. 03 -08 (PTD #1760730) 03 -28 (PTD #1840720) 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 1/13/2011 ~' Schlum6erger Alaska Data & Consulting Services 2525 Gambell Street, SuNe 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.5514 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD Z-30A P-16 03-01 P2-22 U 03 AWJI-00077 AYS4.00122 B9RH-00024 BBUO-00007 MEMORY GLS - PRODUCTION PROFILE _ C X-FLOW CHECK/IBP/CEMENT DUMP USIT 03/06/10 03/08/10 04/21/10 03/08/10 1 1 1 i 1 1 1 1 - BBKA-00021 X-FLOW CHECK/P UG/C MENT G/'- L 04/22/10 1 1 03-37 S-111 R-28 BBKA-00023 BSJN-00049 BCZ2.00009 STATIC PRESSURE SURVEY '- ... y INJECTION PROFILE / PRODUCTION PROFILE ~- G 04/24/10 04/19/10 04/26/10 1 1 1 1 1 1 R-04 13-23A 5-06 Z-31 1 BCZ2-00010 BBSK-00016 BBKA-00026 B3S0-00060 PRODUCTION PROFILE - INJECTION PROFILE - INJECTION PROFILE INJECTION PROFILE 04/27/1D 04/29/10 04/30/10 Od/27/10 1 1 1 1 1 1 1 1 7-22 AWJI-00085 MEM PRODUCTION PROFILE •" - 04/28/10 1 1 14-D7 04-29AL1 A•O6 AVYO-00068 BBSK-00017 BBKA-00006 PRODUCTION PROFILE USIT RST - 04/26/10 04/30/10 02/09/10 1 1 1 1 1 1 A-28 AUTO-00037 RST - - 02/16/10 1 1 17-09A 17-09AP81 10AKA0128 10AKA0128 OH MWD/L D EDIT OH MWD/LWD EDIT ~ 02/11/10 02/07!10 2 2 1 1 PI FARP ACKN(1Wt rune taer eror nv ev_r,u., n wun r,~r. ,...,,.,.. ...,~ .......- ~..,.. __. BP Exploration (Alaska)Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suile 400 Anchorage, AK 99503-2a3B 05/07!10 • ;~ -~~ '' ~:~~Y ~, _.~~ ~~11f1 l~ \J BP Exploration (A~aska) Inc. Attn: Well Iniegrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 i i ~ ~~1~~ ~~~~~~~~ ~ ~` ~` ~ August 14, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, ~ bp :_. ~~E~~~~ OCT ~ 5 2009 ~lask~ Dil F~ 6as Cons. Cor~i~R~Qr~ Anchora~e ~43 - ~. ) ~ ~~ ~~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # lnitial top of cement Vol. of cement um ed Fina1 top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-016 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227s70000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/2M2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-06 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-08A 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-O9A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 z-~ 2 1891020 soo2921 sn0ooo NA 1.2 NA 8.50 ~i2s~2oo9 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-146 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220ot0000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-t9A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-236 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 500292t8790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-3i 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-326L1 1970350 50029219246000 NA 02 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950t00 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-t08 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-112 2071720 50029233800000 NA surface NA STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~,~ ~~~~~~~ 9aa~ ~; ~~~ ~ ~ ~~~~ '-~ tJ t ~ 1. Operations Abandon ~ Repair Weil ~ Plug Perforations ~ Stimulate 0 ,,f;;~e~: f ~~; ~~_~, ~.~~;~~~9;;`,"~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~~ a~ •~ ~', r.~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well [] 2. Operator BP Expioration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~lopment ~ Exploratory ~ 203-2190 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-22013-01-00 7. KB Elevation (ft): 9. Well Name and Number: 79.57 ES _ PBU Z-30A - 8. Property Designation: 10. Field/Pool(s): ADLO-047450 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 16600 , feet Plugs (measured) None true vertical 8891.29 _ feet Junk (measured) None Effective Depth measured 16559 feet true vertical 8893.15 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 110 20" Surface - 110 SurFace - 110 SURFACE 2874 13-3/8" 68# L-80 Surface - 2874 Surface - 2674 4930 2270 PRODUCTION 13367 9-5/8" 47# NT80S Surface - 13367 SurFace - 8230 6870 4760 LINER 848 7" 26# L-80 13186 - 14034 8137 - 8689 7240 5410 LINER 2686 4-1/2" 12.6# L-80 13914 - 16600 8600 - 8891 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 25 - 13918 0 0 - Packers and SSSV (type and measured depth) 7" Top Packer 13186 4-1/2" Baker S-3 Perm Packer 13863 4-1/2" Top Packer 13914 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): " ~~ ,.. ~ ., ~~ ,~~n~ ~' ~ ~ :, ~ ,,. 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: 410 2283 680 329 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: , Copies of Logs and Surveys Run Exploratory I~ Dev+elopment ~' - SBfVIC2 ~ Daity Report of Well Operations X 76. Well Status after propased work: Oil ~_ Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl TiUe Data Management Engineer Signature Phone 564-4944 Date 8/27/2009 Form 10-404 Revised 04/2006 ~~ Submit Ori inal O ly ~..: .~ ~ ~~~ ;F:'' €;~ ~, ~~~G ~~ ~ ~ ~~~,~ Z-30A 203-219 PFRF OTTOCHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z-30A 1/28/04 SL 14,386. 16,557. 8,863.85 8,893.24 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 ~ ~ ~ • Z-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY _ A__ _ ~ ~~ _ .__ ; 8/16/2009; CTU # 9 w/ 2.00" CT, Job scope. Fish . FCO and acid wash. «<InterACT ~ ~ ;publishing »>, MIRU, MU 2.2" JSN. PT, had leak on micromotion. wait for partsl i ~ ~ ~*'''`*Job Continued on 8/17/09"*** ` i 8/17/2009~ASRC Test Unit #2, Assist CTU, "'"Job in progress*"* _~~~.~.. ~..~.____~- ~ ~ 8/17/2009 CTU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT ~ ~publishing »> Continued from 8/16/09. RIH with 2.2" JSN , Set down at 15078" ~ ~ CTM, start circulation and tapqed up on fish at 15156' CTM. Clean off top of fish ~ ~ 13.5 bpm POOH chasing bottoms up. RIH with 1.91" Hydr "G" spear and jars.. tag ; ' up , POOH,_ No fish~MU& RIH Hyd "G" with Jars and a knuckle joint above the ~ ~ ~spear. "**Job continued on 8/18/09**** ~. ._.______ ~ 8/18/2009 ~ CTU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT ! ~publishing »> Continued form 8/17/09,. RIH w Jars , knuckle Joint and 1.91 ~ i E"GS" spear. OOH no fish "G" spear came out with bent finger UD tools. Cut 50' of I ~ ;pipe for pipe management. RIH with 1.91."G" spear with a over sized guide ~ ;shoe.3.60" & diverter sub. OOH with no fish , guide had marks that gave the ~ ~ ; indication that it did not get over the fish and possibly some junk. Call for venturri. ; ~ j j"***Job Continued 8/19/09*""'* ~_ ~.___ _. _._.~~. ._ ._ __-- -- 8/18/2009 ~ CTU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT j publishing »> Continued form 8/17/09,. RIH w Jars , knuckle Joint and 1.91 ~ ' "GS" spear. OOH no fish "G" spear came out with bent finger L/D tools. Cut 50' of ~ ~ ~ pipe for pipe management. RIH with 1.91."G" spear with a over sized guide ~ ;shoe.3.60" & diverter sub. ...Job in Pro~ress F ~ 8/18/2009~ASRC Test Unit #2, Assist CTU, *"*Job in progress'""* ~~~~m~~-~~ ~m ---- __~._ _____.~_.._ ~_._ _ _ ~ __ ~ _ _ _ 8/19/2009 j CTU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT ~ ; publishing »> Continued from 8/18/09, MU & RIH 3 1/8" Venturri , Venturi on top ? ;of fish . POOH. Venturi came back w/1 cup of scale, no marks on bottom. RIH i ~w/a 3.60" tripple bushing cut-lip bellguide w/a 1.91" Gspear to 15160. Made 20 I ;~ar licks at 50k to 59k and came free. POOH to see what we have. """Continue on ~ ~WSR on 8/20/09'`*'' ~~ .~ _- --~ _ ~ ~.. .~. ~ 8/19/2009~ASRC Test Unit 2, Assist CTU, "*Job in progress**" ~ I ~ ~ ~8/20/2009~CTU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT ~ i ~;publishing »> Continued from 8/19/09, Continue POOH. OOH. Had all of ~ ~ ~fish. disco to 3.5 mill). RIH w/ 2.97 JSN. 3tarted the FCO from 15160 to 15900 ~ ~ ;taking returns through the ASRC test sep. Solids ranged from .1 to 4%. ~ ; ~""'Continue on WSR on 8/21/09"`* ! ( ~ ~ ~ : ______~__~. _.~._~ ,___ ~.. ____ 8/20/2009;ASRC Test Unit #2, Assist CTU, ''**Job in progress*"` ~_ ~._._....~._,w. ~ ~ ~ _ ~ _ ~ ~ ~ 8/21/2009 CTU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT publishing »> Continued from 8/20/09, Continue with FCO w/ 2.97 JSN Clean ~ out from 15900 to 16150. Pulling an extra 9-10k while PUH. Decision was made ~ to POOH to check tools due to the extra drag. No obvious marks on tools. ~ Perform weekly BOP Test. Conduct safety audit on coil unit. Stand by while ~ ~ ASRC replaces flow "T" on top of well that is taking returns. ***Continue on WSR on 8/22/09*"* ~ 8/21/2009 A ~ SRC Test Unit #2, Assist CTU, S/D re-rig lines, P/T lines, Continue flow, ***Job ~ ~ in progress""* m _ _._~.__ ~ 8/22/20091 _._ _ __ ................. ASRC Test Unit #2, Assist CTU, """Job in progress''"" ~~. _ ~. _~. " ; 8/22/2009 CTU # 9 w/ 2.00 CT, Job scope, Fish , FCO and acid wash. «<InterACT ~ ~ publishing »> Continued from 8/21/09. ASRC's Flow "T" Reparied. RIH w/ 2.97 JSN to 16559' CTM, encountered no resistance ulled u to 14000' above ~ slotted liner. Pump 280 bbls of 2% KCL down backside. Final pump rate 2.7bpm at 1565psi on tubing. . Pump 111 bbl's of 90:10 DAD acid. Recip across perfs ~ from 14386 to 16559. Titration = 12.5 Iron < 50ppm. ***Continue on WSR on 8/23/09*"" 8/23/2009 ASRC Test Unit #2, Assist CTU, CTU complete, Start Acid flowback, ***Job in ~ ~ progress**" ' ~~8/23/~ TU # 9 w/ 2.00" CT, Job scope, Fish , FCO and acid wash. «<InterACT publishing »> Continued from 8/22/09. PUH washing acid across perfs from ! 15029 to 14386. Park at 14380 and overdisplace 90:10 DAD acid with 102 bbl's ~ of 2%KCL w/F103. Final pump pressure was 106psi on tubing at 2.2 bpm. j ~ POOH. RDMO. Notify operator on departure. "**Job Complete*** ~ ~_- ~ - ' ' ~ 8/24/2009 ASRC Test Unit #2, Complete acid flowback pH-6, Shut in per PE, RDMO, *""Job ! ~_.~-_ complete'''' ~ ---- ~ __ FLUIDS PUMPED BBLS 159 2% KCL W/F103 325 2% KCL 111 90:10 DAD ACID 76 GEO-VIS 1891 2% XS KCL 131 1% XS KCL W/SAFELUBE 570 1 % XS KCL 3263 TOTAL I~fELL ~.QG TRAN5~1/TT~IL • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hote/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lasturflca LR2-1 900 Benson Blvd. Anchorage, Alaska 9950$ and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 7 30 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 03 2 ~9 l~Sltb 1) Leak Detection - STP 07-May-09 Z-30A 2) Signed Print Name: ~iaska Qil ~ Gas Coos. ~;ammission Anchorage PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (90712458952 E--~IaIL : pdsanchorageCa~memorvloa.com WEesITE : www.memorvlog.com C:\Documents and Settings\Owner\Desktop\Transmit_BP.docx OPERABLE: Z-30A (PTD #203~ 90) Passing MITIA • Page 1 of 2 ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj ~~~Ia~l~ Sent: Friday, May 08, 2009 2:35 PM ~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad Z; GPB, Prod Controliers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: Z-30A (PTD #2032190) Passing MITIA / All, Well Z-30A (PTD #2032190) passed a MITIA after settin dumm as lift valves. The well has been reclassified as Operable and may be returne to production once live gas lift vaives are set. .---- Thank you, Anna ~u6e, ~P. E. Well Integrity Coordinator GPB Nilells Group Phone: (907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 15, 2009 7:52 PM ,tti +, ,~,;~~.- ~, ; ` (`~ ~~ ~~.1 J :r~ , ~ ~ ~ .Y, '~'~ ~*:.,~.~ ._ To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Welipad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad Z; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Z-30A (PTD #2032190) Sustained Casing Pressure due to TxIA Communication All, Well Z-30A (PTD #2032190) has been found to have sustained casing pressure on the IA. The TIOs were 2150/2150/140 psi on 04/14/09 when a TIFL failed confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. DHD: TIFL - FAILED 2. Slickline: Change out GLVs 3. DHD: Re-TIFL A TIO plot and wellbore schematic have been attached for reference. Please call with any questions or concerns. Thank you, 7/29/2009 ~ - - OPERABLE: Z-30A (PTD #20~90) Passing MITIA • Page 2 of 2 Anna ~u6e, 2'. E. Well Integrity Coardinator GPB Wells Geoup Phone: {9Q7) 659-5102 Pager: (907} 659-514d x't 154 7/29/2009 PBU Z-30A PTD 203-219 4/15/2009 TIO Pressures 4,OUn ~ 3,000 2.C100 1.C1C10 -*- T bg -~- IA -~ OA OOA -~ OOOA ~ On ~ 01117~'Q9 01/24ln3 01131!09 02107f09 Oi114!09 02I211D3 C12i2~3l09 0310?l09 03I141C19 03J21In9 031~~I09 04JOdI0~ 04111I09 TREE = 4-1l16" FMC WELLHEA~ FMC ACTUATOR = BAKFJ2 KB. ELEV = 79.57' a~. QEV = s2.ai~ KOP = 13383' Max Angle = 94 @ 16210' Datum MD = 16600' daturn ND = 8891' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" ~ ~~~~~ GAS UFT MANDRELS iT MD ND DEV TYPE VLV ~ATCH PORT DATE 5 3254 2895 56 MMG DOME RK 16 Q9/27/07 4 7016 4910 59 MMG DOME RK 16 09/27/d7 3 9983 6502 60 MMG DOME RK 16 09/27(67 2 12405 7748 63 MMG DUME RK 16 d9l27l07 1 13776 8497 42 KBG-2 SO BK 20 09/27/07 Minimum ID = 3.725" @ 13906' 4-1/2" HES XN NIPP~E 13186' ~-~ 9-5/8" X 7" HMC ZXP GNR TOP PKR MI~LOUT WiNDOW {Z-30A) 13367' - 13383~ PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLOTTED LNR 14386 - 16557 O 01(30l04 9-518" CSG, 47#, L-80, ED = 8.681" 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" SAFEfY~ES: 4-1f2" CHROMETUBING 2226~ E-~ 4-1 /2" HES X NIP, iD = 3.813" ~-j4-1l2" HES X NIP, ID = 3.813" ~ 13$63~ 7" X 4-1l2" BKR S-3 PERM PKR, ID = 3.875" 13888' 4-1/2" HES X NIP, ID = 3.813" 13906' 4-1l2'" HES XN NIP, ID = 3.725" 13914~ 7" X 4-1/2" HMC LNR HGR ~. 13~ 918~ ~- 4-1/2" WLEG, ID = 3.958" ~ 4-1/2" TBG, 12.6", 13C R, -t 1391 S' ~ .0152 bpf, ID = 3.858" ~CSG, 26# L-8Q, ID = 6.538" ~ 4-1/2" SLTD LNR, 12.6#, L-$0, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 03/11l90 DFF ORIGINAL CbMPI.ETIdN 09(12l07 KSB/PJC GLV C/O Q2/09/Q4 TM NlKA R!G SlDEI'RACK (Z-30A) 09127/07 DAV/PJC GLV C!O 02/21/04 RWL(KR GlV C!O 10(04/04 RWUTLP GLV C(O 11/21/05 ISJPJC GLV CORRECT (#1 Cl0 1174l04) 03I30/06 DAV/PJC GLV C/4 `'. 16559~ PBTD , , . , . , . , . ~ ,~. PRUDHOE BAY UNIT WEI.~: Z-30A PERMIT No: 2032190 AF=i M1lo: 50-029-22Q13-Q1 SEC 19, T11 N, R12E, 714' FNL & 3648' FEL BP Exploration (Alaska) ~ • z :~. ~~:. ..k: { ~. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marketdoc ell Job# Log Description Date BL Color CD C-11A 11225983 LDL 07/02106 1 B-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G-18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 B-28 11221590 LDL 07/04/06 1 B-01 11211508 PROD LOG W/DEFT 06/23/06 1 W-39A 11216197 MEM PROD PROFILE OS/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02/06 1 G-03A 11211493 LDL OS/24/06 1 C-26A 11225979 LDL 06/07/06 1 F-26B N/A MEM PROD & INJECTION 06/06/06 1 F-26B N/A MEM BORAX LOG 06/06/06 1 W-39A 11216197 MEM BORAX LOG OS/29/06 1 F-04A 11221602 SCMT 08/18/06 1 Y -08A 11221604 SCMT 08/20/06 1 C-06B 11212883 US IT 08/15/06 1 X-27 11217274 USIT 08/26/06 1 K-07D 10942217 MEMORYSCMT 06/15/05 1 Y-10A 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 SBHP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15/04 1 A-30A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17-04B 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 Z-30A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04B PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Schlum_erger 6Xf3 -é)/'1 :pi (L..I(~r- . . SCANNED SEP 1 4. 2005 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth W Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 R. ',: r-,,,'-" '.~ ' , ' " \:'~.. ~ : " ,~.~~:. ,; ¡) \.,1' .",,-j- .i. 08/28/06 OJ ';;':'.) .... ",\,JIJO NO. 3941 ~fJB & Gas Cons, c~ Anchorage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Sc~lIn~e..ger RECEIVED NO. 3914 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth AUG 1 0 2006 Alaska Oil & Gas eons. eommisSlon Anchorage 1Þ I¿¡Ö/3 Field: Prudhoe Bay Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 oow éJ03 - 8-lCJ II We Job# Log Description Date BL Color CD z-3uA 4UU1U092 OH EDIT OF MWD/LWD U1/Z7/04 2 1 17-048 40010183 OH EDIT OF MWD/LWD 03109/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/09/06 . . Z-30 Classified as Normal Well, post OGLV Changeout Hello all. Z-30 has been classified as a Normal well. A TIFL passed post OGLV changeout. p-¡j) '¢J.-Zo3_ '¿.f9 Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.eom ".."_·""·,...','ì . ," t'.~!"i;';.'~ :,:b'\¡rv~~' ~ .¡ L .- '" From: MCCOllUM, CODY 0 (VECO) Sent: Saturday, April 08, 2006 8:55 PM To: NSU, ADW Well Integrity Engineer Subject: Problem Well: Z-30 TIFl - post GlV C/O - **PASSED** recommend swap to normal. Joe, The TIFL for problem well Z-30 post glv c/o has passed with 0 inflow and negligible BUR. The well can be swapped from problem to normal. Thanks, Cody I of I 4/10/20064:16 PM Z-30A (PTD #2032190) Classified as Problem Well e e r¿tr 31lc¡flk Subject: Z-30A (PTD #2032190) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWcllIntcgrityEnginecr@BP.com> Date: Mon, 27 Mar 2006 16:49:56 -0900 To: "Robertson, Daniel B (Alaska)" <Daniel.B.Robertson@BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@BP.com>, "Rossberg, R Steven" <Stcvcn.Rossberg@}BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWeIJOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWells0ptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jimJegg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupcrvisor@BP.com>, "GPB, GC2 Well pad Lead" <GPBGC2WellpadLead@BP.com> CC: "NSlJ, ADW Well Integrity Engineer" <NSUADWWeIlIntcgrityEngineer@BP.com>, "Winslow, Jack L." <Lyonsw@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com> All, Well Z-30A (PTD #2032190) has been found to have sustained casing pressure on the IA The TIO's on 03/26/06 were 2350/2320/130 when a TIFL failed. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. WIE: Eval for GLV c/o 3. SL: GL V c/o 4. DHD: Re-TIFL n h ü-~ A wellbore schematic has been included for reference. «Z-30Apdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, }fnna ()u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: Z-30Apdf Content-Type: application/octet-stream Content-Encoding: base64 ùf\ Z-37DfSí 130~\' Jv{úJ.E 6ß7Df'~ '20 M-A{ P ~3. f) '2c 2.~~ I· iJ r- f'" Cb ~'1Z. . ¿ 4s Pö ~fJ:t¿p sc.:f JA 5l:liJf5; 1 of 1 3/28/20064:47 PM TREE = WELLHEAD = ACTUATOR = KB. ELBI = BF. ELBI '" KOP= rv1ax Angle '" Datum MD '" Datum ND = 4-1/16" FMC FMC BAKER 79.57' 52.01' 1338 e 113-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" @ 13906' 4-1/2" HES XN NIPPLE ÆRFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SLOTTED LNR 14386 - 16557 0 01/30/04 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 14229' 15-1/2" LNR, 17#, L-80. .0232 bpf, ID'" 4.892" 1 Z-30A I S~TES: 4-1/2" CHROME TUBING 2226' -i4-1/2"HESXNIP,ID=3.813" I GAS LIFT MANDRELS ST MD ND DBI TYÆ VLV LATCH PORT DATE 5 3254 2895 56 MMG DOME RK 16 02/21/04 4 7016 4910 59 MMG DOME RK 16 02/21/04 3 9983 6502 60 MMG DOME RK 16 02/21/04 2 12405 7748 63 MMG DOME RK 16 02/21/04 1 13776 8497 42 KBG-2 SO BK 22 11/04/04 -19-5/8" X 7" HMC ZXP LNR TOP PKR I I MILLOUT WINDOW 13367' - 13383' -17" X 4-1/2" BKR S-3 ÆRM PKR, ID = 3.875" -14-1/2" HES X NIP, 10'" 3.813" I --j4-1/2" HES XN NIP, ID'" 3.725" I -i 7" X 4-1/2" HMC LNR HGR I 14-1/2" WLEG, ID '" 3.958" I 4-1/2" TBG, 12.6", 13-CR, .0152 bpf, ID = 3.958" IT' CSG, 26# L-80, ID'" 6.538" I 14-1/2" SL TO LNR, 12.6#, L-80, 10'" 3.958" H 16600' DA TE RBI BY COMMENTS OA TE RBI BY 03/11/90 DFF ORIGINAL COMPLETION 02/01/04 TM N/KA RIG SIDETRACK (Z-30A) 02/21/04 RWLlKAK GLV C/O 10/04/04 RWUfLP GL V C/O 11/21/05 IS/PJC GLV CORRECT (#'1 C/O 11/4/04) COMMENTS , , '< 7559' 1--1 PBTD I ""1' ~ PRUDHOE BA Y UNrf WELL: Z-30A ÆRMrf No: "2032190 API No: 50-029-22013-01 SEC 19, T11N, R12E, 714' FNL & 3648' FEL BP Exploration (Alaska) IM~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2032190 Well Name/No. PRUDHOE BAY UNIT Z-30A Operator BP EXPLORATION (ALASKA) INC ì í ~ J Cv-..- Â-~~ (I )f 1.[. ¿ API No. 50-029-22013-01-00 MD 16600 ~. TVD 8891-" Completion Date 2/1/2004~ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No o;'edlo",' So"",y e ". DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, GR, RES, PWD (data taken from Logs Portion of Master Well Data Maint Log/ Data Type i~ Electr Digital Dataset Med/Frmt Number . Name Log Log Scale Media Run No Interval OH / Start Stop CH Received Comments 1/ i'~ED D I·~ ~. Directional Survey Directional Survey 13341 16600 13341 16600 3/12/2004 3/12/2004 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? f® Chips Received? -~ Daily History Received? Œ/N a>N . Formation Tops Analysis Received? '-vT"N Comments: tv.'(j > M r <.c...'-,.. ì1 \r-. (~ \:J t ~ Ii { So ~. V\!\.Qlll ~_ ~\A~ rð I{ VlACV- Compliance Reviewed By: ____~ A 1/\ ~ v-t~, r::û.rW\.'-..V' J~) ~)? C û ",.......... f) v~ I ì h t ).j,-..j/i¡ -{.. t/J'l£l ,Ie ¿- lli Date: ~ Fit At~ (¡¿ Z-30A (PTD #2032190) Classified as Problem Well Subject: Z-3()/\ (PT[)#2.63:A) Classified as Prohlcm Wcll .~f1i IDI'Z.{04--" From: "NSlJ, AD\-V Wcll Integrity Engineer" <l\SL;\DW\Vc1llntcgrityEnginccr(~i.)3P.com> D~ltc: Thu, 30 Scp 2004 18:56:21 -08()() To: "Robertson, Daniel A (Hollston)" <DanicI.Roberlson@BP.com>, "GPB, Fld TL" <GPßFldTL@BP.com>·, "Rossherg, R Steven" <RossbeRS@.BP.com>, "NSU. ADW Well Operations Supervisor" <.:\Sl}ADWWellOperationsSupervisor@)ßP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng(Z(BP.com>, "AOGCC Jim Rcgg (E-mail)" ·<jim__rcgg@admin.state.ak.Lls>, "AOGCC Winton AubcI1 (E-mail)" <winton "aLlberl(~i~admin.state.ak.Lls>, "NSLJ, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "Johnson, Larry 0" <JohnsoLO@BP.com>, "Boss, Gcorgc W" <Gcorgc.W.ßoss@BP.com>, "OPB, Wcll Pads LVZ" <GPB W ellPadsL VZ@~BP .com> CC: "NSLJ, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Mielkc, Rohcrt L." <robcrLmielke(@BP.com> All, Well Z-30A (PTD #2032190) has been found to have sustained casing pressure on the IA. The surface pressures were T/I/O = 2000/2000/220 on 8/20/04. Sustained casing pressure could not be immediately confirmed because of the GC-2 shutdown that prevented bleeding gas down the flowline. Bleeding gas to tanks was not an option due to associated hot work in the area. The well is a gas lifted producer and was brought on line on 9/12/04. By producing the well, the casing pressure reduced to 1500 psi. A TIFL failed on 9/28//04 confirming sustained casing pressure. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: GLV c/o 3. DHD: Re-TIFL A wellbore schematic has been included for reference. «Z-30A.pdf» The well has been classified as a Problem well and may continue to be produced while diagnostic work continues. Please call if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 Content-Description: Z-30A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 10/12/20047:47 AM 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 14229' J-----.a -- / 15-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" H 14967' 1 . TREE = WELLHEAD = A crUA TOR = KB. ELEV = BF. ELEV = KOP= ïíl1ax A nQîé = Datum MD = DatumTVD= 4-1/16" FMC FMC BA KER 79.57' 52.01' 13383' 94 @ 16210' . 16600' 8891' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" H 2875' r--J IMinimum ID = 3.725" @ 13906" 4-112" HES XN NIPPLE PERFORATION SUIllMARY REF LOG: ANGLEA TTOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF IN1£RVA L Opn/Sqz ()/.\ 1£ SLOTTED LNR 14386 - 16557 0 01/30/04 ()/.\ lE REV BY COMrÆNlS 03/11/90 DFF ORIGINAL COMPLETION 02101/04 TMN/KAM RIG SIDETRACK (Z-30A) 02121/04 RWl./KA t< GLV C/O . Z-30A SAÆTYNOTES: 4-1/2" CHROME TUBING. 2226' 1-14-1/2" HES X NIp, ID = 3.813" 1 L! ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LA TCH PORT DAlE 5 3254 2895 56 MM3 DOrÆ RK 16 02/21/04 4 7016 4910 59 MM3 DOrÆ RK 16 02/21/04 3 9983 6502 60 MM3 DOrÆ RK 16 02/21/04 2 12405 7748 63 MM3 DOrÆ RK 16 02/21/04 1 13776 8497 42 KBG-2 SO BK 22 02/21/04 5<: :8: ~ 13186' H 9-5/8" X 7" HM:: ZXP LNR TOP f'KR I I MILLOvr IMNDOW 13367' - 13383' I 13843' -4-1/2"HESXNP, ID=3.813" 1 13863' H7" X4-1/2" BKRS-3 ÆRM PKR, ID = 3.875" 13886' H4-1/2" HES X NP, ID= 3.813" 1 13906' 1-14-1/2" HESXN NIP, ID = 3.725" I 13914' H7"X4-1/2"HMCLNRH<\NGER 1 13918' W4-1/2"WLEG, ID= 3.958" I I ~ \ , 1 16559' I-J PBlD I , , , , , , 14-1/2" TBG, 12.6", 13-CR, H 13918' 1 .0152 bpf, ID = 3.958" I 17" CSG, 26# L-80, D = 6.538" H 14034' I 14-1/2" SL TDLNR, 12.6#, L-80, ID= 3.958" H 16600' I DATE REV BY OOMrÆNTS PRlJDHOEBAY ll-Irr I.'IIELL: Z-30A PERMT No: 2032190 API No: 50-029-22013-01 stC 19, T11 N, R12E, 714' FNL & 3648' FEL BP Exploration (Alaska) . STATEOFALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 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: 714' SNL, 1323' EWL, SEC. 19, T11N, R12E, UM Top of Productive Horizon: 4202' NSL, 345' EWL, SEC. 07, T11N, R12E, UM Total Depth: ~ø<i> e.rt-J 2951' NSL...-r EWL, SEC. 07, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599043 y- 5959360 Zone- ASP4 TPI: x- 597933 y- 5969542 Zone- ASP4 Total Depth: x- 599642 y- 5968314 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, RES, PWD 22. One Other 5. Date Comp., Susp., or Aband. 2/1/2004 6. Date Spudded 1/19/2004 7. Date T.D. Reached 1/27/2004 8. KB Elevation (ft): 79.57' 9. Plug Back Depth (MD+ rvD) 16600 + 8891 10. Total Depth (MD+rvD) 16600 + 8891 11. Depth where SSSV set (Nipple) 2226' MD 19. Water depth, if offshore NIA MSL CASING SIZE 30" 13-3/8" 9-5/8" CASING, LINER AND CEMENTING RECORD SETtiNG DEPTHMb S.ETtING DEF'THT\ID IOÞ BOTTOM 'lOP BOTtOIlA Surface 110' Surface 110' Surface 2874' Surface 2674' Surface 13367' Surface 8230 13186' 14034' 8137' 8689' 13914' 16600' 8600' 8891 PER FT. 68# 47# 26# 12.6# L-80 NT80-S L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + rvD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-112" Slotted Section MD rvD MD rvD 14386' - 16557' 8864' - 8893' 26. Date First Production: February 23, 2004 Date of Test Hours Tested PRODUCTION FOR 3/18/2004 4 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ........ Press. 309 1,480 24-HoUR RATE""'" 17-1/2" 12-1/4" 8-1/2" 6-1/8" 24. SIZE 4-1/2", 12.6#,13Cr80 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-219 13. API Number 50- 029-22013-01-00 14. Well Name and Number: PBU Z-30A 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 047450 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 4009 cu ft Permafrost 3209 cu ft Class 'G' 219 cu ft Class 'G' Uncemented Slotted Liner DEPTH SET (MD) 13918' PACKER SET (MD) 13863' , ACID, FRAþ"l"VRE,pÊMENT SaUEEZE,Êrd. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2264' Freeze Protect with 156 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BsL 395 OIL-BsL 2,369 27. GAs-McF 756 GAs-McF 4,534 WATER-BsL -0- W A TER-BsL -0- CHOKE SIZE I GAS-OIL RATIO 1760 1,913 OIL GRAVITY-API (CORR) 25.1 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). No:Obm;t¡;;~Jf:~lnone. state "none", I- t V~al t 1 ~,~,,_'., ~ :-t....)'(~\..;,4 Form 10-407 Revised 12/2003 u¡ AL t lJ ¡ ¡ ki'\f'R'2. "2.2.0D4- ~Wt 2 'l\)~Î~ CONTINUED ON REVERSE SIDE RØ)MS Bt-l ~ rv G 28. GEOLOGIC MARKERS. 29. ~ .JRMATION 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". Sag River 14024' 8681' None Shublik 14076' 8718' Eileen 14306' 8840' Sadlerochit I Zone 4B 14408' 8869' tI~,\lþ í l..i)O It 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ÇþV1iR. ~~ Title Technical Assistant PBU Z-30A 203-219 Well Number Permit No. I Approval No. INSTRUCTIONS Date D3-19..tf{ Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: Nei/ Magee, 564-5119 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 12/2003 o~tG\~,L~L Legal Name: Z-30A Common Name: Z-30A Test Date Test Type -.----..........--..,..-- 1/18/2004 FIT 1/24/2004 FIT 1-·----····----···-···········- TestDepth (TMD) 13,367.0 (ft) 14,034.0 (ft) BP Leak-Off Test Summary TestDepth (TVD) 8,240.0 (ft) 8,689.0 (ft) AMW 11.50 (ppg) 8.70 (ppg) Surface Pressure 645 (psi) 1,046 (psi) Leak Off Pressure (BHP) 5,568 (psi) 4,973 (psi) Page 1 of 1 -.-........-- EMW 13.01 (ppg) 11.02 (ppg) . . Printed: 212/2004 2:21 :52 PM .. Page 10f11 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Z -30A Z -30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES From - To I Hours Task Start: Rig Release: Rig Number: Phase I Code P NPT 1/12/2004 00:00 - 03:00 3.00 MOB 03:00 - 06:00 3.00 MOB 06:00 - 07:00 1.00 MOB 07:00 - 15:00 8.00 MOB 15:00 - 18:00 3.00 MOB 18:00 - 19:00 1.00 MOB 19:00 - 20:00 1.00 MOB 20:00 - 21 :00 1.00 RIGU 21 :00 - 00:00 3.00 RIGU PRE PRE P PRE P PRE P PRE P PRE P P PRE PRE P PRE P 1/13/2004 00:00 - 00:30 0.50 RIGU P 00:30 - 01 :30 1.00 RIGU P 01 :30 - 03:00 1.50 RIGU P 03:00 - 05:30 2.50 KILL P PRE PRE PRE DECOMP 05:30 - 07:00 1.50 CLEAN P DECOMP 07:00 - 08:00 1.00 PULL P DECOMP 08:00 - 08:30 0.50 WHSUR P DECOMP 08:30 - 10:00 1.50 WHSUR P DECOMP 10:00 - 11 :30 1.50 WHSUR P DECOMP 11 :30 - 16:00 4.50 BOPSUR P DECOMP 16:00 - 16:30 0.50 BOPSURP DECOMP 16:30 - 22:00 5.50 BOPSURP DECOMP 1/12/2004 2/112004 Spud Date: 1/15/2004 End: 2/112004 Description of Operations Held PJSM. RID, Prepped and Moved Rig Shop and Satellite Camp to Z Pad. Held PJSM. Broke Apart Rig Modules. Backed Pit Module Away From Sub. RID and Backed Sub Base Away from S-118. P I U and Loaded Rig Mats. Prepared to Move Rig. Held PJSM wI Security, Truck Drivers and Drilling Crew. Moved Rig from S-118 to Z-30A. Moved Rig onto Mats, Spotted Spools and Equipment in Cellar. Spotted and Leveled Rig Over Z-30A. Bermed Rig. Spotted Pit Module and Leveled Same. R I U Lines from Pit Module to Sub Base. Prepared to Take on Seawater. Spotted Slop Tank. Began Taking on 140 deg 8.5 ppg Seawater. Accepted Rig at 2000 hrs 1 112 I 2004. Continued to Take on 140 deg Seawater. R I U on Tree to Pump Down Tubing and Take Returns Off of Annulus Through Choke. Held Pre-Spud Meeting wI Drilling Crew, Tour Pusher and Drilling Supervisor. Held PJSM. R I U DSM Lubricator, Pulled BPV, RID DSM Lubricator. Tubing and Annulus on Vacuum. Weighted Up 140 deg Seawater to 8.6 ppg. Tested Lines to 3,500 psi, OK. Pumped Down Tubing and Took Returns Up Annulus Through Choke to Displace Wellbore to 140 deg 8.6 ppg Seawater. Staged Up Pump Rate as Follows: 3 bpm, 70 psi, Gained Returns w/10 bbls Pumped, 4 bpm 150 psi, 6 bpm 400 psi, 8 bpm 735 psi, 10 bpm 1,200 psi. Steady Pump Rate 10 bpm 1,200 psi. Total Wellbore Volume = 949 bbls. Total Volume Pumped To Displace Wellbore to Clean Fluid = 1,100 bbls. Closed Circulating System Back to Pits. Circulated and Conditioned Brine to 8.6 ppg In 18.6 ppg Out. Pump Rate 10 bpm 1,200 psi. Monitored Well, Wellbore Losses 23.5 bph. SetTWC. Held PJSM. N I D Tree and Removed from Cellar fl NORM Inspection. Bled Down, Terminated and Plugged off Control Lines. Removed Adapter Flange and Inspected Tubing Hanger. Held PJSM. N I U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram wI 3-1/2" x 6" Variable Rams, Blind Rams, Mud Cross, Lower Pipe Rams wI 3-1/2" x 6" Variable Rams, Spacer Spool, Kill and Choke Lines. R I U Test Equipment to Test BOPE. M I U Test Joint and RIH wI Same. Opened Annulus Valve. Filled BOP Stack. Held PJSM. Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves to 3,500 psi High I 250 psi Low. Tested Annular Preventer to 3,500 psi High 1250 psi Low. All Tests Held fl 5 Min wI No Leaks or Pressure Loss. BOPE Test Witnessed by AOGCC Rep John Spaulding. Note: IBOP would not Test. Printed: 2/2/2004 2:21 :59 PM j. .... . BP Operations Summary Report DECOMP Blew Down All Lines, Closed Annular Valve, LID Test Joint. R I D BOPE Test Equipment. DECOMP Brought to Rig Floor and R I U 4-1/2" Tubing Handling Equipment. DECOMP Held PJSM. Set 7" Lubricator Extension wI 7" Otis Connection in Annular, Closed Bag. M I U DSM Lubricator to 7" Otis Connection. Pulled TWC, Well On Vacuum. RID DSM Lubricator and 7" Lubricator Extension. Steamed Inside of IBOP Valve. Valve was Frozen R I U and Retested IBOP to 3,500 psi High I 250 Low. Tests were Held fl 5 Min wI No Leaks or Pressure Loss. Held PJSM. M I U Spear wI 3.958" Double Grapples to 5" DP. RIH wI Spear and Engaged 4-1/2" Tubing. BOLDS, Pulled on Tubing to 125,000#, Tubing Hanger Moved Off Seat at 125,000#. Observed Tubing Movement at 135,000#, Pulled Tubing Hanger to Rig Floor, String Weight Up 140,000#. Broke Out and LID Spear. Terminated Control Lines in Tubing Hanger. Broke Out and LID Tubing Hanger. R I U Circulating Head and Line. Circulated Bottoms Up, Pump Rate 10 bpm, 1,150 psi. Losses While Circulating 35 bph. R I U CAMCO Spooling Equipment. POOH and LID 4-1/2" 12.6# L-80 TDS Tubing. Spooled Up Dual Encapsulated Control Line. LID 52 Joints of 4-1/2" Tubing. Broke Out and LID SSSV Assembly. RID CAMCO Spooling Unit. Recovered 28 Control Line Clamps and 2 SS Bands. POOH LID 4-1/2" 12.6# L-80 TDS Tubing. Held PJSM. POOH LID 4-1/2" Tubing, Recovered the Following: 343 Jts 4-1/2" 12.6# L-80 TDS Tubing - 1 SSSV Assembly wI Control Line - 28 Control Line Clamps, 2 SS Bands - 5 GLM Assemblies - Cut Joint = 30.04'. Average Losses While POOH 15 bph. Note: NORM Report of Downhole Equipment: 1 - 2 Rem I hr. RID 4-1/2" Tubing Handling Equipment. Cleared and Cleaned Rig Floor. Held PJSM. Slipped and Cut Drilling Line. Serviced Rig. M I U Retrieving Tool, Ran and Set Wear Bushing. Held PJSM. Loaded 5" DP, 5" HWDP and 6-1/4" DC into Pipe Shed and Tallied Same. Held PJSM. M I U Mill I Clean Out BHA: Starting Mill - Lower Mill- Upper MiII- Bumper Sub - Oil Jars - XO - 9 x 6-1/4" DC- XO - 21 Jts 5" HWDP. BHA Total Length: 942.63' RIH wI Clean Out BHA on 5" DP. PI U 5" DP 1 x 1 from Pipe Shed. Held PJSM. RIH wI Clean Out BHA on 5" DP to 13,826', DPM. PI U 5" DP 1 x 1 from Pipe Shed. Tagged 4-1/2" Tubing Stub at 13,826'. M I U Top Drive and Circulated to Clean Well bore. Pump Rate 7 bpm, 1,300 psi. Losses While Circulating 15 bph. Established Parameters: String Weight Up 275,000#, String Weight Down 160,000#, String Weight Rotating 210,000#, RPM 60, Torque Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To Z -30A Z -30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES I I Hours I Task Code NPT ¡Phase 1/13/2004 1.00 BOPSURP 22:00 - 23:00 23:00 - 00:00 1.00 PULL P 1/14/2004 00:00 - 01 :30 1.50 PULL P 01 :30 - 02:30 1.00 BOPSURP DECOMP 02:30 - 03:00 0.50 PULL P DECOMP 03:00 - 03:30 0.50 PULL P DECOMP 03:30 - 04:30 1.00 PULL P DECOMP 04:30 - 06:30 2.00 PULL P DECOMP 06:30 - 10:00 3.50 PULL P DECOMP 10:00 - 11 :00 1.00 PULL P DECOMP 11 :00 - 00:00 13.00 PULL P DECOMP 1/15/2004 00:00 - 02:30 2.50 PULL P DECOMP 02:30 - 04:00 1.50 PULL P DECOMP 04:00 - 05:00 1.00 CLEAN P DECOMP 05:00 - 05:30 0.50 CLEAN P DECOMP 05:30 - 06:00 0.50 WHSUR P DECOMP 06:00 - 10:00 4.00 CLEAN P DECOMP 10:00 - 12:00 2.00 CLEAN P DECOMP 12:00 - 00:00 12.00 CLEAN P DECOMP 1/16/2004 00:00 - 11 :00 11.00 CLEAN P DECOMP 11 :00 - 13:30 2.50 CLEAN P DECOMP Page 2 of 11 Start: 1/12/2004 Rig Release: 2/112004 Rig Number: Spud Date: 1/15/2004 End: 2/112004 Description of Operations Printed: 2/2/2004 2:21 :59 PM ..... . Page 3 of 11 BP Operations Summary Report Legal Well Name: Z-30A Common Well Name: Z-30A Event Name: REENTER+COMPLETE Start: 1/12/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/112004 Rig Name: NABORS 7ES Rig Number: Date I From - To Hours Task i Code NPT ¡ Phase 14,000 ft Ilbs. Blew Down Top Drive, Monitored Well, Fluid Level Falling in Wellbore. POOH wI 5" DP to 900'. Calculated Fill = 91 bbls, Actual Fill = 175 bbls. Losses = 84 bbls. POOH wI BHA. Stood HWDP and Drill Collars in Derrick. Broke Out and LID Mills, Jars and Bumper Sub. Held PJSM wI Drilling Crew, Schlumberger Crew, Tour Pusher and Drilling Supervisor. R I U Schlumberger Sheaves and E-Line Equipment. Brought Logging Tool to Rig Floor: Gamma Ray I CCL - Junk Basket I 8.5" Gauge Ring. Held PJSM. RIH wI Schlumberger's Logging Tool: Gamma Ray I Collar Locator - Junk Basket wI 8.5" Gauge Ring. Stacked Out at 12,300'. Made Several Attempts to Work Past 12,300'. Last Attempts to Work Through Stacked Out at 12,300' Took 1,500# Overpull to Free Tools. Note: Circulated Over Hole During Operation, Losses 10 bph. Logged Up from 12,300' to 11,200 for Partial Correlation Tie-In Log. Note: Circulated Over Hole During Operation, Losses 10 bph. POOH wI Tools to Surface. Note: Circulated Over Hole During Operation, Losses 10 bph. Washed Down Tools, Emptied Junk Basket. Recovered 1/4 Gallon Scale and Paraffin. Changed Out 8.5" Gauge Ring to 8.0" Gauge Ring. Changed Out to Larger Head wI Stronger Weak Point of 4,800# - 5,400#. Checked Tools, OK. Note: Circulated Over Hole During Operation, Losses 10 bph. DECOMP RIH wI Gamma Ray I Collar Locator - Junk Basket wI 8.0" Gauge Ring to 13,850'. Note: Circulated Over Hole During Operation, Losses 10 bph. DECOMP Tagged Up on Tubing Stub at 13,850', WLM. Logged Up from 13,850' to 11,800', Correlated and Tied into Halliburton Open Hole Dual Spaced Neutron Log, 03-March-1990. Winch Chain on Schlumberger Truck Parted. Note: Circulated Over Hole During Operation, Losses 10 bph. SFAL DECOMP Held PJSM. Installed Primary T-Bar Clamp on E-Line and Slacked Off on Rig Blocks. Installed Secondary T-Bar Clamp on E-Line. Schlumberger's Mechanics Arrived on Location, Repaired Winch on Truck. Removed Secondary T-Bar Clamp from E-Line. Raised Rig Blocks and Elevator to Original Position. Removed Primary T-Bar Clamp. Note: Circulated Over Hole During Operation, Losses 10 bph. POOH wI Logging Tools on E-Line. Note: Circulated Over Hole During Operation, Losses 10 bph. Broke Out and LID Junk Basket and Gauge Ring. Note: Circulated Over Hole During Operation, Losses 10 bph. Held PJSM. M I U HES 9-5/8" EZSV Bridge Plug to Schlumberger Running and Setting Tool wI Gamma Ray - eeL. Note: Circulated Over Hole During Operation, Losses 10 bph. DECOMP RIH wI 9-5/8" EZSV on Schlumberger E-Line to 13,500'. Relogged Interval to Confirm Correlation. Set On Depth, CCL at 13,403.8' I CCL to Top of EZSV Stand Off 12.2' - Top of -..-.-.---....-.-..---.---- 1/16/2004 11 :00 - 13:30 2.50 CLEAN P DECOMP 13:30 - 20:30 7.00 CLEAN P DECOMP 20:30 - 21 :30 1.00 CLEAN P DECOMP 21 :30 - 22:30 1.00 CLEAN P DECaMP 22:30 - 23:00 0.50 PXA P DECOMP 23:00 - 00:00 1.00 PXA P DECOMP 1/17/2004 00:00 - 01 :30 1.50 PXA P DECOMP 01 :30 - 02:00 0.50 PXA P DECaMP 02:00 - 03:30 1.50 PXA P DECOMP 03:30 - 04:30 1.00 PXA P DECOMP 04:30 - 06:00 1.50 PXA P 06:00 - 06:30 0.50 PXA P 06:30 - 11 :30 5.00 PXA N 11 :30 - 13:00 1.50 PXA P DECaMP 13:00 - 13:30 0.50 PXA P DECOMP 13:30 - 14:30 1.00 PXA P DECOMP 14:30 - 16:00 1.50 PXA P Spud Date: 1/15/2004 End: 2/112004 Description of Operations -. ¥--...¥...--...._.~ .." --...--.-.----- Printed: 2/2/2004 2:21 :59 PM . . Page 4 of 11 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-30A Z-30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Date i i From - To Hours i Task 'Code NPT Phase i 1/17/2004 14:30 - 16:00 DECOMP 1.50 PXA P 16:00 - 17:00 17:00 - 18:00 18:00 - 19:00 DECOMP DECOMP DECOMP 1.00 PXA P 1.00 PXA P 1.00 PXA P 19:00 - 20:30 1.50 WHSUR P DECOMP 20:30 - 21 :00 0.50 STWHIP P WEXIT 21 :00 - 00:00 3.00 STWHIP P WEXIT 1/18/2004 7.50 STWHIP P WEXIT 00:00 - 07:30 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 10:00 1.50 STWHIP P WEXIT 10:00 - 16:00 6.00 STWHIP P WEXIT Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/112004 1/12/2004 2/112004 Description of Operations EZSVat 13,416'. Set HES 9-5/8" EZSV Bridge Plug at 13,416'. Pulled Up Hole to 13,350', RIH and Set Down on EZSVat 13,416' to Confirm Setting Depth. Note: Circulated Over Hole During Operation, Losses 10 bph. Losses Stopped After Setting EZSV. POOH wI Running and Setting Tool on E-Line. RID Schlumberger's Sheaves and E-Line Equipment. Held PJSM. Closed Blind Rams, Pressure Tested 9-5/8" EZSV Plug and 9-5/8" Casing to 3,500 psi fl 30 minutes, OK. Calculated Strokes to Pressure Up to 3,500 psi, 166 - 11.50 bbls, Actual Strokes 185 - 12.75 bbls. Bled off Pressure, Opened Blind Rams. Blew Down Lines. Held PJSM. M I U Retrieving Tool, Latched and Pulled Wear Bushing. M I U Packoff Tool to 5" DP. RIH Through BOP Stack Set into and Engaged 9-5/8" Packoff, BOLDS. Pulled Up On DP to 25,000#, Packoff Came Free. Pulled Packoff to Floor. Broke Out Old Packoff, M I U New 9-5/8" Packoff onto Running Tool. RIH and Set Packoff in Wellhead. RILDS. Tested 9-5/8" Packoff to 5,000 psi f/1 0 Minutes, OK. Ran and Set Wear Bushing. Note: Bleed Trailer was Connected and Open to 13-3/8" x 9-518" OA During the Entire Operation wI 0 psi. Held PJSM wI Drilling Crew, Baker Rep, Anadrill Crew, Tool Pusher and Drilling Supervisor. M I U Whipstock I Milling BHA: Bottom Trip Anchor - Whipstock Slide - 8" Starter Mill - 8" Lower Mill - 8.51" Upper Mill - 1 Jt 5" HWDP - XO - Float Sub - MWD - XO - UBHO Sub - XO - 9 x 6-1/4" DC - XO - 21 Jts 5" HWDP. Total BHA Length: 1,021.67' . Held PJSM. RIH wI Whipstock BHA on 5" DP to 13,283'. Tripping Speed 1-1/2 - 2 Minutes I Stand. Filled Pipe Every 30 Stands. M I U Top Drive, Engaged Pumps, Established Parameters: Pump Rate 500 gpm, 2,100 psi, String Weight Up 215,000#, String Weight Down 153,000#. Oriented Whipstock 52 deg Left and RIH very slowly, Tagged Up at 13,391' Drill Pipe Measurement. Set Down wI 25,000# and Set Whipstock Trip Anchor. Picked Up wI 10,000# Overpull to Confirm Anchor Set. Slacked Off and Stacked Out wI 40,000# and Sheared off of Whipstock. Pulled up and Confirmed Whipstock was Set and Sheared. Held PJSM. Displaced Wellbore to 11.6 ppg LSND Milling Fluid. Pump Rate 575 gpm, 2,450 psi. Circulated Mud System 1 Full Circulation, 11.6 ppg - In, 11.6 ppg - Out. Addition of EP Mudlube to System While Displacing and Milling, 0.5% by Volume. Milled Window from 13,367' to 13,383'. WOM 10,000#- 20,000#, RPM 70 - 100, Torque Off Bottom 10,000 ft Ilbs, Torque On Bottom 13,000 - 15,000 ft Ilbs, Pump Rate 500 gpm, 2,125 psi. Pumped 30 bbl Hi-Vis Sweeps wI Super Sweep Material Every 2-1/2 Hours. String Weight Up 215,000#, String Weight Down 153,000#, String Weight Rotating 185,000#. Printed: 2/212004 2:21 :59 PM ~ - BP Operations Summary Report Page 5 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-30A Z -30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES I I ! From - To . Hours Task' Code NPT Start: Rig Release: Rig Number: Phase 1/12/2004 2/112004 Spud Date: 1/15/2004 End: 2/112004 Date Description of Operations 1/18/2004 10:00 - 16:00 6.00 STWHIP P 13:00 - 14:00 1.00 DRILL P WEXIT Note: Top of Window 13,367' I Bottom of Window 13,383'. Drilled New Hole to 13,399'. WEXIT Pumped and Circulated Around 30 bbl Hi-Vis Sweep wI Super Sweep Material. Pump Rate 500 gpm, 2,150 psi. Circulated until Returns Over Shakers were Clean. Note: Recovered 170# of Metal Cuttings. WEXIT Held PJSM. Pulled Back in Window, Closed Pipe Rams and Performed FIT. Strokes Pmp'd Pressure 3 55 psi 6 103 psi 9 158 psi 12 217 psi 15 274 psi 18 353 psi 21 393 psi 24 461 psi 27 520 psi 30 582 psi ~ M1~ 34 645 psi MW 11.5 ppg, WindowTVD 8,240', Pressure 645 psi = 13.00 ppg EMW. Held Pressure f/10 minutes, Pressure Leaked Off from 620 psi to 604 psi in 5 minutes. Pressure at 10 minutes 593 psi. Bled down Pressure, Opened Pipe Rams. Flow Checked Well, Well Static. Pumped Dry Job, Blew Down Lines. POOH wI 5" DP. Calculated Fill 91 bbls, Actual Fill 93.5 bbls. Held PJSM. Broke Out and LID 6-1/4" DC, UBHO Sub, MWD, Float Sub, and Mills. All Mills Were In Gauge. Cleared Rig Floor of BHA Components. Cleaned Rig Floor. M I U Retrieving Tool, Latched and Retrieved Wear Bushing. L I D Retrieving Tool. M I U BOP Stack Washer, Washed and Flushed BOP Stack. LID BOP Stack Washer. M I U Running Tool, Ran and Set Wear Bushing. LID Running Tool. WEXIT Held PJSM. M I U 8-1/2" Directional BHA: 8-1/2" DS70 PDC Bit Ser#200346 dressed w/6 x 14 Jets - 6-3/4" 7.0 Stg 4/5 Lobe XP Mud Motor w/1.5 deg Bend - 8-1/2" Stabilizer - CDR Assembly - MWD Assembly - 8-1/2" Stabilizer - 3 x 6-3/4" Flex Collars - XO - 1 Jt 5" HWDP - Jars - 22 Jts 5" HWDP. Total BHA Length: 903.88'. Oriented Motor to MWD. Pulsed Tested MWD, OK. WEXIT RIH wI 8-1/2" Directional BHA on 5" DP to 13,351'. Calculated Displacement = 88 bbls, Actual Displacement 87 bbls. WEXIT M I U Top Drive, Established Parameters: String Weight Up 210,000#, String Weight Down 155,000#, String Weight Rotating 175,000#, RPM 60, Torque 10,000 ft Ilbs Pump Rate 500 gpm, 2,250 psi, ECD 12.6 ppg. Oriented Tools 60 deg Left, Shut Down Pumps, RIH Through Window. Re-Engaged Pumps, Washed Down as Precaution from 13,385' to 13,399'. Pump Rate 500 gpm, 2,250 psi. INT1 Drilled 8-1/2" Directional Hole by Rotating and Sliding from 13,399' to 13,600'. WOB Sliding 8,000# - 10,000#, WOB 16:00 - 17:30 1.50 STWHIP P 17:30 - 18:00 0.50 EVAL P 18:00 - 18:30 0.50 STWHIP P WEXIT 18:30 - 00:00 5.50 STWHIP P WEXIT 1/19/2004 00:00 - 02:30 2.50 STWHIP P WEXIT 02:30 - 03:30 1.00 STWHIP P WEXIT 03:30 - 05:00 1.50 BOPSUR P WEXIT 05:00 - 07:00 2.00 DRILL P 07:00 - 13:00 6.00 DRILL P 14:00 - 00:00 10.00 DRILL P Printed: 2/212004 2:21 :59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/19/2004 1/20/2004 1/21/2004 . . Page 6 of 11 BP Operations Summary Report Z -30A Z -30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES From - To ! Hours Task Code NPT 14:00 - 00:00 00:00 - 03:30 03:30 - 04:30 04:30 - 05:15 05:15 - 09:15 09:15 - 10:45 10:45 - 14:00 14:00 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30-21:00 21 :00 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 07:30 07:30 - 10:00 10:00 - 10:30 10:30 - 11 :00 10.00 DRILL P 3.50 DRILL P 1.00 DRILL P 0.75 DRILL P 4.00 DRILL P 1.50 DRILL P 3.25 DRILL P 2.00 DRILL P 0.50 DRILL P 1.00 DRILL P 1.00 DRILL P 2.50 DRILL P 3.00 DRILL P 3.50 DRILL P 2.50 DRILL P 1.50 CASE P 2.50 CASE P 0.50 CASE P 0.50 CASE P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Start: 1/12/2004 Rig Release: 2/112004 Rig Number: Spud Date: 1/15/2004 End: 2/112004 Phase Description of Operations Rotating 10,000#, RPM 60, Motor RPM 280, Torque Off Bottom 10,000 ft Ilbs - On Bottom 11,000 ft Ilbs, Pump Rate 560 gpm, SPP Off Bottom 2,700 psi, On Bottom 2,900 psi. String Weight Up 230,000#, String Weight Down 145,000#, String Weight Rotating 180,000#. Calculated ECD 12.64 ppg PWD ECD 12.55 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed to Clean Hole. ART 5.00 hrs, AST 0.25 hrs. Slide Sheet Depth Tool Face 13,399' - 13,444' 170.0 L 13,444' - 13,519' 170.0 R 13,555' - 13,595' 170.0 L Drilled 8-1/2" Directional Hole by Rotating and Sliding from 13,600' to 13,819'. WOB Sliding 5,000# - 8,000#, WOB Rotating 10,000#, RPM 100, Motor RPM 280, Torque Off Bottom 12,000 ft Ilbs - On Bottom 15,000 ft Ilbs, Pump Rate 560 gpm, SPP Off Bottom 2,800 psi, On Bottom 3,100 psi. String Weight Up 230,000#, String Weight Down 145,000#, String Weight Rotating 180,000#. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed to Clean Hole. Circulated Bottoms Up, Pump Rate 560 gpm, 2,800 psi. Rotated and Reciprocated Drill String While Circulating. RPM 100, Torque 10,000 ft Ilbs. POOH, Stood Back 3 Stands of 5" DP, String Weight Up 245,000#. PI U and RIH w/9 Joints of 5" DP. Drilled 8-1/2" Directional Hole by Rotating from 13,819' to 13,987'. WOB Rotating 10,000#, RPM 100, Motor RPM 280, Torque Off Bottom 12,000 ft Ilbs - On Bottom 15,000 ft Ilbs, Pump Rate 540 gpm, SPP Off Bottom 2,850 psi, On Bottom 3,100 psi. Circulated Bottoms Up for Samples per Gelogist request. Pump Rate 540 gpm, 2,760 psi. Rotated and Reciprocated Drill String While Circulating. RPM 100, Torque 12,500 ft Ilbs. Drilled 8-1/2" Directional Hole by Rotating from 13,987' to 14,034'- TD per Geolgist. WOB Rotating - 5K to 10K, RPM 100, Motor RPM 280, Torque Off Bottom 12,000 ft Ilbs - On Bottom 15,000 ft Ilbs, Pump Rate 540 gpm, SPP Off Bottom 2,850 psi, On Bottom 3,100 psi. Daily AST = 3.86 Hrs. ART = 2.22 Hrs. CBU to Clean Hole. Calculated ECD = 12.72 ppg. Actual ECD = 12.75 ppg. Wipe through Window - Max pull = 20K over. Service Top Drive, Crown & D-Works. RIH to TD # 14,034'. No Problems - No Fill. Circulate Hi-Vis Sweep. Spot Lube Pill. POH wI 5" DP. No Drag through Open Hole. POH wI 140 Stands 5" DP. UD 5" HWDP & BHA #3. Clear & Clean Rig Floor. RIU to run 7" Liner. PJSM. Run 20 Jts, 7", 26#, L-80, BTC-M, Liner. CIO Elevators. PIU & MIU, 7" X 9 5/8", Baker HMC Liner Hanger & ZXP Liner Packer Assy. MIU 1 st. stand of 5" DP & Circulate Liner volume @ 3 BPM I Printed: 2/2/2004 2:21 :59 PM .... . . Page 7 of 11 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z -30A Z -30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: NPT ¡Phase ¡ Date From - To ¡ Hours Task Code 1/21/2004 10:30 - 11 :00 0.50 CASE P 11 :00 - 21 :00 10.00 CASE P 21 :00 - 22:00 1.00 CASE P 22:00 - 23:30 1.50 CASE P 23:30 - 00:00 0.50 CASE P INT1 INT1 INT1 INT1 INT1 1/22/2004 2.00 CEMT P 00:00 - 02:00 INT1 02:00 - 03:00 1.00 CEMT P INT1 03:00 - 04:00 1.00 CASE P INT1 04:00 - 05:30 1.50 CEMT P INT1 05:30 - 06:00 0.50 CASE P INT1 06:00 - 07:00 1.00 CASE P INT1 07:00 - 10:30 3.50 CASE P INT1 10:30 - 12:00 1.50 CASE N SFAL INT1 12:00 - 15:00 3.00 CASE P INT1 15:00 - 16:30 1.50 DRILL P PROD1 16:30 - 17:00 0.50 BOPSUR P PROD1 17:00 - 21:30 4.50 BOPSUR P PROD1 21 :30 - 00:00 2.50 DRILL P PROD1 1/12/2004 2/112004 Spud Date: 1/15/2004 End: 2/112004 Description of Operations _"_P_____ 120 psi. Run liner in Hole on 5" DP stands from Derrick to 13,305'. Fill pipe & break circulation every 10 stands. Circulate & Condition Mud above Window. MIU Space out Pup Jts, PIU single on string & M/U Cement head on single. Leave Cement Head on Skate, made up on single. Run Liner through Window & into Open Hole. No Problems. Up weight = 225K, Down weight = 140K. Tagged TD @ 14,034'. No Fill. 100% correct displacement. RIU to circulate. With 7" Liner on Bottom @ 14,034; Break Circulation & Stage Pumps up gradually to 7 BPM @ 1160 psi. Circulate & Condition Mud & Hole. Hold PJSM with Dowell, Rig Crew & Baker. Switch over to Dowell and Cement as follows: Pump 3 BBls of MudPush @ 12.1 ppg. Test lines to 4000 psi. Pump 22 Bbls 12.1 ppg MudPush. Pump 38 Bbls, 15.8 ppg, Class "G" Batch Mixed Slurry wI yield of 1.16 cu. ft./sk. Drop Drill Pipe Wiper Plug and chase wI 5 Bbls Water from Dowell to clear lines. Switch to Rig Pumps & Displace with 228 Bbls 11.6 ppg. Mud. @ 7 BPM, slowing to 3 Bbm to latch into Liner Wiper Plug and again prior to Bumping. Bump Plug and pressure up to 3500 psi. to set HMC Hanger. 100 % Returns throughout Job. Set 50K downn on Hanger to insure set. Bleed pressure to '0' and check floats - OK. Rotate 15 turns to right to release Tool. Pressure up to 1000 psi & P/U until packing out of seal area. Circulate 40 Bbls. Mud @ 7 BPM to move cement up Hole. Slow pumps to 2 BPM & PIU DP 3' to expose dog sub. Set down 50 K to set ZXP Liner Top Packer. Top of Tie Back Sleeve on ZXP Packer@ 13,186'. Insert Landing Collar @ 13,948'. Shoe on Bottom @ 14,034'. Circulate Bottoms up @ 500 GPM I 2420 psi. Approximately 10 Bbls. Cement to Surface. Pump Dry Job. UD Cement Head wI single. Break Down Circ. Lines & Hose. Flush Mud Manifold. POH wI 7 Stands. UD Space out single & 2 Pup Jts. P/U & BIO Cement Head & single. UD Same. POH to 5212'. Iron Roughneck not working. Troubleshoot & Repair Va reo Iron Roughneck - Repair electrical controlleaver on control panel. Complete POH wI 5" DP. UD C-2 Running Tool. Slip & Cut 185' off Drilling Line. Drain Stack. Pull Wear Bushing. PJSM. Test BOPE to 250 13500 psi. Tested both 4" and 5" TIW and Gray IBOP. P/U & M/U 61/8" BHA. Printed: 2/2/2004 2:21 :59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1/23/2004 00:00 - 00:30 00:30 - 06:00 06:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 16:30 16:30 - 19:00 19:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 1/24/2004 00:00 - 00:30 18:30 - 20:00 20:00 - 21 :30 21 :30 - 23:30 . . Page 8 of 11 BP Operations Summary Report Z-30A Z -30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Hours I Task Code ! Spud Date: 1/15/2004 End: 2/112004 Start: 1/12/2004 Rig Release: 2/112004 Rig Number: NPT! Phase ______L____._ 0.50 DRILL P 5.50 DRILL P 6.00 DRILL P 1.00 DRILL P 1.00 DRILL P 1.00 DRILL P 1.50 CASE P 2.50 DRILL P 2.00 DRILL P 1.00 DRILL P 2.00 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 INT1 PROD1 PROD1 PROD1 PROD1 PROD1 00:30 - 01 :00 0.50 DRILL P 01 :00 - 01 :30 0.50 DRILL P 01 :30 - 03:00 1.50 DRILL P 03:00 - 04:00 1.00 DRILL P 04:00 - 18:30 14.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 1.50 DRILL P 1.50 DRILL P PROD1 PROD1 2.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 1/25/2004 00:00 - 09:00 9.00 DRILL P PROD1 09:00 - 11 :00 2.00 DRILL P PROD1 11 :00 - 13:30 2.50 DRILL P PROD1 13:30 - 17:30 4.00 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 23:00 4.50 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 Description of Operations ---- ----._------- P/U 1 Jt 4" DP, M/U XO, Break circulation & Test MWD - OK. RIH, P/U 4" DP singles from Shed. Total 120 Jts. RIH wI 5" DP from derrick to 13,168'. Fill pipe prior to entering liner @ 13,186'. Entered Liner with no problems. Continue RIH to 13,827'. Service Top Drive, Blocks & Crown. Hook up Blower Hose. Wash down from 13,827 to Plugs on Landing Collar @ 13,945'. RlU & Test Liner & Lap to 3500 psi. Chart for 30 Minutes. RID testing equipment. Drill Plugs, Landing Collar, Cement, & Float Collar down to 14,032'- 2 ft. above Float Shoe, rotating @ 10 RPM in order to get weight on bit. Pump 55 Bbl Hi - Vis Spacer, 50 Bbls Water, 55 Bbl Hi - Vis Spacer, 50 Bbls Water followed by 8.7 ppg FloPro Mud to Displace 400' above Liner Top. No Rotation. POH to 13,073' - Above Liner Top. Had to M/U Top Drive to every stand because of heavily unballanced condition. Continue 8.7 ppg. FloPro Displacement in 95/8" Casing, rotating @ 50 RPM & pumping @ 280 GPM. Complete dispacement of 8.7 ppg. FloPro Mud. Pres. from 2700 psi. down to 1700 psi. when completely displaced wI 8.7 ppg. new mud. RIH to 14,015. Wash down to 14,032'. Drill out Shoe and 20' of New Hole to 14,054'. NO losses. Circulate Clean & Condition Mud to a balanced 8.7 ppg. in and out. 275 GPM & 1700 psi. RlU & Perform FIT test.- 8.7 ppg Mud in Hole. TVD @ Shoe = 8689'. Pressured up in straight line to 1046 psi. FIT = 11.02 ppg. EMW. Take ECD Baselines & Directional Drill 6 1/8" Hole, All Slide, from 14,054 to 14,423'. 285 to 290 GPM 1950 psi on bottom, 1700 psi. off bottom. WOB 15K to 25K. AST = 8.92 Hrs. Circulate @ 290 GPM 1720 psi. Reciprocate but no Rotation. Pump out of Hole 11 Stands to position Circ Sub at TOL in 9 5/8" Casing @ 13,186'. Pumped out @ 280 GPM & 1680 psi. Drop Bar & Break circulation, Open Circ Sub and circulate Hi-Vis Sweep @ 575 GPM & 1630 psi. Rotate @ 50 RPM while Reciprocating Drill Pipe 90'. Hole cleaned up totally after sweep over shakers. Shut down pumps, Monitor well, Pump Slug. POH POH, standing back 5" DP. Lay Down 90 Jts of 5" DP to make room for 40 stands of 4" DP in Derrick. Continue POH - Stand Back HWDP & Flex Collars. UD MWD, Motor & Bit. P/U BHA #5. Surface Test - OK. RIH wI 4" DP. P/U 5" DP from Shed & RIH. Service Top Drive, Blocks, Crown & Hydraulic Brake. RIH to 14,390'. Precautionary Wash to bottom @ 14,423'. No Problems, No Fill. Directional Drill 6 1/8" Hole from 14,423' to 14,450' sliding all Printed: 2/2/2004 2:21 :59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/25/2004 1/26/2004 1/27/2004 1/28/2004 1/29/2004 . . Page 9 of 11 BP Operations Summary Report . Z-30A Z-30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Spud Date: 1/15/2004 End: 2/112004 Start: 1/12/2004 Rig Release: 2/112004 Rig Number: NPT I Phase I From - To Hours! Task Code 23:00 - 00:00 00:00 - 00:00 00:00 - 08:30 08:30 - 10:30 10:30 - 14:30 14:30 - 15:00 15:00 - 17:00 17:00 - 20:30 20:30 - 00:00 00:00 - 02:00 02:00 - 06:00 06:00 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 19:00 19:00 - 00:00 00:00 - 00:30 00:30 - 02:30 1.00 DRILL P PROD1 24.00 DRILL P PROD1 8.50 DRILL P PROD1 2.00 DRILL P PROD1 4.00 DRILL P PROD1 0.50 DRILL P 2.00 DRILL P PROD1 PROD1 3.50 DRILL P PROD1 3.50 DRILL P PROD1 2.00 DRILL P PROD1 4.00 DRILL P PROD1 6.00 DRILL P PROD1 1.50 DRILL P 0.50 CASE P 5.00 CASE P PROD1 COMP COMP 5.00 CASE P COMP 0.50 CASE P COMP 2.00 CASE P COMP Description of Operations the way. 290 GPM @ 1950 psi. Wt on Bit + 5 to 15K. P/U Wt. = 225K, Slack Of Wt = 150K. AST = 0.56 Hrs. Directional Drill 6 1/8" Hole from 14,450' to 15,890'. 290 GPM @ 2250 psi. WOB = 10 to 25K Torque On = 11.5K, Torque Off = 10K. PIU Wt = 225K, Dn Wt. = 150K, Rot. Wt. = 185K. Calculated ECD = 9.75 ppg. Actual ECD = 9.92 ppg. AST = 9.24 Hrs. ART = 4.94 Hrs. Pumped Hi-Vis Sweeps while Rotating after Slides when ECD greater than 0.3 ppg over calculated. Directional Drill 6 1/8" Hole from 15,890 to 16,600' - TD. 290 GPM @ 2410 psi. WOB = 10K to 17K P/U Wt. = 225K, Dn WT. = 143K, ROT Wt. = 185K Torque On = 11 K to 13K, Torque Off = 8.5K ECD @ TD = 10.1 ppg. Calculated ECD = 10.0 ppg AST = 0.97 Hrs. ART = 4.46 Hrs. Circulate Hi-Vis Sweep @ 290 GPM & 2100 psi. Rotating @ 80 RPM wI 8.5K Torque. Pump out of Hole to 7" Liner Shoe @ 14,034. Pumping @ 270 GPM 11900 psi. No Rotation. Service Top Drive, Blocks & Crown. RIH to 16,551'. No Problems. Precautionary Wash to Bottom @ 16,600'. Circulate Hi-Vis Sweep @ 290 GPM & 2100 psi. Spot Lube Pill in DP. Pump out of Hole @ 52 GPM 1450 psi. Laying Lube Pill in Open Hole. Pump out of Hole to 7" Liner Shoe laying Lube Pill in Open Hole. Pump out at 270 GPM & 1600 psi to position Circ Sub A Liner Top - 13,186'. Drop Ball/Dart and pump down to open Circ. Sub. Circulate @ 580 GPM & 1650 psi. Pump 15 Bbls Water followed by 25 BBI. Hi- Vis Sweep. Some sand over shakers, but not as much as expected. Pump 20 bbls Water followed by 50 Bbl. Hi-Vis Sweep, weighted to 10.0 ppg. Again some sand over shakers. Pump Slug. POH w/5" DP to 4102'. Stand back 8 Stands 4" DP, UD remaining 96 Jts. BIO & UD BHA #5. Clear & Clean Floor. RIU to run 4.5" Production Liner. Run 4.5" Production Liner as per Program. Total of 53 Jts Slotted & 12 Jts Solid wI Baker 'HMC' Hydraulic Hanger. P/U 14 Jts of 4" DP from Shed and Continue RIH wI Stands from Derrick to just above 7" Shoe @ 14,011'. Circulate DP Volume prior to entering Open Hole. 280GPM @ 900 psi. Up Wt. = 225K, Dn Wt = 150K. RIH wI Production Liner on 5" DP to TD @ 16,600', Hole Very Slick - No Problems. Slack Off Wt. = 150K. Pick up Wt = 240K. Pick String Up 1 (one) Ft. Printed: 2/2/2004 2:21 :59 PM . . BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-30A Z-30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Date I From - To Hours Task: Code NPT Phase __n__ 1/29/2004 2.50 CASE P 02:30 - 05:00 COMP 05:00 - 05:30 0.50 CASE P COMP 05:30 - 07:30 2.00 CASE P COMP 07:30 - 09:30 2.00 CASE P COMP 09:30 - 11 :00 1.50 CASE P COMP 11:00 -11:15 0.25 CASE P COMP 11:15-14:00 2.75 CASE N SFAL COMP 14:00 - 23:30 9.50 CASE P COMP 23:30 - 00:00 0.50 RUNCOMP COMP 1/30/2004 00:00 - 01 :30 1.50 RUNCOMP COMP 01 :30 - 02:00 0.50 RUNCOMP COMP 02:00 - 03:00 1.00 RUNCOMP COMP 03:00 - 21 :30 18.50 RUNCOMP COMP 21 :30 - 22:30 1.00 RUNCOMP COMP 22:30 - 00:00 1.50 RUNCOMP COMP 1/31/2004 00:00 - 03:00 3.00 RUNCOMP COMP 03:00 - 03:30 0.50 RUNCOMP COMP 03:30 - 04:30 1.00 RUNCOMP COMP 04:30 - 07:00 2.50 RUNCOMN DPRB COMP 07:00 - 13:30 6.50 RUNCOMN DPRB COMP 13:30 - 15:30 2.00 RUNCOMP COMP Page 10 of 11 Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/112004 1/12/2004 2/112004 Description of Operations Break Circulation - Circulating OK. Shut down pumps, BIO Top Drive & drop Baker 29132" Setting Ball. MIU Top Drive & pump ball down for 121 Bbls @ 4 BPM. Slow pumps down to 1.5 BPM and pump another 106 Bbls to seat Ball. Pressure up to 2500 psi to set HMC Hanger. Slack off 50 K to insure slips engaged - OK. Pressure up to 3500 to release HR Tool & then up to 4275 psi. to Shear out Ball & Seat. Liner Set @ 16,600' Top of Liner: ('HR' Sleeve) @ 13,914'. Pick up out of Liner with Setting Tool, UD one single of DP. Pump 419 Bbls Seawater @ 8 Bbl Min I 900 psi. Follow wI 8.6 ppg KCL Brine until Clean Seawater @ Surface. Clean Possum Belly, Shakers, Trough, Flush Hole fill, Choke & Kill lines. Complete displacement of well to 8.6 ppg KCL. POH UD 5" DP. Bolt broke on Varco Iron Roughneck Spinner Wrench. Repair Iron Roughneck POH UD all 5" & 4" DP. Clear & Clean Rig Floor. RlU to run 4.5" Completion String. Pre - Job Safety Meeting with Crew, Casers & Baker. Pull Wear Bushing & PIU & Make Dummy Run with Tubing Hanger & Landing Jt. PIU & M/U 4.5" Completion Tail Assy, 'X' Nipple Assy & Baker S-3 Packer Assy. Bakerloc all connections below Packer. Continue RIH wI 4.5", 12.6#, 13 Cr, VAM-TOP Tubing as per Program. Torque to 4,440 ftllbs. Run total 325 Jts. + jewelry. Space out 3' up into Tie Back Sleeve. UD Tbg Jt & PIU Space out Pup, Tbg Hanger & Landing Jt. Reverse Cirulate Corrosion Inhibited 8.6 ppg, KCL, Brine @ 3 BPM I 270 psi. Complete Displacing Annulus with 542 Bbls, Corrosion Inhibited, 8.6 ppg. KCL Brine. Chase with 175 BBls Clean, 8.6 ppg. KCL Brine to Spot below Upper GLM. Pump All @ 3 BPM. Land Tubing Hanger, Drop BalllRod & R.I.L.D.S. Pump down Tubing in attempt to set Packer - BallI Rod not on seat. Pump 30 Bbls no Success. Attempt to surge @ 7.5 BPM - Bleed down & re- try 15 Times- No Success. Call out SWS Slick Line Wait on SWS Slick Line. Secure proper XO's and RlU for WL while waiting. Also pump down annulus wI Clean KCL to re-spot Corrosion inhibited KCL displaced when trying to set Ball/Rod. PJSM wI SWS Slick Line Crew. RlU Lubricator & Test. RIH wI 3.5" OS & LIB. Found Ball-Rod Assy in Top GLM. Knock Free & Chase to RHC Plug. Test to 500 psi to confirm. POH & RID SWS Slick Line. Test Tubing to 3500 psi. Hold & Chart for 30 Minutes Bleed Tubing to 1500 psi. Printed: 2/212004 2:21 :59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ---..---- 1/31/2004 .... . BP Operations Summary Report Phase COMP 15:30 - 16:00 0.50 BOPSURP COMP 16:00 - 18:00 2.00 BOPSURP COMP 18:00 - 22:00 4.00 WHSUR P COMP 22:00 - 22:30 0.50 WHSUR P COMP 22:30 - 23:00 0.50 RIGD P COMP 23:00 - 00:00 1.00 RUNCOMP COMP 2/1/2004 00:00 - 02:00 2.00 RUNCOMP COMP Z-30A Z-30A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES From - To I Hours Task Code 1 NPT 13:30 - 15:30 2.00 RUNCOMP 02:00 - 03:00 03:00 - 03:30 03:30 - 04:00 1.00 RUNCOMP 0.50 RUNCOMP 0.50 RUNCOMP COMP COMP COMP Page 11 of 11 Start: 1/12/2004 Rig Release: 2/112004 Rig Number: Spud Date: 1/15/2004 End: 2/112004 Description of Operations Pressure Annulus to 3500 psi. Hold & Chart for 30 Minutes. Bleed Annulus - Then Bleed Tubing. Pressure Annulus to 2100 psi- DCR in GLM #5 @ 3254'MD Sheared. Pump each way to confirm Shear. Pull Landing JI. Dry Rod in TWC. Test from Below to 1000 psi. NID BOPE & Set Back Same. NIU Adapter Flange & Tree. Test Both to 5000 psi. RlU DSM Lubricator & Pull TWC. RID Lubricator. Remove Bails & Elevators from Top Drive. PJSM wI Little Red Hot Oilers. RlU Little Red. Test lines & reverse Cirulate, pumping Diesel down Annulus. Complete pumping 156 Bbls heated diesel down 41/2" X 9 5/8" Annulus. Shut in and allow to U-Tube into Tubing. Diesel sufficient to Freeze Protect Tubing & Annulus to 2200' TVD 12264 MD. RlU DSM Lubricator & Set BPV. RID DSM. Test BPV to 1000 psi wI Little Red-OK. Bleed off Annulus & Lines. Install VR Plugs in Both Upper Annulus Valves wI blind flange & Gauge. Install Tree Cap. Suck out Cellar. Secure Well. RIG RELEASED @ 04:00 HOURS 1 FEBRUARY 2004. Printed: 2/212004 2:21 :59 PM . . Well: Field: API: Permit: Z -30A Prudhoe Bay Unit 50-029-22013-01 203-219 Accept: Spud: Release: Rig: 01/12/04 01/19/04 02/01/04 Nabors 7ES y, ·~=·Y"·.=Y= .," =".. .=__ .. _=" POST RIG WORK 02/15/04 ASSIST REMOVAL OF BPV. PULL BALL AND ROD FROM 13883' SLM. PULLED DGLV'S FROM. ST A'S# 1, 3, & 4 & SHEAR VALVE FROM ST A. # 5. CURRENTLY ATTEMPTING TO PULL ST A. # 2 DGLV. 02/16/04 PULL 1-1/2" DGLV RK FROM STA-2 @ 12400' SLM. SET 1-1/2" LGLV (16/64,1406#, RK) IN STA-5 @ 3240' SLM. SET 1-1/2" LGLV (16/64,1385#, RK) IN STA-4 @ 7004' SLM. SET 1-1/2" LGLV (16/64, 1363#, RK) IN STA-3 @ 9975' SLM. SET 1-1/2" LGLV (16/64,1338#, RK) IN STA-2 @ 12400' SLM. SET 1" OGLV (22/64, BK) IN STA-1 @ 13767' SLM. ATTEMPTING TO PULL RHC PLUG BODY- CANNOT GET BY ST A-5. 02/17/04 RAN 3.70" IMPRESSION BLOCK TO STA-5 @ 3240' SLM (IMPRESSION OF GLV LATCH -1-1/4" FROM EDGE OF BLOCK). RAN 3.60" BELL GUIDE & PULLING TOOL TO SAME AND COULD NOT LATCH - SAW NO MARKS ON TOOLS. SHUT DOWN DUE TO COLD TEMP (-42°) @ 03:00 HRS. 02/20/04 PULL LGLV FROM STA-5 (MISS-SET ON 2/16/04 WSR). BRUSH OUT STA-5 AND SET DGLV TO ENSURE GOOD MANDREL. DRIFT W/3.80 CENTRALIZER THROUGH STATION #5. PULL DGLV FROM ST A-5 (BOTH SETS OF PKG TORE UP). RIH TO ST A. #5 TO SET DGL V TO ENSURE A CLEAN POCKET. 02/21/04 SET AND PULL DGLV IN STA. #5 TO ENSURE CLEAN POCKET (HAD TROUBLE SETTING VALVE YESTERDAY). POCKET LOOKS CLEAN - PKG ON DGLV GOOD - LOOKS LIKE VALVE WAS ALL THE WAY INTO NO-GO. SET 1-1/2" LGLV (1406#,16/64, RK) IN STA. #5 @ 3240' SLM. PULL 41/2" RHC PLUG FROM XN NIP @ 13892' SLM (HALF OF PKG GONE - BACK UP RING BENT). WELL LEFT S/I. 03/03/04 INITIAL FLOW BACK AND WELL TEST ON Z-30A, USING FLOWLINE FOR Z-26. . . Ö Schlumberger /.'...:." Z-30A Survey Report Report Date: February 2, 2004 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 106.450' Field: Prudhoe Bay Unn . WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Z·PAD / Z·30 TVD Reference Datum: Rotary Table Well: Z·30 TVD Reference Elevation: 79.57 ft relative to MSL Borehole: Z·30A Sea Bed 1 Ground Level Elevation: 51.32 ft relative to MSL UWUAPI#: 500292201301 Magnetic Declination: 25.144' Survey Name 1 Date: Z·30A 1 January 14, 2004 Total Field Strength: 57556.406 nT Tort 1 AHD 1 DDII ERD ratio: 333.492' 112629.06 ft 16.894/1.414 Magnetic Dip: 80.799' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 14, 2004 Location LatlLong: N 70 17 54.294, W 14911 52.462 Magnetic Declination Model: BGGM 2003 Location Grid N/E YIX: N 5959359.990 ftUS, E 599043.010 ftUS North Reference: True North Grid Convergence Angle: +0.75514597' Total Corr Mag North .> True North: +25.144' Grid Scale Factor: 0.99991114 Local Coordinates Referenced To: Well Head Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Lathude Longhude Depth Section Departure (ft) ( deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg/100 ft) ( deg/100 ft) ( deg/100 ft) (ftUS) (ftUS) 13341.75 58.88 3.54 8217.28 8137.71 -3849.83 9618.55 9495.37 -1210.49 0.70 -0.45 0.62 5968837.73 597707.60 N 70 1927.679 W 149 1227.793 13341.75 58.88 3.54 8217.28 8137.71 -3849.83 9618.55 9495.38 -1210.49 0.00 0.00 0.00 5968837.73 597707.60 N 70 1927.679 W 149 1227.793 13367.00 58.79 3.62 8230.34 8150.77 -3854.64 9640.16 9516.94 -1209.14 0.45 ·0.36 0.32 5968859.30 597708.66 N 70 1927.891 W 149 1227.754 13383.00 60.09 1.73 8238.48 8158.91 -3857.92 9653.94 9530.70 -1208.50 13.02 8.12 -11.81 5968873.07 597709.12 N 70 1928.027 W 149 1227.735 13399.00 60.09 1.73 8246.46 8166.89 -3861 .45 9667.81 9544.56 -1208.08 0.00 0.00 0.00 5968886.94 597709.36 N 70 1928.163 W 149 12 27.723 13465.37 53.65 0.64 8282.71 8203.14 -3876.05 9723.36 9600.10 -1206.92 9.80 -9.70 -1.64 5968942.48 597709.80 N 70 1928.709 W 149 12 27.689 13560.09 48.58 358.83 8342.16 8262.59 -3897.21 9797.06 9673.80 -1207.21 5.56 -5.35 -1.91 5969016.16 597708.53 N 70 1929.434 W 149 1227.698 13652.89 44.16 358.45 8406.17 8326.60 -3917.74 9864.21 9740.93 -1208.80 4.77 -4.76 -0.41 5969083.26 597706.06 N 701930.094 W 149 1227.745 13747.12 41.84 358.35 8475.08 8395.51 -3937.65 9928.47 9805.17 -1210.59 2.46 -2.46 -0.11 5969147.46 597703.42 N 70 19 30.726 W 149 1227.797 13846.41 41.38 358.74 8549.32 8469.75 -3957.93 9994.41 9871.08 -1212.27 0.53 -0.46 0.39 5969213.34 597700.87 N 70 1931.374 W 149 1227.846 13939.24 41.52 3.94 8618.92 8539.35 -3973.93 10055.83 9932.47 -1210.83 3.71 0.15 5.60 5969274.74 597701.50 N 70 19 31.978 W 1491227.805 13962.72 42.03 6.88 8636.43 8556.86 -3976.92 10071.47 9948.04 -1209.35 8.62 2.17 12.52 5969290.33 597702.78 N 70 19 32.131 W 149 12 27.762 14026.54 43.45 11.02 8683.31 8603.74 -3982.55 10114.78 9990.80 -1202.60 4.93 2.23 6.49 5969333.17 597708.97 N 70 1932.552 W 149 12 27.565 14056.58 44.61 12.87 8704.91 8625.34 -3984.19 10135.65 10011.23 -1198.27 5.76 3.86 6.16 5969353.65 597713.02 N 70 1932.753 W 149 12 27.438 14088.10 48.45 19.05 8726.60 8647.03 -3984.34 10158.51 10033.18 -1191.95 18.72 12.18 19.61 5969375.68 597719.05 N 70 1932.968 W 149 12 27.254 14119.83 52.19 25.61 8746.87 8667.30 -3981.81 10182.92 10055.73 -1182.65 19.79 11.79 20.67 5969398.35 597728.05 N 70 19 33.190 W 149 1226.983 14150.79 55.24 31.19 8765.20 8685.63 -3976.62 10207.87 10077.66 -1170.77 17.55 9.85 18.02 5969420.43 597739.64 N 70 1933.406 W 149 1226.636 14181.87 57.17 40.03 8782.51 8702.94 -3968.14 10233.68 10098.61 -1155.74 24.43 6.21 28.44 5969441.57 597754.40 N 70 19 33.612 W 1491226.197 14212.24 59.28 45.15 8798.51 8718.94 -3956.76 10259.49 10117.59 -1138.26 15.92 6.95 16.86 5969460.79 597771.62 N 70 1933.799 W 149 1225.687 14244.10 61.71 51.94 8814.22 8734.65 ·3942.02 10287.21 10135.92 -1117.49 20.05 7.63 21.31 5969479.38 597792.15 N 70 1933.979 W 149 1225.081 14275.09 65.12 57.18 8828.09 8748.52 -3924.91 10314.91 10151.96 -1094.91 18.70 11.00 16.91 5969495.72 597814.51 N 70 19 34.137 W 1491224.422 14305.24 68.23 63.38 8840.04 8760.47 -3905.74 10342.59 10165.66 -1070.88 21.51 10.31 20.56 5969509.73 597838.36 N 70 19 34.272 W 149 1223.721 14337.64 72.16 68.76 8851.02 8771.45 -3882.52 10373.07 10178.00 -1043.03 19.78 12.13 16.61 5969522.44 597866.04 N 70 19 34.393 W 149 12 22.908 14369.61 75.48 73.73 8859.93 8780.36 -3857.44 10403.76 10187.86 -1013.96 18.18 10.38 15.55 5969532.68 597894.97 N 70 19 34.490 W 149 1222.059 14395.26 77.40 76.83 8865.95 8786.38 -3836.11 10428.70 10194.19 -989.85 13.93 7.49 12.09 5969539.33 597918.99 N 70 19 34.552 W 14912 21.355 14425.63 80.35 81.72 8871.81 8792.24 -3809.61 10458.49 10199.73 ·960.58 18.54 9.71 16.10 5969545.25 597948.18 N 70 19 34.607 W 149 12 20.501 14457.17 80.91 85.33 8876.95 8797.38 -3780.95 10489.61 10203.24 -929.67 11.43 1.78 11.45 5969549.16 597979.05 N 70 19 34.641 W 14912 19.599 14488.60 80.76 88.10 8881.95 8802.38 -3751.75 10520.64 10205.02 -898.69 8.71 -0.48 8.81 5969551.35 598009.99 N 70 19 34.659 W 149 12 18.695 14519.42 81.17 90.65 8886.79 8807.22 -3722.65 10551.08 10205.35 -868.26 8.28 1.33 8.27 5969552.08 598040.42 N 70 19 34.662 W 149 12 17.806 14551.44 82.74 93.97 8891.28 8811.71 ·3691.92 10582.78 10204.07 -836.59 11.38 4.90 10.37 5969551 .22 598072.10 N 70 1934.650 W 149 12 16.882 14582.36 85.12 94.94 8894.55 8814.98 -3661.84 10613.53 10201.68 -805.94 8.31 7.70 3.14 5969549.24 598102.78 N 701934.626 W 149 12 15.987 14614.47 87.66 95.08 8896.57 8817.00 -3630.44 10645.57 10198.88 -774.02 7.92 7.91 0.44 5969546.86 598134.73 N 701934.599 W 149 12 15.055 14650.03 89.48 96.28 8897.46 8817.89 -3595.51 10681.12 10195.36 -738.64 6.13 5.12 3.37 5969543.81 598170.14 N 70 1934.564 W 149 12 14.023 14681.85 89.03 97.69 8897.87 8818.30 -3564.13 10712.93 10191.49 -707.06 4.65 -1.41 4.43 5969540.35 598201.77 N 70 1934.526 W 149 12 13.101 14709.80 88.55 100.50 8898.46 8818.89 -3536.42 10740.88 10187.08 -679.47 10.20 -1.72 10.05 5969536.30 598229.41 N 70 1934.483 W 149 12 12.295 14740.04 87.97 104.45 8899.38 8819.81 -3506.27 10771.10 10180.55 -649.97 13.20 -1.92 13.06 5969530.16 598259.00 N 70 1934.418 W 1491211.434 14772.44 88.55 107.02 8900.36 8820.79 -3473.89 10803.49 10171.77 -618.80 8.13 1.79 7.93 5969521.79 598290.28 N 70 1934.332 W 149 12 10.524 14802.35 88.52 108.91 8901.13 8821.56 -3444.01 10833.39 10162.54 -590.36 6.32 -0.10 6.32 5969512.95 598318.83 N 70 19 34.241 W 149 129.694 14835.70 89.17 112.29 8901.80 8822.23 -3410.75 10866.73 10150.81 -559.15 10.32 1.95 10.13 5969501.63 598350.19 N 70 19 34.126 W 149 128.783 14865.91 89.24 115.32 8902.22 8822.65 -3380.80 10896.94 10138.62 -531.52 10.03 0.23 10.03 5969489.81 598377.98 N 70 19 34.006 W 149 127.976 14897.40 88.76 117.54 8902.77 8823.20 -3349.79 10928.42 10124.61 -503.32 7.21 -1.52 7.05 5969476.17 598406.35 N 70 1933.868 W 149127.153 14929.66 88.83 121.07 8903.45 8823.88 -3318.35 10960.68 10108.83 -475.20 10.94 0.22 10.94 5969460.76 598434.68 N 70 1933.713 W 149 126.333 14959.91 88.86 123.95 8904.06 8824.49 -3289.29 10990.92 10092.57 -449.70 9.52 0.10 9.52 5969444.84 598460.39 N 70 1933.553 W 149 125.588 14991.28 89.34 126.19 8904.55 8824.98 -3259.57 11022.29 10074.55 -424.03 7.30 1.53 7.14 5969427.16 598486.29 N 70 1933.376 W 149 124.839 15026.29 89.75 127.54 8904.83 8825.26 -3226.76 11057.30 10053.55 -396.02 4.03 1.17 3.86 5969406.54 598514.57 N 70 19 33.170 W 149 124.021 15057.59 89.38 128.35 8905.07 8825.50 -3197.64 11088.59 10034.30 -371.34 2.85 -1.18 2.59 5969387.62 598539.50 N 70 19 32.980 W 149 123.301 15084.67 89.51 128.93 8905.33 8825.76 -3172.57 11115.67 10017.40 -350.19 2.19 0.48 2.14 5969370.99 598560.87 N 70 19 32.814 W 149 122.683 15118.01 89.99 129.02 8905.47 8825.90 -3141.77 11149.01 9996.43 -324.27 1.46 1.44 0.27 5969350.37 598587.06 N 70 19 32.608 W 149 121.927 15152.57 89.58 130.10 8905.60 8826.03 -3109.98 11183.57 9974.42 -297.63 3.34 -1.19 3.12 5969328.71 598613.99 N 70 19 32.391 W 149121.149 15178.82 89.31 130.21 8905.86 8826.29 -3085.95 11209.82 9957.49 -277.56 1.11 -1.03 0.42 5969312.05 598634.27 N 70 19 32.225 W 149 120.563 SurveyEditorVer 3.1RT-SP3.03-HF2.03 Bld( d031rt-546) Z-301Z-301Z-30AIZ-30A Generated 3/4/2004 2:10 PM Page 1 of 2 '" . . . Measured Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Ea.ling Lathude Longhude Depth Section Departure (ft) ( deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg/l00 ft ) ( deg/l00 ft) ( deg/l00 ft) (ftUS) (ftUS) 15211.33 90.10 131.58 8906.02 8826.45 -3056.36 11242.33 9936.21 -252.99 4.86 2.43 4.21 5969291.10 598659.12 N 70 19 32.016 W 14911 59.846 15246.51 89.89 132.58 8906.03 8826.46 -3024.64 11277.51 9912.63 -226.88 2.90 -0.60 2.84 5969267.87 598685.54 N 70 1931.784 W 14911 59.084 15272.75 89.21 132.47 8906.23 8826.66 -3001.07 11303.75 9894.90 -207.54 2.63 -2.59 -0.42 5969250.39 598705.11 N 70 1931.609 W 14911 58.519 15306.57 88.32 133.85 8906.96 8827.39 -2970.87 11337.56 9871.77 -182.88 4.85 -2.63 4.08 5969227.59 598730.07 N 701931.382 W 14911 57.800 15337.95 88.42 132.86 8907.86 8828.29 -2942.89 11368.93 9850.23 -160.07 3.17 0.32 -3.15 5969206.36 598753.16 N 70 19 31.170 W 14911 57.134 15364.85 86.81 132.79 8908.97 8829.40 -2918.82 11395.80 9831.96 -140.36 5.99 -5.99 -0.26 5969188.36 598773.11 N 70 19 30.990 W 149 11 56.558 15399.66 85.74 135.00 8911.24 8831.67 -2887.99 11430.54 9807.88 -115.33 7.04 -3.07 6.35 5969164.61 598798.45 N 70 19 30.754 W 149 11 55.828 15433.36 84.95 134.88 8913.97 8834.40 -2858.47 11464.13 9784.16 -91.56 2.37 -2.34 -0.36 5969141.20 598822.53 N 70 1930.520 W 149 11 55.134 15459.45 85.95 135.91 8916.04 8836.47 -2835.71 11490.14 9765.64 -73.29 5.49 3.83 3.95 5969122.93 598841.04 N 70 1930.338 W 149 11 54.601 15492.34 87.12 135.45 8918.03 8838.46 -2807.06 11522.97 9742.15 -50.36 3.82 3.56 -1.40 5969099.75 598864.28 N 70 1930.107 W 149 11 53.931 15522.11 86.26 135.00 8919.75 8840.18 -2781.01 11552.69 9721.05 -29.42 3.26 -2.89 -1.51 5969078.93 598885.49 N 70 19 29.900 W 149 11 53.320 15552.83 85.92 135.42 8921.84 8842.27 -2754.15 11583.33 9699.30 -7.83 1.76 -1.11 1.37 5969057.47 598907.36 N 70 1929.686 W 149 11 52.690 15586.19 85.85 135.43 8924.24 8844.67 -2725.04 11616.61 9675.60 15.52 0.21 -0.21 0.03 5969034.08 598931.02 N 701929.453 W 149 11 52.008 15615.89 85.68 136.41 8926.43 8846.86 -2699.25 11846.23 9654.33 36.13 3.34 -0.57 3.30 5969013.08 598951.90 N701929.243 W1491151.407 15844.37 85.40 136.31 8928.64 8849.07 -2674.64 11674.62 9633.78 55.72 1.04 -0.98 -0.35 5968992.79 598971.77 N 701929.041 W 149 11 50.835 15681.76 86.43 137.75 8931.31 8851.74 -2642.53 11711.92 9606.49 81.14 4.73 2.75 3.85 5968965.84 598997.54 N 70 1928.773 W 149 11 50.093 15710.50 88.25 137.08 8932.64 8853.07 -2617.91 11740.62 9585.35 100.57 6.75 6.33 -2.33 5968944.96 599017.24 N 70 1928.565 W 149 11 49.526 15739.44 90.24 137.07 8933.02 8853.45 -2593.01 11769.56 9584.16 120.27 6.88 6.88 -0.03 5968924.04 599037.22 N 70 1928.357 W 149 11 48.951 15775.14 92.78 137.16 8932.08 8852.51 -2562.32 11805.24 9538.02 144.56 7.12 7.12 0.25 5968898.22 599061 .85 N 70 19 28.099 W 149 11 48.242 15805.04 93.68 136.93 8930.40 8850.83 -2536.62 11835.10 9516.17 164.90 3.11 3.01 -0.77 5968876.64 599082.47 N 70 1927.885 W 149 11 47.648 15831.75 93.57 136.19 8928.71 8849.14 -2513.56 11861.75 9496.81 183.23 2.80 -0.41 -2.77 5968857.53 599101.06 N 70 1927.694 W 1491147.113 15866.61 92.43 135.07 8926.88 8847.31 -2483.17 11896.56 9471.93 207.57 4.58 -3.27 -3.21 5968832.97 599125.72 N 70 1927.449 W 149 11 46.403 15898.72 92.06 135.59 8925.63 8846.06 -2455.08 11928.65 9449.11 230.13 1.99 -1.15 1.62 5968810.45 599148.57 N 70 1927.225 W 149 11 45.745 15926.96 92.23 134.51 8924.57 8845.00 -2430.30 11956.87 9429.14 250.07 3.87 0.60 -3.82 5968790.75 599168.77 N701927.029 W1491145.163 15961.08 92.06 134.52 8923.29 8843.72 -2400.21 11990.97 9405.23 274.38 0.50 -0.50 0.03 5968767.17 599193.40 N 70 1926.794 W 149 11 44.453 15991.99 92.51 135.55 8922.06 8842.49 -2373.09 12021.85 9383.38 296.20 3.63 1.46 3.33 5968745.61 599215.51 N 70 1926.579 W 149 11 43.816 16021.18 93.05 136.01 8920.64 8841.07 -2347.67 12051.01 9362.49 316.54 2.43 1.85 1.58 5968724.99 599236.11 N 70 1926.373 W 149 11 43.223 16054.69 92.99 136.59 8918.88 8839.31 -2318.65 12084.47 9338.29 339.66 1.74 -0.18 1.73 5968701.10 599259.54 N 70 19 26.135 W 149 11 42.548 16086.42 92.71 136.80 8917.30 8837.73 -2291.27 12116.16 9315.23 361.39 1.10 -0.88 0.66 5968678.33 599281 .58 N 70 1925.908 W 149 11 41.914 16113.61 92.33 136.88 8916.11 8836.54 -2267.84 12143.33 9295.42 379.97 1.43 -1.40 0.29 5968658.76 599300.42 N701925.713 W1491141.371 16147.38 91.54 136.23 8914.97 8835.40 -2238.64 12177.08 9270.91 403.18 3.03 -2.34 -1.92 5968634.57 599323.95 N 70 1925.472 W 149 11 40.694 16179.58 91.92 137.07 8913.99 8834.42 -2210.83 12209.26 9247.51 425.28 2.86 1.18 2.61 5968611.46 599346.34 N 70 19 25.242 W 149 11 40.049 16210.16 93.85 135.63 8912.45 8832.88 -2184.35 12239.80 9225.41 446.36 7.87 6.31 -4.71 5968589.65 599367.71 N 70 1925.025 W 149 11 39.434 16241.97 93.77 135.40 8910.34 8830.77 -2156.61 12271.54 9202.77 468.60 0.76 -0.25 -0.72 5968567.30 599390.25 N 70 1924.802 W 149 11 38.785 16274.67 93.40 136.02 8908.30 8828.73 -2128.14 12304.18 9179.41 491.38 2.20 -1.13 1.90 5968544.24 599413.34 N 70 1924.572 W 149 11 38.120 16304.56 92.85 136.37 8906.67 8827.10 -2102.23 12334.02 9157.87 512.04 2.18 -1.84 1.17 5968522.98 599434.28 N 70 1924.361 W 149 11 37.517 16340.03 92.44 136.71 8905.03 8825.46 -2071.57 12369.45 9132.15 536.42 1.50 -1.16 0.96 5968497.59 599458.99 N 70 1924.108 W 149 11 36.806 16371.02 92.95 136.43 8903.57 8824.00 -2044.79 12400.41 9109.67 557.70 1.88 1.65 -0.90 5968475.39 599480.56 N 70 1923.887 W 149 11 36.185 16400.17 93.53 134.84 8901.92 8822.35 -2019.39 12429.51 9088.86 578.05 5.80 1.99 -5.45 5968454.86 599501.18 N 701923.682 W 149 11 35.591 18435.65 93.36 135.86 8899.79 8820.22 -1988.38 12464.93 9063.67 602.94 2.91 -0.48 2.87 5968429.99 599526.40 N 701923.434 W 149 11 34.864 16467.10 93.33 135.75 8897.96 8818.39 -1961.02 12496.32 9041.16 624.82 0.36 -0.10 -0.35 5968407.78 599548.57 N701923.213 W1491134.226 16495.26 93.22 136.13 8896.35 8816.78 -1936.54 12524.44 9020.96 844.37 1.40 -0.39 1.35 5968387.83 599568.39 N 70 1923.014 W 149 11 33.655 16527.29 92.85 135.91 8894.65 8815.08 -1908.73 12556.42 8997.94 666.58 1.34 -1.16 -0.69 5968365.12 599590.90 N 70 1922.788 W 149 11 33.007 16546.50 92.60 135.63 8893.74 8814.17 -1891.99 12575.61 8984.19 679.97 1.95 -1.30 -1.46 5968351.54 599604.46 N 701922.652 W 14911 32.616 16600.00 92.60 135.63 8891.31 8811.74 -1845.33 12629.06 8945.99 717.34 0.00 0.00 0.00 5968313.84 599642.33 N 70 1922.277 W 14911 31.526 Leaal DescriDtion: Northina m IftUSl Eastina (XI IftUSl Surface: 4565 FSL 3630 FEL S19 T11N R12E UM 5959359.99 599043.01 Tie-In: 4565 FSL 3630 FEL S19 T11N R12E UM 5959360.02 599043.00 BHL: 2951 FSL2877FELS7T11NR12EUM 5968313.84 599642.33 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) Z -301Z-301Z -30AIZ-30A Generated 3/4/2004 2: 1 0 PM Page 2 of 2 ... 2875' ~ 13,186' Top of Window at 13,367' BP set at 13,416' 13,850' Z stump top 14,229' ~ Z-3ót Actual Completi~ -. ~.. 13-3/8", 68#, L-80 , _ ~ k27' L 14-1/2" 'X' nipple at.226{1'MD ACllIA TOR = KB. ELEV = iF. 'ELEV = KOP= Max Angle = Datum MD = Datum.1VD= BAKER 79.57 52.01' 1~383' 93.85@ 16210' '. 16600 .8891 GLM Design: TVD (KAii) SIZE K- 2899' 13254' - 4-1/2" X 1-1/2· ;JI/f - 4915' 17016' - 4-1/2· X 1-1/2" '11- 6506' 19983' - 4-112· X 1-112" ,4-fM ~ n.. 7753' 112405' - 4-1/2" X 1_1/2·,M.M6-- 111 ~8496/13775' ·4-1/2" X 1" Kß"-2. l ·'14-1/2", 12.6#, 13Cr-80, Tubing ~ c...A-t"""",- ~ .~ I'C M G. A.. K /JÞf.'1 MM~ ¡¿I( ð,..., ~K ß,t.., A.K 4""'''' 131< IJ'" '1 9-5/8" X 7" HMC Liner Hanger with ZXP _ J5 , ~ , Liner Tòp Packer and C2 Running Tool I . ,] ~I.( 2 - tlt'1 ~ ;u?II (1:6 ~ ?fI1·~ Tubing Tail: -10' Pup Joint -X Nipple (3.813") .:.2 x 10' Pup Joint -Packer -2 x 10' Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint· -XN Nipple (3.725") -10' Pup Joint -WLEG -<:: .::rd = 'J.' 7r" 7" X 4~1/2" S-3 Permanent Packer @ 13,863',1 7" X 4-1/2" HMC Liner Hanger \.\lj.tl't G' C^t.- @ 13,913' ,i'l'~c.. - I+~f )C. .N.'" -.z...ð = ]..'i'/7 "lor - HÇf XNN'-, ;:Z-(J ..3.7>.S" 17', 26#,L-80, BTC-M @ 14,034'1 1:?11~ - WLE¡;. -C:C = 1."'ir-y z £t;.oø-1ð ~ - = --:- - -~-'-~ _________ - . /br~~'- Pð117> ~/2", 12.6#, L-80, IBT-M Slotted Liner: 14,386-16,600 4-1/2" 12.6#, L-80, IBT-M Solid Liner: ~4,386 1~"j13 if . ~ 9-5/8",47#, L-80 ~"J. ¿/¡ID1 PRUDHOE BAY UNIT WELL: Z-30A API NO: 50-029-22013-01 Permit No: 203-219 GPB Rotarv Drillina 14,967' ~ ~ 5.5", 17#, L-80 Date Rev By Comments 12-1.5~03 NM Proposed Completion Design - P6 1-1-04 AM 160 Actual completion ., ~ ô Report Date: Client: field: Structure I Slot: Well: Borehole: UWIIAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NIE Y/x: Grid Convergence Angle: Grid Scale Factor: RECEIVED 8)C)3-ê).\'1 1 " ')n~ A , ¡. L.;.,·UI.j. f,jal}b~ Olj & Gas GOI1$. Comm~n Schlumberuer Z-30A Survey Report l;l:~:nt}mge Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 106.450° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: RKB TVD Reference Elevation: 79.6 ft relative to MSL Sea Bed I Ground Level Elevation: 54.000 ft relative to MSL Magnetic Declination: 25.134° Total Field Strength: 57557.065 nT Magnetic Dip: 80.799° Declination Date: January 22, 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North·) True North: +25.134° Local Coordinates Referenced To: Well Head January 27,2004 BP Exploration Alaska Prudhoe Bay Unit - WOA Z-PAD / Z-30 Z-30 Z -30A 50-029-22013-01 Z-30A TIP / January 22, 2004 333.544° /12629.05 ft /6.894/1.414 NAD27 Alaska State Planes, Zone 04, US Feet N 70 17 54.294, W 149 11 52.462 N 5959359.990 ftUS, E 599043.010 ftUS +0.75514597° 0.99991114 . Comments Measured Inclination Azimuth TVD Vertical NS EW Closure Closure DLS Tool Face Survey Tool Depth Section Azimuth Model (ft ) (deg) (deg) (ft) ( ft) (ft ) (ft ) (ft ) (deg) ( degJ100 ft) (deg) Tie-In 13341.75 58.88 3.54 8217.28 -3849.82 9495.36 -1210.48 9572.20 352.74 0.70 142.15G BP _GCT MS TOW 13367.00 58.77 3.64 8230.35 -3854.63 9516.92 -1209.13 9593.42 352.76 0.55 -51.74G BP _INC+TREND BOW 13383.00 60.09 1.73 8238.49 -3857.90 9530.68 -1208.49 9606.99 352.77 13.18 O.OOG BP _INC+TREND Mill Rat Hole 13399.00 60.09 1.73 8246.46 -3861.43 9544.54 -1208.07 9620.69 352.79 0.00 -172.23G BP _INC+TREND Interpolated Azi 13465.37 53.65 0.64 8282.72 -3876.03 9600.08 -1206.90 9675.64 352.83 9.80 -165.03G BP INC+TREND -176.57G BP ~MWD+IFR:A. 13560.09 48.58 358.83 8342.16 -3897.19 9673.78 -1207.20 9748.81 352.89 5.56 13652.89 44.16 358.45 8406.18 -3917.72 9740.91 -1208.79 9815.63 352.93 4.77 -178.35G BP _MWD+IFR:AK 13747.12 41.84 358.35 8475.09 -3937.63 9805.15 -1210.58 9879.60 352.96 2.46 150.77G BP _MWD+IFR:AK 13846.41 41.38 358.74 8549.33 -3957.91 9871.06 -1212.25 9945.22 353.00 0.53 89.62G BP _MWD+IFR:AK 13939.24 41.52 3.94 8618.93 -3973.91 9932.45 -1210.81 10005.98 353.05 3.71 76.50G BP _MWD+IFR:AK 13962.72 42.03 6.88 8636.44 -3976.90 9948.02 -1209.34 10021.25 353.07 8.62 64.72G BP _MWD+IFR:AK 14026.54 43.45 11.02 8683.32 -3982.53 9990.78 -1202.58 10062.90 353.14 4.93 48.61G BP _INC+TREND 14056.58 44.61 12.87 8704.92 -3984.17 10011.20 -1198.26 10082.66 353.17 5.76 51.59G BP_MWD 14088.10 48.45 19.05 8726.61 -3984.32 10033.16 -1191.94 10103.71 353.23 18.72 55.60G BP _MWD 14119.83 52.19 25.61 8746.88 -3981.79 10055.71 -1182.64 10125.01 353.29 19.79 57.54G BP _MWD Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 ~ ~~'Ì\ ~ \\\Z-30A TIP Generated 2/26/2004 4:41 PM Page 1 of 4 .. Comments Measured Inclination Azimuth TVD Vertical NS EW Closure Closure DLS Tool Face Survey Tool Depth Section Azimuth Model (ft) (deg) (deg) ( ft) (ft ) (ft ) (ft ) (ft ) (deg) ( deg/100 ft ) (deg) 14150.79 55.24 31.19 8765.21 -3976.60 10077 .63 -1170.75 10145.41 353.37 17.55 77.77G BP _MWD 14181.87 57.17 40.03 8782.52 -3968.12 10098.58 -1155.72 10164.50 353.47 24.43 65.50G BP _MWD 14212.24 59.28 45.15 8798.52 -3956.74 10117.57 -1138.25 10181.40 353.58 15.92 69.35G BP _MWD 14244.10 61.71 51.94 8814.22 -3942.00 10135.90 -1117.47 10197.31 353.71 20.05 55.15G BP _MWD 14275.09 65.12 57.18 8828.10 -3924.89 10151.94 -1094.90 10210.81 353.84 18.70 62.61G BP _MWD 14305.24 68.23 63.38 8840.04 -3905.72 10165.64 -1070.86 10221.89 353.99 21.51 53.11G BP_MWD 14337.64 72.16 68.76 8851.03 -3882.50 10177.98 -1043.01 10231.28 354.15 19.77 55.89G BP _MWD 14369.61 75.48 73.73 8859.94 -3857.42 10187.84 -1013.95 10238.17 354.32 18.18 57.87G BP MWD 14395.26 77.40 76.83 8865.95 -3836.09 10194.17 -989.84 10242.11 354.45 13.93 58.91G BP =MWD+IFR:Ae 14425.63 80.35 81.72 8871.82 -3809.59 10199.71 -960.57 10244.84 354.62 18.54 81.36G BP _MWD+IFR:AK 14457.17 80.91 85.33 8876.95 -3780.93 10203.21 -929.65 10245.48 354.79 11.43 93.36G BP _MWD+IFRAK 14488.60 80.76 88.10 8881.96 -3751.73 10204.99 -898.68 10244.49 354.97 8.71 80.95G BP _MWD+IFR:AK 14519.42 81.17 90.65 8886.80 -3722.64 10205.32 -868.25 10242.19 355.14 8.28 64.71G BP _MWD+IFRAK 14551.44 82.74 93.97 8891.28 -3691.90 10204.04 -836.57 10238.28 355.31 11.38 22.11 G BP _MWD+IFRAK 14582.36 85.12 94.94 8894.55 -3661.82 10201.66 -805.92 10233.44 355.48 8.31 3.15G BP _MWD+IFRAK 14614.47 87.66 95.08 8896.57 -3630.42 10198.86 -774.00 10228.18 355.66 7.92 33.41 G BP _MWD+IFRAK 14650.03 89.48 96.28 8897.46 -3595.50 10195.34 -738.63 10222.06 355.86 6.13 107.71G BP _MWD+IFR:AK 14681.85 89.03 97.69 8897.88 -3564.11 10191.47 -707.05 10215.97 356.03 4.65 99.72G BP _MWD+IFR:AK 14709.80 88.55 100.50 8898.47 -3536.40 10187.05 -679.46 10209.69 356.18 10.20 98.41G BP _MWD+IFR:AK 14740.04 87.97 104.45 8899.38 -3506.25 10180.52 -649.95 10201.25 356.35 13.20 77.32G BP _MWD+IFR:AK 14772.44 88.55 107.02 8900.37 -3473.87 10171.74 -618.78 10190.55 356.52 8.13 90.93G BP _MWD+IFR:AK 14802.35 88.52 108.91 8901 .13 -3443.99 10162.52 -590.34 10179.65 356.68 6.32 79.15G BP _MWD+IFR:AK 14835.70 89.17 112.29 8901.81 -3410.73 10150.79 -559.14 10166.18 356.85 10.32 88.70G BP MWD+IFRA. 14865.91 89.24 115.32 8902.22 -3380.78 10138.60 -531.50 10152.52 357.00 10.03 102.22G BP _MWD+IFR:A 14897.40 88.76 117.54 8902.77 -3349.77 10124.59 -503.31 10137.09 357.15 7.21 88.90G BP _MWD+IFR:AK 14929.66 88.83 121.07 8903.45 -3318.33 10108.80 -475.19 10119.97 357.31 10.94 89.43G BP _MWD+IFR:AK 14959.91 88.86 123.95 8904.06 -3289.27 10092.55 -449.69 10102.56 357.45 9.52 77.92G BP _MWD+IFR:AK 14991.28 89.34 126.19 8904.56 -3259.55 10074.53 -424.02 10083.45 357.59 7.30 73.11 G BP _MWD+IFR:AK 15026.29 89.75 127.54 8904.83 -3226.74 10053.53 -396.01 10061.32 357.74 4.03 114.55G BP _MWD+IFR:AK 15057.59 89.38 128.35 8905.07 -3197.62 10034.28 -371.33 10041 .15 357.88 2.85 77.37G BP _MWD+IFRAK 15084.67 89.51 128.93 8905.33 -3172.55 10017.37 -350.17 10023.49 358.00 2.19 10.62G BP _MWD+IFRAK 15118.01 89.99 129.02 8905.48 -3141.75 9996.40 -324.26 10001.66 358.14 1.46 110.79G BP _MWD+IFRAK Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 \\\Z-30A TIP Generated 2/26/20044:41 PM Page 2 of 4 Comments Measured Inclination Azimuth TVD Vertical NS EW Closure Closure DLS Tool Face Survey Tool Depth Section Azimuth Model ( ft) (deg) (deg) (ft ) (ft ) ( ft) (ft ) (ft ) (deg) ( deg/100 ft ) (deg) 15152.57 89.58 130.10 8905.61 -3109.96 9974.39 -297.61 9978.83 358.29 3.34 157.83G BP _MWD+IFR:AK 15178.82 89.31 130.21 8905.86 -3085.93 9957.47 -277.55 9961.33 358.40 1.11 60.03G BP _MWD+IFR:AK 15211.33 90.10 131.58 8906.03 -3056.34 9936.18 -252.98 9939.40 358.54 4.86 101.86G BP _MWD+IFR:AK 15246.51 89.89 132.58 8906.03 -3024.62 9912.61 -226.87 9915.20 358.69 2.90 -170.81G BP _MWD+IFR:AK 15272.75 89.21 132.47 8906.24 -3001.05 9894.87 -207.53 9897.05 358.80 2.63 122.84G BP _MWD+IFR:AK 15306.57 88.32 133.85 8906.97 -2970.85 9871.74 -182.87 9873.44 358.94 4.85 -84.24G BP _MWD+IFR:AK 15337.95 88.42 132.86 8907.86 -2942.87 9850.21 -160.06 9851.51 359.07 3.17 -177.51G BP _MWD+IFR:AK 15364.85 86.81 132.79 8908.98 -2918.80 9831.94 -140.35 9832.94 359.18 5.99 115.95G BP _MWD+IFR:AK 15399.66 85.74 135.00 8911.24 -2887.97 9807.86 -115.32 9808.54 359.33 7.04 -171.40G BP _MWD+IFR:Ae 15433.36 84.95 134.88 8913.98 -2858.45 9784.13 -91.54 9784.56 359.46 2.37 45.80G BP _MWD+IFR:AK 15459.45 85.95 135.91 8916.05 -2835.69 9765.62 -73.28 9765.89 359.57 5.49 -21.44G BP _MWD+IFR:AK 15492.34 87.12 135.45 8918.04 -2807.04 9742.13 -50.34 9742.26 359.70 3.82 -152.43G BP _MWD+IFR:AK 15522.11 86.26 135.00 8919.75 -2780.99 9721.03 -29.41 9721.08 359.83 3.26 129.07G BP _MWD+IFR:AK 15552.83 85.92 135.42 8921.85 -2754.13 9699.28 -7.82 9699.28 359.95 1.76 171.89G BP _MWD+IFR:AK 15586.19 85.85 135.43 8924.24 -2725.02 9675.58 15.54 9675.59 0.09 0.21 99.90G BP _MWD+IFR:AK 15615.89 85.68 136.41 8926.44 -2699.23 9654.30 36.14 9654.37 0.21 3.34 -160.41G BP _MWD+IFR:AK 15644.37 85.40 136.31 8928.65 -2674.62 9633.75 55.74 9633.91 0.33 1.04 54.41G BP _MWD+IFR:AK 15681.76 86.43 137.75 8931.31 -2642.51 9606.46 81.15 9606.81 0.48 4.73 -20.21G BP _MWD+IFR:AK 15710.50 88.25 137.08 8932.65 -2617.90 9585.33 100.58 9585.86 0.60 6.75 O.DOG BP _MWD+IFR:AK 15739.44 90.24 137.07 8933.03 -2593.00 9564.14 120.29 9564.90 0.72 6.88 2.03G BP _MWD+IFR:AK 15775.14 92.78 137.16 8932.09 -2562.30 9537.99 144.57 9539.09 0.87 7.12 -14.31G BP _MWD+IFR:AK 15805.04 93.68 136.93 8930.40 -2536.60 9516.14 164.91 9517.57 0.99 3.11 -98.45G BP _MWD+IFR:AK 15831.75 93.57 136.19 8928.72 -2513.54 9496.79 183.24 9498.56 1.11 2.80 -135.52G BP_MWD+IFR:A:' 15866.61 92.43 135.07 8926.89 -2483.15 9471.91 207.59 9474.18 1.26 4.58 125.44G BP _MWD+IFR:A 15898.72 92.06 135.59 8925.63 -2455.06 9449.09 230.14 9451.89 1.40 1.99 -81.03G BP _MWD+IFR:AK 15926.96 92.23 134.51 8924.58 -2430.28 9429.12 250.08 9432.43 1.52 3.87 176.64G BP _MWD+IFR:AK 15961.08 92.06 134.52 8923.30 -2400.19 9405.21 274.39 9409.21 1.67 0.50 66.36G BP _MWD+IFR:AK 15991.99 92.51 135.55 8922.07 -2373.07 9383.36 296.22 9388.03 1.81 3.63 40.38G BP _MWD+IFR:AK 16021.18 93.05 136.01 8920.65 -2347.65 9362.46 316.55 9367.81 1.94 2.43 95.90G BP _MWD+IFR:AK 16054.69 92.99 136.59 8918.89 -2318.63 9338.27 339.67 9344.45 2.08 1.74 143.16G BP _MWD+IFR:AK 16086.42 92.71 136.80 8917.31 -2291.25 9315.21 361.41 9322.22 2.22 1.10 168.12G BP _MWD+IFR:AK 16113.61 92.33 136.88 8916.11 -2267.82 9295.39 379.99 9303.16 2.34 1.43 -140.56G BP _MWD+IFR:AK 16147.38 91.54 136.23 8914.97 -2238.62 9270.89 403.20 9279.65 2.49 3.03 65.64G BP _MWD+IFR:AK Version DO 3.1RT (do31rt_546) 3.1RT-SP3.03 \\\Z-30A TIP Generated 2/26/2004 4:41 PM Page 3 of 4 .. Comments Measured Inclination Azimuth TVD Vertical NS EW Closure Closure DLS Tool Face Survey Tool Depth Sectio n Azimuth Model (ft) (deg) (deg) (ft ) (ft) (ft ) (ft ) (ft ) (deg) ( deg/100 ft ) (deg) 16179.58 91.92 137.07 8914.00 -2210.81 9247.49 425.29 9257.26 2.63 2.86 -36.66G BP _MWD+IFR:AK 16210.16 93.85 135.63 8912.46 -2184.33 9225.39 446.37 9236.18 2.77 7.87 -109.21G BP _MWD+IFR:AK 16241.97 93.77 135.40 8910.35 -2156.59 9202.75 468.61 9214.67 2.92 0.76 120.86G BP _MWD+IFR:AK 16274.67 93.40 136.02 8908.30 -2128.12 9179.38 491.40 9192.53 3.06 2.20 147.56G BP _MWD+IFR:AK 16304.56 92.85 136.37 8906.67 -2102.21 9157.84 512.06 9172.15 3.20 2.18 140.35G BP _MWD+IFR:AK 16340.03 92.44 136.71 8905.04 -2071.55 9132.13 536.43 9147.87 3.36 1.50 -28.73G BP _MWD+IFR:AK 16371.02 92.95 136.43 8903.58 -2044.77 9109.65 557.71 9126.70 3.50 1.88 -69.89G BP _MWD+IFR:AK 16400.17 93.53 134.84 8901.93 -2019.37 9088.84 578.06 9107.20 3.64 5.80 99.45G BP _MWD+IFR:A. 16435.65 93.36 135.86 8899.80 -1988.36 9063.65 602.95 9083.68 3.81 2.91 -105.28G BP _MWD+IFR:A 16467.10 93.33 135.75 8897.96 -1961.00 9041.14 624.84 9062.70 3.95 0.36 106.16G BP _MWD+IFR:AK 16495.26 93.22 136.13 8896.36 -1936.52 9020.93 644.39 9043.92 4.09 1.40 -149.29G BP _MWD+IFR:AK 16527.29 92.85 135.91 8894.66 -1908.71 8997.92 666.60 9022.57 4.24 1.34 -131.79G BP _MWD+IFR:AK 16546.50 92.60 135.63 8893.75 -1891.98 8984.17 679.98 9009.86 4.33 1.95 O.OOG BP _MWD+IFR:AK Project to TD 16600.00 92.60 135.63 8891.32 -1845.31 8945.96 717.36 8974.68 4.58 0.00 O.OOG BP _BLIND Survey Type: Raw Survey NOTES: Only depth error sources are used from surface to mud-line. . Version DO 3.1RT (do31rt_546) 3.1RT-SP3.03 \\\Z-30A TIP Generated 2/2612004 4:41 PM Page 4 of 4 . . ¿jcY3 -ë) ( ~ Schlumberger Drilling & Measurements MWD/lWD log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No Z-30A Date Dispatched: 19-Dec-03 Installation/Rig Nabors 7ES Dispatched By: F.Alabi Data No Of Prints No of Floppies Surveys 2 RECEIVED . ~J 2004 Received By: ,,¡ti~rQ¡ ('t! ~, (';§\'i¡ r\ ;f\nc C··O ffiMI'6II1... í" ",. f:c",I,..,~.'r.tf ", ¡¡",>: 'UtA'.,p' ,.:,-....~u~~ , J ,I wN ii .f.,. '''...........''''. Me þ,,', (J :~:}~ <i:fW:1 ..".~ " ~_ Please sign and return to: James H. Johnson ~:~"'-À~\'').. S f'...e.. Ä.r:!'~ BP Exploration (Alaska) Inc. Petrotechnical Oata Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private ~~~,,\~ · ....::;¡ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe bay Unit Z-30A Pennit No: 203-219 Surface Location: 714' SNL, 1323' EWL, Sec. 19, TIIN, R12E, UM Bottomhole Location: 2956' NSL, 2054' EWL, Sec. 07, TIIN, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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,. .. U// . - ¿:: A./ ð~> -...1\ Sarah Palin \J Chair BY ORDER 9:Ji1 THE COMMISSION DATED this~day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA _ ALASKA 0,. ND GAS CONSERVATION COM_SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IHI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 16890 TVD 8899 7. Property Designation: ADL 047450 o Drill IBI Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 714' SNL, 1323' EWL, SEC. 19, T11N, R12E, UM Top of Productive Horizon: 4332' NSL, 318' EWL, SEC. 07, T11N, R12E, UM Total Depth: 2956' NSL, 2054' EWL, SEC. 07, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-599043 Y-5959360 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18. Casing Program Size CasinQ 7" Hole 8-1/2" 6-1/8" 13428 ft Maximum Hole Angle Specifications Grade CouplinQ L-80 BTC-M L-80 IBT-M 4-1/2" WeiQht 26# 12.6# WGir t L/ ¿4 l..OCí3 ./ IBI Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU Z-30A / 12. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: January 15, 2004 / 14. Distance to Nearest Property: 11,000 9. Acres in Property: 2560 92° 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): Plan = 82' feet Z-27 is 430' away 17. Anticipated pressure (see 20 AAC 25.035) / Max. Downhole Pressure: 3775 psig. Max. Surface Pressure: 2915 psig Setting Depth Quantity of Cement Top Bottom (c.f. or sacks) MD TVD MD TVD (including stage data) 13250' 8174' 14092' 8718' 213 cu ft Class 'G' 14000' 8570' 16890' 8899' Uncemented Slotted Liner LenQth 842' 2890' PRËSENT WELL..· CONDITION SUMMARY (To bècoI'I'Íþlèfed for RedriIIANDRè..;entrYOpefafions) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Depth TVD 14970 9100 NIA 14885 9058 Structural Conductor 110' 30" 110' 110' Surface 2874' 13-3/8" 4009 cu ft Permafrost 2874' 2674' Intermediate 14229' 9-5/8" 3209 cu ft Class 'G' 14229' 8701' Production Liner 990' 5-1/2" 431 cu ft Class 'G' 13980' - 14970' 8560' - 9100' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Signature 1--.J 1L. L L . Phone 564-5521 Commission Use Only 16:~~it APprov,IZIZ2M ~~co;~~:;;~ o Yes ~ No Mud Log ReqUire~r ít{ -~ I ~ Ifiji;. U .I8J Yes 0 No Directional Survey ReqUiredOE~ ¡eb 2b~~ Perforation Depth MD (ft): 14606' - 14650' 20. Attachments IHI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch Permit To Drill I API Number: Number:Zo3- 2-/'1 50-029-22013-01-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other:Tes.\- BoP E +0 '3500 ps/. Original Sfgned 8y Sarah Pälln Approved By: ants 8Ft OFC 2S JIl~ Form 10-401 Revised 3/2003 IPerfOration Depth TVD (ft): 8912' - 8936' IHI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IHI Drilling Fluid Program 1H120 AAC 25.050 Requirements Date: Contact Neil Magee, 564-5119 Date 11(¡a/ðJ Prepared By Name/Number: Terrie Hubble, 564-4628 Alaska Oil & Gas Cons. Commission Anchorage . Date /2/Zlh0 Submit In &~I¡{ate BY ORDER OF LJ~fbrrJ ATL COMMISSION e IWell Name: IZ-30A e I Drill and Complete Summary I Type of Redrill (producer or injector): I Producer Surface Location: X = 599,043.01 / Y = 5,959,359.99 714' FNL, 3629' FEL, See 19, T11N, R12E KOP: X = 597,709.79 / Y = 5,968,880.56 1736' FNL, 4799' FEL, See 7 T11 N, R12E Target Location: X = 597,904.00 / Y = 5,969,671.00 94WFNL,459~FEL,Sec7,T11N,R12E Bottom Hole Location: X = 599,657.98 / Y = 5,968,319.00 232~FNL,2861'FEL,Sec7,T11N,R12E I AFE Number: 1 PBD4P2166 I I Estimated Start Date: 11/15/04 /'1 I MD: 116,890' 1 I TVD: 18899' I Rig: 1 Nabors 7ES ""- I Operating days to complete: 121.0 I Cellar Elevation: 154' 1 RKB: 182' I Well Design (conventional, slim hole, etc.): I Conventional Big Bore - 9-5/8" Sidetrack I Objective: 1 Complete as Zone 4B,45,46P Horizontal Producer to replace original wellbore. Productive Interval is 550' away from nearest wellbore Z-27 at 15,800' in the Z-30A wellbore The well approaches to within 11,000' of nearest Prudhoe Bay property line. Formation Markers Formation Tops MD TMLV Top Kingak (JG) Top Kingak (JF) Top Kingak (JE) Top Kingak (JD) Top Kingak (JC) Top Kingak (JB) Fault No.1 Sag River Shublik Top Eileen TSAD (TZ4B) 45N 45P POWC at Heel OOWC TVDss 6840' 7547' 7765' 8024' 8143' 8278' 8461' 8525' 8635' 8654' 8791' 8806' 8838' 8841' 8900' 8960' Comments /-; 3775 psi @8600' TVDss «8.4-ppg EMW) ~ /'" 3700 psV(8'yppg EMW) Hydrocarbon Bearing Hydroca~ Bearing Hydrocarbon Bearing Hydrocarbon Bearing * Static pressures from offset wells Z-30, Z-31 , Z-27 and Z-21 A indicate a 8.0 to 8.4 ppg equivalent pressures in the Sadlerochit Zone 48 at about 8800' TVD ss. Z-30A Well Plan (AOGCC) Page 1 e Casingrrubing Program Hole Size Csg/ WtlFt Tbg O.D. 8-1/2" 7" 26# 6-1/8" 4-1/2" Slotted 12.6# Tubing 4-1/2" 12.6# 7" Burst 7,240 psi, Collapse 5410 psi Directional KOP: (P6) I -13,428' MD Maximum Hole Angle: Close Approach Well: Survey Program: e Grade I L-80 L-BO 13Cr Top MDrrVD 13,250' 18174' 14,000' 18570' GL Btm MDrrVD 14,092' 18718' 16,890' I 8899' 14,000' 18570' Conn / BTC-Mod IßT-Mod VAM ACE Length -842' -2,890' -14,000' -920 through Reservoir section All wells pass BP Close Approach guidelines. Standard MWD Surveys from kick-off to TO. (IFR+MSA Survey Correction) Mud Program Viscosity Sidetrack Interval Mud Properties: LSND Fluid 8 1/2" hole R!:!. Density /) 11.6C::&/ 45-60 Plastic Viscositv 8-10 Yield Point (lb/1 OOft¿) 25 - 35 CI Fluid Loss 15 - 18K API <8 8.5-9.5 production Interval Mud Properties: FloPro Fluid 61/8" hole FloPro Densitv Be Plastic Viscosity 12 - 18 Yield Point (lb/100ff) 20 - 25 MBT Fluid Loss R!:!. <3 4-6 8.5-9.0 Hydraulics: Intermediate Hole: 8-1/2" Interval Pump Drill AV (fpm) Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe ppg-emw ("/32) (in2) 13,400' - 550 5" 19.5# 270 3300 12.6 N/A 6 x14 0.902 14,092' Production Hole: 6 1/8" Interval Pump Drill Pipe AV (fpm) Pump PSI ECD Motor Jet Nozzles TFA GPM ppg-emw ("/32) (in2) 14,092' - 275 5" 19.5# 135 2100 9.5 N/A 6x10 .460 16,890' 4" 15.7# Z-30A Well Plan (AOGCC) Page 2 e e Logging Program 81h" Intermediate: Drilling: MWD IGR /Res I PWD - Realtime over entire interval. No sample catchers. Open Hole: No open hole logs are planned. Cased Hole: No cased hole logs are planned. 6-1/8" Production: Drilling: MWD IGR IRes I PWD - Realtime over entire interval. Sample catchers as per on-site Geologist. Open Hole: No open hole logs are planned. Cased Hole: No cased hole logs are planned. Cement Program (Preliminary) Estimated Bottom Hole Static Temperature=:: 220F Casing Size I 7" Drilling Liner I Basis: I Lead: Based on 690' open hole with 30% excess, 82' 7" shoe joint, 150' liner lap and 200' cement across 5" x 9-5/8" annulus volume. Fluid Sequence & Volumes: Pre None Flush Spacer 20 bbls MUdPUS..æ·, cosified Spacer weighted to 12.1 ppg Tail ~1/213 fe 1 8 sks of Dowell Premium 'G' at 15.8 ppg and .1 uftlsk. (us ctual circulating temps recorded by MWD at '- * The 7" slurry assumes a fracture gradient at the 7" shoe (TSAG) of 13.2 ppg. Z-30A Well Plan (AOGCC) Page 3 e e Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 3775 psi @ 8600' TVDss - Top Sag River · Maximum suñace pressure: 2915 psi @' surface (based on BHP and a full column of gas from TD @ 0.10 psilft) .,/ · Planned BOP test pressure: · Planned completion fluid: 3500 psi / 8.6 ppg seawater / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Z-30A Well Plan (AOGCC) Page 4 e e Sidetrack and Complete Procedure Summary Pre-Ria Work: Well Condition (12/9/03): Well was killed and freeze protected with 60/40 methanol on 1/11/03. Tubing is collapsed at approximately 13,884' as indicated by last LIB and video log run 12/16/2002. 9-5/8" pack-off failed pressure test on 9/16/02. "Primary seal is leaking-secondary seal is holding". Description of pre-rig work required. 1. Record SITP and IA pressure. 2. Pull Otis SSSV at 2114' if present. Drift the 4-1/2" tubing to collapse point at 13,884'SLM - collapsed tubing point Ensure no ice is present in the tubing.. 3. Replace all live GL V's with dummy GL V's. 4. RIH with Schlumberger string shot and chemical cutter for 4-1/2" tubing Cut the tubing at approximately 13,860'. 5. Circulate the well to seawater and record SITP and IA pressure. (Contact ODE to discuss pressures recorded if seawater not sufficient to kill well.) Plan on immediately freeze protecting well if seawater provided sufficient hydrostatic pressure. Well should be freeze protected to 2100' with diesel in tubing and annulus. 6. Function test all tubing hanger lockdown screws on the wellhead by backing out and re-torquing one at a time. 9-5/8" Pack-off failed test (9/17/02) No indication that tubing hanger seals have been tested. LDS checked and torqued to 650 ft-Ibs (9/17/02) 7. Set BPV in tubing hanger and secure well. 8. Prior to rig arrival remove well house and flowlines. If necessary level the pad and dig out the cellar. 9. Provide total cumulative cost to BP Drilling Supervisor on Handover. Summary of Ria Operations: 1. MIRU Nabors 7ES. Circulate out freeze protection and displace well to 8.4 ppg seawater. Pre-Rig work may indicate a higher weight brine is required to kill well. (Fo~tion pressure expected to be 8.1 ppg.) Set TWC. 2. Nipple down tree. Nipple up and test BOPE to 3500 psi. 3. Pull and lay down 3-1/2" tubing from cut. 4. M/U 8-1/2" milling BHA. RIH PU drillpipe and drift down to remaining tubing stub. POOH. 5. RIH with EZSV on e-line and set at approximately 13,420'. Pressure test to 3500 psi. ./ 6. Replace and test 9-5/8" mandrel hanger pack-off to 5000 psi. 7. RIH with 9-5/8" (47 Ib/ft) Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Change well over to 11.6 ppg LSND milling/drilling mud. Mill window in 9-5/8" casing at -13,400' MD. Prior to/ POH, perform FIT to 13.0 ppg EMW. 8. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate /' section to Top Sag @ ±14,092' MD (8717' TVD). 9. Run and cement 7",26# intermediate drilling liner to -150' back into window. POH. 10. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/ABI). Pressure test casing to 3500 psi. Drill landing collar and clean out shoe track. Swap mud over to 8.8 ppg FloPro drill in fluid. .,/ 11. Drill 20' of new formation. Conduct FIT to 10.5 ppg EMW. / 12. Drill 6-1/8" production section as per directional plan to an estimated TD of 16,890' MD (8899' TVD). 13. Run 4 %,', 12.6# L-80 slotted production liner throughout the 6-1/8" wellbore. Displace to clean seawater above liner top. POH LD excess drill pipe. 14. Run a 4-1/2", 12.6# 13Cr Vam Ace completion tying into the 4-1/2" liner top. / 15. Set packer and test the tubing and annulus to 3500 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to -2200' TVD and secure the well. 18. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below production packer. Install gas lift valves. Z-30A Well Plan (AOGCC) Page 5 e e Job 1: MIRU Hazards and Contingencies > Two wells will require shut-in for the rig move to Z-30A. The two adjacent wells Z-29 (producer) and Z-31 (injector) are both approximately 35' from the Z-30 wellhead. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. > None of the current producers on Z-Pad indicate the presence of H2S, however Standard Operating Procedures for H2S precautions should be followed at all times. Reference RPs .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" SOP _~~-m;.w.,-.. Job 2: Decomplete Well HazardsandConHngencres > Z-30A is currently shut in. The tubing string should be cut and dummy GLV's installed. Prior to pulling the completion monitor the well closely for any signs of underbalance and have additional brine weight up material available on site > The 9-5/8" pack-off failed a 5000 psi pressure test on 9/17/02. > Note and record PU weight to pull tubing from cut point. > NORM inspect all equipment laid down and report readings on Morning Report. Reference RPs .:. "Decompletions" RP Job 3: Run Whipstock Hazards and Contingencies > Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. > After setting the bridge plug, the 9-5/8" mandrel will have to be replaced. Replace pack-off through the stack. > Top of cement in 9-5/8" annulus is expected at 6800' to 7900'. Reference RPs .:. "Whipstock Sidetracks" RP .:. "Leak Off and Formation Integrity Tests" SOP Job 5: Drill 8%" Intermediate Hole Hazards and ConHngencres > Z Pad has a limited history of wellbore stability problems within the Kingak shales and of the problems encountered, minor incidents of tight hole and packing off have been the main problems. Stuck pipe incidents are noted on the pad data sheet. Correct selection of mud weight is critical to ensure Kingak Z-30A Well Plan (AOGCC) Page 6 · e shale stability. Problems have been encountered in both high and low angle wells, however high angle wells have been most problematic. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. >- A mud weight of 11.6 ppg has been picked for drilling this Kingak interval. This is based on the inclination and azimuth of the well applied to the Kingak Polar plot. >- Extreme care should be taken when picking the 7" casing point. Lost circulation may be seen when the Sag River is penetrated. >- Z-30A is expected to penetrate a fault in the in the lower Kingak at approximately 8525> TVD ss. The estimated throw of this fault is 15' and is not expected to be of significant concern. This fault was previously in the original wellbore, Z-30 without incident. >- The kick tolerance for the 8%" open hole section would be infinite assuming a kick from the Sag River at -8,600' TVD ss. This is based on an 8.4 ppg pore pressure, a fracture gradient in excess of 13.0 ppg at the 9-5/8" window and 11.6 ppg mud in the hole. >- Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is Z-19 which is -372' center-to-center at 16,169' MD. Reference RPs .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. Standard Operating Procedure: Leak-off and Formation Integrity Tests Job 6: Install 7" Intermediate Liner Hazards and Contingencies >- Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could exacerbate Kingak instability problems. >- Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RPs .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies >- Z-30A is expected to penetrate one fault in the in the production hole at 14,700' MD (8820' TVD). The estimated throw of this fault is 10' and will be crossed at approximately 90 deg to the strike of the fault. >- Z Pad has a history of lost circulation events while drilling in the Sadlerochit reservoir section. Losses have ranged from minor to severe (-6,000 barrels). All cases of severe losses have been fault related and were managed by pumping fiberous/carbonate LCM pills. Be prepared for losses by establishing a contingency plan and consulting the Lost Circulation Contingency plan attached. >- To the East side of the wellbore is a complex series of faults The target polygon hardline is designed to maintain 150' standoff from this region. Z-30A Well Plan (AOGCC) Page 7 e tit > The kick tolerance is infinite for the 6-1/8" open hole section assuming a kick from Zone 4B at -8,800' TVD ss. This is based on an 8.4 ppg pore pressure, a minimum fracture gradient of 10.5 ppg at the 7" shoe, and 8.8 ppg mud in the hole. > Drilling Close Approach: All wells pass BP Close Approach guidelines. )0> There are no restrictions concerning adding lubricants to the mud whilst drilling the production hole section. LubetexlFlolube concentrations of 1.5+% and 1% EP Mudlube are needed to improve weight transfer in critical kick-off section. )0> Under no circumstances add any LCM (including Walnut sweeps, cellulose material) other than calcium carbonate for losses < 50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses> 50 BPH may include the use of cellulose material to arrest losses. See LCM discussion in MI Mud Program. )0> Expect a certain amount of geo-steering , but significant changes to the planned directional profile should be discussed with the Drilling Manager/Operations Drilling Engineer. Reference RPs .:. "Standard Operating Procedure for Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP \'\)_ =~.~~x" Job 9: Install 4%" Production Liner Hazards and Contingencies > Differential sticking could be a problem. The 8.8 ppg FloPro will be -300 psi over-balanced to the Sadlerochit formation. Minimize the time the pipe is left stationary while running the liner. Reference RPs .:. "Modified Conventional Liner Cementing" RP '''mm''^,,~;''~ ,__ Job 12: Run Completion Hazards and Contingencies > Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. > Watch hole fill closely and verify proper safety valves are on the rig floor while running the completion. Reference RPs .:. "Completion Design and Running" RP .:. "Tubing connections" RP .:. Running and handling 13Cr. ="'~~ "'---, "" '''~" ,,,,,,,Á';m;x~,, Z-30A Well Plan (AOGCC) Page 8 e e Job 13: ND/NUlRelease RiQ Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. Reference RPs .:. "Freeze Protecting an Inner Annulus" RP Z-30A Well Plan (AOGCC) Page 9 e e Z-30A Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Decompletion: · Tubing may be NORM contaminated. Ensure tubing, hanger and completion jewelry is . checked for radiation. · 9-5/8" casing pack-off will not pressure test. Plans are to replace pack-off after tubing is recovered and bridge plug is set in well. Intermediate Hole Section: · The intermediate hole section will be drilled with a mud weight of 11.6 ppg to ensure Kingak shale stability. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the Kingak shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. · Extreme care must be taken when picking the 7" casing point - Top Sag. Lost circulation is possible when this subnormal pressure formation is encountered. · Z-30A is expected to cross one fault in the intermediate hole section. The approximate location of the fault is 8525'TVD ss and has an estimated throw of 10'. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. Production Hole Section: · Mud losses of up to 100 bph have been encountered in offset horizontal sections. All cases of severe losses were fault related and were treated with fiberous/carbonate LCM pills. Contingency LCM material and mud product should be available at the rigsite/mud plant. · The Eastern target polygon maintains at least a 150' separation from numerous faults in the area. Careful directional control will be required. · One fault is expected to be crossed in the production hole interval. The approximate location is 14,700' MD. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S / . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies DATE 03/11/90 02/04/91 03/08/01 03/14/01 05/19/01 COMMENTS ORIGINAL COMPLETION RNO RECOMPLETION SIS-QAA CONVERTEDTOCANVAS SIS-MD FINAL RN/TP CORRECTIONS REV BY DFF SEe BP Exploration (Alaska) PRUDHOE BAY UNrr WELL: 2-30 ÆRMrr No; 1900230 API No: 50-029-22013-00 19, T11N, R12E, 714' FNL & 3648' FEL DATE REV BY COMMENTS 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" PBTD H H 14967' 14885' -, ~ UNKNOWN-14-7/8" X 3/4" X DEPTH Note: SIZE 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" ANGLE AT TOP PERF: 56 @ 14606' Refer to Production DB for historical perf data SPF INTERVAL Opn/Sqz DATE 4 14606-14622 0 03/11/90 4 14634 - 14654 0 03/11/90 4 14668 - 14684 0 03/11/90 4 14688-14735 0 03/11/90 4 14745 - 14764 0 03/11/90 4 14773 - 14795 0 03/11/90 6 14580 - 14650 0 04/17/91 118" 0M-1 SPRING 01/01/96 PERFORATION SUMMARY REF LOG: HLS BHCS ON 03/03/90 14352' H MARKER JOINT 9-5/8" CSG, 47#, L-80, ID = 8.681 H 14229' ~ ~ .0152 bpf, TOP OF 5-1/2" LNR H H 13973' 13980' I 13973' 13987' J H ELMD TT LOGGED 08/12/92 4-1/2 "TBG, 12.6#, L-80, ID = 3.958" 13949' 13961 4-1/2" WLEG, ID = 3.958" H4-1/2" PARKER SWS NIP, ID = 3.813" H4-1/2" PARKER SWN NIP, ID = 3.725" :8: ~ Collapsed Tubing at 13,864' MD ( 13924' 13912' H9-5/8" x 4-112" BKR, PKR H4-1/2" PARKERSWS NIP, ID= 3.813" Minimum ID = 3.725" @13961' 4-1/2" PARKER SWN NIPPLE L 13-3/8" CSG, 68#, L-80, ID = 12.415" H 2875' r--4 ST 6 5 4 3 2 1 ~ MD lVD 3398 2891 8298 5506 10881 6882 12290 7614 13308 8116 13889 8422 GAS LIFT MANDRELS DEV TYPE VLV LATCH 55 MERLA RK 56 MERLA RK 58 MERLA RK 56 MERLA RK 59 MERLA RK 57 MERLA RK TREE:;: 4-1/16" FMC WELLHEAD = FMC ACTUA TOR;;-~ BAKER ·~·_·___~~~~N'~N~ KB. ELEV = 88.66' =~~~, BF. ELEV = 52.01' =~~~~~~~~~~~~-~~ KOP= 1300' ~~N~~~~ M _~~^., Max Angle = 60 @ 14825' Datum MD = 14727' Dãtu"m lVD = "~·~·ã80ÒõSS . 2114' PORT H4-1/2" OTIS SSSV NIP, ID = 3.813" DATE e Z-30 / S~TES 2875' ~ _ ~3-3/8". 68#, L-BO ..J 14-1/2" 'X' nipple at 2200' MD I Z-30_ Proposed Com~tion ACTUATOR =------SAKER "K.s. ~~-:~~.:. ~..~=~'m~~:~: SF. ELEV = 52.01' ='="""'=NN.w.·.,·_·,~",-".-~y.-m=N"W".'=mm",_·_~"".",,_,.·hW=-.'~"=m,','~., KOP = . 13428' Ivìì:ïx'Angíe = ,mww'92@'illöÜ' Datum'rvìÖ-;w-, "W~~_ ~~·^"~A'~~mm~,,~~.w.·.m~,~___w,_~_~,,~~^ DatumTVD= l 14-1/2",12.6#, 13Cr-80, Tubing GLM Design: #5 - ????' TVD - 4-1/2" X 1-1/2" #4 - ????' TVD - 4-1/2" X 1-1/2" #3 - ????' TVD - 4-1/2" X 1-1/2" #2 - ????' TVD - 4-1/2" X 1-1/2" #1 - 1 jt above packer - 4-1/2" X 1" 13,250' ..J 9-5/8" X 7" HMC Liner Hanger with ZXP / Liner Top Packer and C2 Running Tool -<::: 13,924' :8: ::8: . 7" X 4-1/2" S-3 Permanent Packer @ 13,940' I 7" X 4-1/2" HMC Liner Hanger with ZXP Liner Top Packer and C2 Running Tool @ 14,000' Top of Window a~ 13,400' 17',26#, L-80, BTC-M @ 14,092' 1 Tubing Tail: -10' Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint -Packer -2 x 10' Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG BP set at /13,420' I " . :I / ~ ..... 14 229' ~ , ~ 9-5/8",47#, L-80 4-112", 12.6#, L-80, IBT-M Slotted Liner @ 16,890' 14,967' ~ ~ 5.5", 17#, L-80 Date 12-15-03 Rev By Comments NM Proposed Completion Design - P6 PRUDHOE BAY UNIT WELL: Z-30A API NO: 50-029-22013-01 Permit No: GPB Rotary Drilling Report Date: Client: Field: Structure I Slot: Well: Borehole: UWl/API#: Survey Name I Date: Tort I AHD I DOlI ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: Z-30A (P6) Proposal December 4, 2003 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA d Vertical Section Origin: Z-PAD/Z-30 rÐ st~1III Y TVDReferenceDatum: Z-30 rÐ ~ ~ IlII m"" fíbIIII TVD Reference Elevation: Z-30A f·· tõì~@Dl.Q,Iu[' ßJ1 Sea Bed I Ground Level Elevation: 500292201301 ~ Magnetic Declination: Z-30A (P6) I December 3, 2003 Total Field Strength: 318.296° 112913,45 11/6,891/1.447 Magnetic Dip: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: N 70.29841498, W 149,19790604 Magnetic Declination Model: N 5959359,990 IIUS, E 599043,010 IIUS North Reference: -t{),75514597" Total COlT Mag North·) True North: 0,99991114 Local Coordinates Referenced To: Schlumberger Minimum Curvature / Lubinski 106.450° N 0,000 II, E 0,000 II Rotary Table 82,70 II relative to MSL 54,16 II relative to MSL 25,134° 57557,040 nT 80.799° January 22, 2004 BGGM 2003 True North +25,134° Well Head e Comments Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Latijude . Longitude Depth Section (It) (deg) (deg ) (It) (It) (It) (It) (It) ( deg/100 It ) ( deg/100 It ) ( deg/100 It ) (deg) (ltUS) (ltUS) Tie-In Survey 13378,54 58,73 3,67 8237.82 8155.16 -3856,23 9524,20 -1208.66 0,55 -0.45 0.39 -124,79G 5968866.63 597709.05 N 70.32443422 W 149.20770544 Top Whipstock 13400.00 58.71 3.64 8248,96 8166,30 -3860.30 9542.50 -1207.49 0.16 -0,09 -0,15 O,OOG 5968884.94 597709.97 N 70.32448423 W 149.20769599 Base Whipstock 13416,00 60,63 3.64 8257,04 8174,38 -3863,36 9556,28 -1206,62 12,00 12,00 0.00 O,OOG 5968898.73 597710.67 N 70.32452188 W 149,20768890 KOP Cry 6/100 13428,00 60,63 3.64 8262.93 8180,27 -3865,68 9566.72 -1205.95 0,00 0.00 0.00 173,70G 5968909.18 597711.19 N 70.32455039 W 149,20768353 13500,00 56,34 4.21 8300,56 8217,90 -3879,02 9628.00 -1201.77 6,00 -5.96 0.79 173,40G 5968970.44 597714.58 N 70.32471765 W 149.20764963 13600.00 50,38 5.10 8360.21 8277.55 -3895.43 9707.94 -1195,28 6,00 -5.96 0.89 172,86G 5969050.45 597720.01 N 70,32493604 W 149.20759716 TJC 13600.71 50,34 5.11 8360,66 8278,00 -3895.54 9708.48 -1195,23 6,00 -5.95 0.97 172.86G 5969051.00 597720.05 N 70.32493752 W 149,20759677 13700.00 44,43 6,16 8427,86 8345.20 -3909.28 9781,17 -1188,09 6,00 -5.95 1.06 172.14G 5969123.77 597726,23 N 70.32513610 W 149,20753896 End Cry 13735,91 42,30 6.60 8453,97 8371,31 -3913.57 9805,62 -1185,35 6.00 -5.94 1.22 O,OOG 5969148.30 597728,65 N 70.32520305 W 149,20751678 TJB 13857,18 42,30 6.60 8543.66 8461.00 -3927,55 9886.75 -1175,97 0,00 0.00 0,00 O.OOG 5969229.48 597736.96 N 70.32542453 W 149,20744080 Fault Crossing 13943,71 42.30 6,60 8607,66 8525.00 -3937,51 9944.59 -1169,27 0,00 0.00 0.00 O,OOG 5969287,41 597742.89 N 70,32558257 W 149.20738659 Sag River 14092.43 42,30 6,60 8717.66 8635,00 -3954,63 10044.02 -1157,77 0,00 0.00 0.00 O,OOG 5969386,96 597753.09 N 70,32585419 W 149,20729341 7" Csg pt 14092.44 42,30 6.60 8717,67 8635,01 -3954,63 10044,03 -1157,77 0,00 0,00 0,00 O,OOG 5969386.97 597753.09 N 70,32585421 W 149.20_ KOP Cry 15/100 14111,08 42,30 6.60 8731.45 8648,79 -3956,75 10056.42 -1156,32 0.00 0,00 0,00 50.07G 5969399.45 597754.37 N 70.32588825 W 149.20 Shublik 14118,15 42.99 7,8 8736,66 8654 -3957,54 10061,24 -1155,72 15 9.72 16.87 49,19G 5969404,21 597754.90 N 70.32590124 W 149.207 6 14200,00 51,68 19.63 8792.18 8709.52 -3959,97 10119,35 -1141,09 15,00 10.55 14.65 41.13G 5969462,50 597768.76 N 70.32605999 W 149.20715831 14300,00 63.52 30,60 8845.79 8763.13 -3946,77 10195.25 -1104,93 15.00 11.83 10.96 35.21G 5969538.87 597803.93 N 70.32626737 W 149.20686514 Eileen 14375,02 72.86 37.36 8873.66 8791,00 -3925,71 10252.82 -1065,96 15,00 12,46 9,01 32.69G 5969596,94 597842.13 N 70.32642467 W 149.20654926 14400,00 76.03 39.44 8880.36 8797.70 -3916,71 10271.68 -1051,01 15.00 12,51 8.85 32.13G 5969615.99 597856.82 N 70,32647618 W 149.20642807 TSAD / TZ4B 14442,49 81.44 42.87 8888,66 8806.00 -3899,29 10303.03 -1023,59 15.00 12.75 8.06 31.46G 5969647.70 597883.83 N 70.32656185 W 149.20620575 End Cry 14455.70 83.14 43.91 8890.43 8807.77 -3893,34 10312.48 -1014,59 15.00 12.77 8,01 O.OOG 5969657.33 597892.69 N 70.32658783 W 149.20613286 Cry 15/100 14455,88 83,14 43,91 8890,45 8807,79 -3893.26 10312,61 -1014.47 0,00 0,00 0,00 78.05G 5969657.46 597892.81 N 70.32658818 W 149.20613187 14500,00 84.55 50.41 8895,19 8812,53 -3870.89 10342,48 -982.33 15.00 3.20 14.74 77.35G 5969687.68 597924,56 N 70.32666962 W 149.20587122 14600.00 87,97 65.05 8901.75 8819.09 -3805,22 10395.58 -898.18 15,00 3.43 14.64 76,39G 5969741.88 598007,99 N 70,32681472 W 149.20518898 Tgt2 14639,10 89,36 70.75 8902,66 8820,00 -3774,64 10410,22 -861.98 15,00 3,55 14.58 90,47G 5969757.00 598044,00 N 70,32685489 W 149,20489543 well Design Ver 3,1 RT-SP3,03-HF2,03 Bld( d031rt-546 ) Z-301Z-30IZ-30AIZ-30A (P6) Generated 12/4/2003 10:50 AM Page 1 of 2 Comments Measured I Inclination I Azimuth I TVD I Sub·Sea 1VD I Vertical NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Latitude Longitude Depth Section (It) (deg) (deg ) (It) (It) (It) (It) (It) (degl100 It) (deg/100 It) (deg/100 It) (deg) (ltUS) (ltUS) 14700,00 89.29 79,89 8903,38 8820,72 -3722,60 10425,70 -803,14 r 15,00 -0.11 15,00 90,36G 5969773,25 598102.62 N 70,32689703 W 149.20441831 14800,00 89.22 94,89 8904,68 8822,02 -3628,36 10430.24 -703,53 15,00 -0.Q7 15,00 90,17G 5969779,11 598202,15 N 70,32690948 W 149.20361067 14900,00 89,21 109,89 8906,06 8823,40 -3528,90 10408,86 -606,15 15,00 -0.02 15,00 89,96G 5969759,01 598299.80 N 70,32685107 W 149.20282100 15000,00 89,24 124,89 8907,42 8824,76 -3431,01 10362,99 -517,62 15,00 0.04 15,00 89,76G 5969714,32 598388.92 N 70,32672579 W 149.20210313 15100,00 89,33 139,89 8908,67 8826,01 -3341,35 10295.77 -443,98 15,00 0.09 15,00 89,57G 5969648,08 598463,43 N 70,32654216 W 149.20150597 End Cry 15124.31 89,36 143,54 8908,95 8826.29 -3321.48 10276,64 -428,92 15,00 0.12 15,00 O,OOG 5969629.21 598478.73 N 70,32649006 W 149.20138387 Tgt 31 Cry 10/100 15635.67 89,36 143,54 8914,66 8832,00 -2913,58 9865,4 1 -125,02 0,00 0.00 0,00 -97,13G 5969222,00 598788.00 N 70,32536665 W 149,19891969 15700,00 88,57 137,15 8915,82 8833.16 -2860,24 9815.98 -84,00 10,00 -1.23 -9,93 -97,02G 5969173,12 598829.67 N 70,32523144 W 149.19858704 End Cry 15718,18 88,35 135,35 8916,31 8833.65 -2844,44 9802,79 -71,43 10,00 -1,22 -9,93 O,OOG 5969160,15 598842,4 1 N 70,32519557 W 149.19848513 45N 15868,68 88,35 135,35 8920,66 8838.00 -2712,76 9695.83 34,30 0,00 0,00 0,00 O,OOG 5969054,55 598949.53 N 70,32490322 W 149.19762786 45P 15972,59 88,35 135,35 8923.66 8841,00 -2621,82 9621,95 107,30 0,00 0,00 0,00 O.OOG 5968981,64 599023,49 N 70.32470136 W 149.197. Cry 10/100 16007,71 88,35 135,35 8924,67 8842,01 -2591,07 9596.92 131,97 0,00 0,00 0,00 27,63G 5968957,00 599048,49 N 70,32463315 W 149.196 End Cry 1 Tgt 4 16045,52 91,70 137,10 8924.66 8842.00 -2558.26 9569.63 158,13 10,00 8,86 4,64 O,OOG 5968930,00 599075.00 N 70,32455859 W 149.196 TO 14-1/2" Lnr 16890.48/" 91,70 137,10 8899.66 8817,00 -1831,64 8950.94 733,08 0,00 0,00 0,00 O.OOG 5968319,00 599658.00 N 70.32286829 W 149.19196290 Leqal Description: Northinq (y) [ftUS] Eastinq (X) [ftUS] Surface: 4565 FSL 3630 FEL S19 T11N R12E UM 5959359,99 599043,01 Tie-In: 4565 FSL 3630 FEL S19 T11N R12E UM 5968866,63 597709,05 Tgt2 : 4416 FSL4450 FELS7T11N R12E UM 5969757,00 598044.00 Tgt3 : 3871 FSL 3716 FEL S7 T11N R12E UM 5969222,00 598788.00 Tgt4 : 3575 FSL 3434 FEL S7 T11 N R12E UM 5968930,00 599075.00 TO/BHL: 2956 FSL 2861 FEL S7 T11 N R 12E UM 5968319,00 599658.00 - WeliOesign Ver 3,1 RT-SP3.03-HF2,03 Bld( do31rt-546 ) Z-301Z-301Z-30AIZ-30A (P6) Generated 12/4/2003 10:50 AM Page 2 of 2 8100 Schlumberger WELL Prudhoe Bay Unit - WOA STRUCTURE Z-PAD FJELD Z-30A (P6) Magnetic Parameters Model' BGGM 2003 Miscellaneous Slot: Z·30 Plan" Z-30A(P6) $urfaceLocation La\: N70 17 54.294 Lon W14911 52.462 NAD27 Alaska Stale Planes. Zone 04, US Feel NofU¡ing: 5959359.99ftUS GridComr: +0.75514597' Easting 599043.01 ftUS Scale Fact: 0.9999111434 TVD Ref: Rotary Table (82.66 ft above MSL) SrvyData: DecElmber04,2003 Dip' 80.799' MagDac' +25.134" Date: January22,2004 FS' 57557.0nT -4200 -3900 -2400 -2100 -1800 -3600 -3300 -3000 -2700 e 8100 8400 8400 ~ Õ 0 <:'< g ~ II Q) (ij 8700 8700 () (/) 0 > I- TD/4-112" e 9000 9000 9300 9300 -4200 -3900 -3600 -3300 -3000 -2700 -2400 Vertical Section (ft) Azim = 106.45°, Scale = 1(in):300(ft) Origin = 0 N/-S, 0 E/-W -2100 -1800 10500 10200 ^ ^ ^ z 4? Õ o ~ g ~ II () 15 () C/) C/) v v v Schlumberger WELL STRUCllJRE Z-PAD FIELD Z-30A (P6) Prudhoe Bay Unit - WOA MagneticParame\ers Model eGGM 2003 Surfacalocation Lat N70 17 54.294 Lon: W1491152.462 NAD27 Alaska Stale Planes, Zone 04. US Feet Northing: 5959359.99 ftUS Grid Corw: +0.15514591' Easting: 599043.01 ftUS Scale Fad: 0.9999111434 Miscellaneous Slot: 2-30 Plan; Z·30A(P6) TVD Ref; Rotary TabJø (82.66 II. above MSl) $Ny Date: Deœmber04,2003 Dip: 80,799' Mag Dac: +25.134· Date January22.2004 FS: 57557.0nT -1200 600 -900 o 300 -600 -300 ."""",,,..... .............lm··l~7 ...",...,."...."... 9900 rgt2 ............. ..~.':':.~t1~.0............m......... End crvl KOP çrv 151100 --- 7" C~gpt r ¡ Fault Crossing: -- /¡ ...............................,;l,. ,..............T"................................ ,'..,."...",...,........ ":' '^^ " :- :1 End Cry I Tgt 3 / Cry 1011r +--r=': 9600 , KOP Cry 61100 ,··"V·~~~~'~~;~~~~~ - , ï::::-, ¡ ~OP Whipstock . Tie-In Survey Ilm- ,...,......,',.."....."....,,,....... '.n"'''''......".,.... 9300 t....·.... "~^^'H.'.. ,............;."...... ,.""...."'......,...<, ,.".....",......... 9000 · , · , , , ,_...........>.....H.............................,....."H. · . · . · . · . · . , " : : TD 1 4-1/2"" Lnr <.vv.........,.".......... ,,".>..H.."V'......... v............._....... n.......................,.,'..,..... :Z·3Ò -1200 -900 -600 -300 0 <<< W Scale = 1 (in):300(ft) E >>> 300 600 900 10500 e 10200 9900 9600 e 9300 9000 900 e BPX AK Anti~ollision Report e Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB Z Pad Z-30 Z-30A Date: 12/4/2003 Time: 13:46:09 'aJ,:e: Co-ordinate(NE) Reference: Vertical ([VD) Reference: Well: Z-30, True North Z-30A Plan 82.7 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 13400.00 to 16890.48 ft Maximum Ratio: 1000 Reference: Error Model: Scan Method: Error Surface: Dh: Sybase .--' Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/3/2003 Validated: No Version: 7 Planned From To Survey Toolcode ft ft 31.85 13378.54 1: Schlumberger GCT multishot (31.85-148.m!3"!J~~ 13378.54 16890.48 Planned: Plan #6 V1 MWD+IFR+MS Tool Name Schlumberger GCT multishot MWD + IFR + Multi Station Casing Points ..--.--' ; i TVD ft 2668.73 8248.96 8717.67 8899.66 13.375 9.625 7.000 4.500 Hole Size Name in 17.500 133/8" 12.250 9 5/8" 8.500 7" 6.125 4 1/2" MD ft 2869.00 13400.00 14092.44 16890.48 Diameter in Summary <------------------- Offset Well path Site Well > .'''.------..- Reference Offset Ctr-Ctr :'Iio-Go Allowable :VID :\om Distance Area Deviation Warning ft ft ft ft ft --,-----_._-- -.--."- -.--". 16169.62 13700.00 371.91 0.00 371.91 Pass: Minor 1/200 13494.05 13500.00 0.81 0.00 0.81 Pass: NOERRORS 16225.77 13348.00 1344.99 357.64 987.35 Pass: Major Risk Well path --.-..- --.----.---. PB Z Pad PB Z Pad PB Z Pad Z-19 Z-30 Z-31 Z-19 V1 Z-30 V7 Z-31 V1 --588 400 ···200 ~o 200 400 --588 Field: Site: Well: Wellpath: Prudhoe Bay PB Z Pad Z-30 Z-30A o 5Ð8 270- 180 .n. Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre to Centre Separation [200ft/in] e 90 e e e " p 055197 DATE INVOICE / CREDIT MEMO 11/25/2002 PR 111803G THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY: DATE I I CHECK NO. 11/25/2003 055197 VENDOR DESCRIPTION GROSS DISCOUNT NET PERMIT TO DRILL =EES -Z ·2i)Fr RECEIVED DEC 11 2003 H Alaska Oil & Gas Cons. Commission Anchorage TOTAL ~ NATIONAL CITY BANK Ashland. Ohio No. P 055197 56·389 412 CONSOLIDATED COMMERCIAL ACCOUNT B· . P·.. r;.~ "lr"du'l .... ~ ~.., '0 fHW~ () In". DATE AMOUNT November 25, 2003 I I *******$100,00*******1 NOT VALID AFTER 120 DAYS TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 II- 0 5 5 ¡. 9 ? II- !: 0... ¡. 20 :I B 9 5 I: 0 ¡. 2 ? 8 9 b 1111 e e TRANSM1T AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing well ~ Permit No, API No. Production. sbould continue to be reported as a function· of tbe original API number stated above. HOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates Tbe permit is approved subject to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrough target zones. WELL PERMITCHECi~LIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT Z-30A Program DEV PTD#: 2032190 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Administration 1 Permit fee <!ttached _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ Y~s _ _ _ _ . _ _ _ _ _ _ _ _ 2 le<!s~number _appro¡:¡riate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 .U_n[que well_n_a!11~_and oumb.er _ . . _ _ _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WeJlJocat~d in.a.c:lefine~ppol . . . . . . . . . . . . . . . . . . . . Y~s _ ............ . . . . . . . . . . . . . . . . . . . . . . . . . 5 WeJlJocat~d proper .distance. from driJling unitb.ound.ary . . . . _ . Yes. . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . _ . 6 WeJlJocat~d properdistance3rom otber weUs. _ _ . . . . . . . . . . . . . . . . . . . _ . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . 7 .S.utficienLacre<!g.e.ay<!ilable in_drilJiog unjt . . . . . . . . . . . . . . . . . _ . _ Y.es. . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jtd~vi<!ted, js. weJlbore platJncJu~ed . . _ _ . . . . . . . . . . . . . . . . . . _ . Yes. . . . _ . . . . . . . . . . . . . . . . . . . . . . 9 Operator only <!f[ected party. _ . _ . . . . . . . . . . . . . . . . . . . . Y~s. ....... . . . . . . . . . . . . . . . . . . 10 .Operator bas.apprppriate.b.onQ inJorce. . . _ . . _ _ . . . . . _ . . . . . . . . . . . . _ . . . . . . . Y~s . _ . . . . _ _ . . . . _ . . . . _ . . . . . _ . . . . . . . . . . _ . . . _ _ . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . 11 p~(I1]it c.an be issued witbout çonservation order. . . . . . . _ . . . . . . . . . . . . Yes. . . . . . . . . . _ . . . . . . _ _ . . . . . . . . . . . _ 12 P~rmitc.an be issuedwitbout ad.ministratille.approvaL _ . . . . . . . . . . . . . .Y~s . . . . . . . _ . . . . . . . . . . . _ _ . . . . . _ . . . . . _ . . . . . . iA... 12/19/2003 13 Can permit be approved before 15-daywait Yes _ 14 We.llJocated within <!re<! an.d.strataauthorized by.lnjectioo Ord~r# (puUOtl in.cO!11!11~ots)(FQr.NA _ . . . . . . . _ . . . . . . . . . . . . . . . . . . _ . . . . . 15 AJlw~Us_witj1in.1l4.mile.are.a.ofreyiewid~ot[fied(F9rservjc.e.'^'.e!lpnly). _.... _. _... _.. .NA _ _... _ _ _... _..... _... _ _ _............. _ _.... _ _ _... _.... _.......... _.... _'.'_ 16 Pre-produ.ced injector; ~uration.of pre-pro~uction I~ss. th<!n. 3 montbs. (For.service welt onJy) . . .NA . . . . . _ . . . . . _ _ . . . . . . . . . . . . . . . . . . . 17 ACMPJ:ïndjng .of Con,Si,Stencyhas bee.n Jssued. for.tbis project . . . . . . . . . . . .NA. ....... . . . . . . . 18 .Condu.ctor string.provided . . _ _ _ . . . _ . .NA . . . . . . . . . . . . . . . 19 .S.urf<!ce .casing.protects all.known. USDWs . . . . . _ . . . . NA . . . . . . . . . . . . 20CMTvoladequ.ate.to circ.uJ.ateo.n.cpnd_uctor.& surf.csg. ...... _ . . . . . . . . . . . . . . . .NA _ . . . . . . . . . . _ . . . . . _ 21CMT v.oJ. adequ.ate.to tie-in Jong string to.surf csg. _ . . . . . . . . . . . . _ . . . . . _ NA . 22 .CMTwill coyeraJl know.nwoductive borizon.s_ . . . . . . . . . . . . . _ . No.. . . . Slotted, . _ . . . . . . . . . . . _ 23 .C.asing de.signs <!d.eCuate for C,T, B&.Rermafrost . . . . . . Y~s . . . . . _ . . . . . . . . . . . . 24A~equatet<!n.kageor re.serve pit . . . . _ _ . . . . . . . . Yes.. . .1II<!bors7.ES, . . . . . . . 25 Jtare-~rill~ b<!sa 1.0:403 for abandon.me.nt be~1l ¡¡pproved . . . . . . . . . Y~s . . . . . . _ . . . . . . . . . . . . . . . . . . . 26 .Mequatewe!lbore.separ¡¡tjo.n.proposed...... _ . . . . . . . . . _ . . . . . . . . . . . . . . . . Y~s. . . . . . . . . . . . . . . . . . _ _ _ . . . . _ . . . . _ . . . . . . . 27 Jf.diverter required, does iLmeet reguJations. _ . . . . . . NA _ . . . . Sidetrack. _ . . . . . . . . . . . . Date 28 .DrillillgfJuid.Rrogramsc:;hematic.&eQ.uipJistadequ¡¡te.. ... _.. Y~s.. . Max MW.1L8.ppg. . 12/22/2003 29BQPEs,. do they meet reguJa.tioo . _ . . . .. ...... . . . . Yes. 30 .B.OPEpre.ss ra.tiog appropriate;testto(put psig i.ncomments). . . . . . . . . . . . Y~s . 31C.hokemanjfold compJies w/API R~-53 (May 84) . . . . . . . Yes. 32 Work will pCC.ur withputoper¡¡tjo.n .sbutdown. .. ...... . . . . . . . Y~s . 33 Js presence. of H2S gas. Rrob.able. . . . . . . _ . No. 34 Meçba.nicaLcpndJllon9tWe.lIs within ,A.OR verified (For.s.ervjce welJ Qnly). . . . .NA Appr Date Engineering Appr - Geology 35 36 Date 37 12/19/2003 38 39 Appr RPC Geologic Commissioner: 00 Well bore seg Annular Disposal o o - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - . . . . Te.st to 3500 psi. .MS~ 29.15 psi. - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- P~rmit. can be issued wfo. hyd~ogen s.ulfide l11e<!s~res. . . . .D.ata_preseoted on. pote.ntial 9ve.rpres.sur~zones. .S~i.sl11icanalysjs Qf sbaJlow gas.zolles . S~abed .conditioo survey.(if off-shore) _ . . . . . . . . Conta.ct namelpj1oneJor\l\'eelsly progress reports [exploratpryonly]. _ . . . . . .No NA NA _. . . . NA . _......... N.A ...... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - - - - - -- - - - - - - Date: Engineering Commissioner: Date Public Commissioner Date /~ 2-~f 3 ~ ~ \1"'" ~ ,