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Home My WebLink About207-111• • Imlage Project Well History File COVer Wage xNVZE 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 inspeclItion of the fife. c~; ~ ~ - 1 I i Well History File Identifier Organizing(aone) ^ Two-sided IIIII~)IIIIIIIIIIII ^ Rescan Needed IIIIIIIIIIIIIII~III RESCAN DIGITAL DATA ~olor Items: Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Date: I OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: q /s/ ProjectProofing ~ ~ ~ III IIIIIIIIIII IIIII BY: Maria Date: ~ /s/ Scanning Preparation ~ x 30 = _--1^ + ~ =TOTAL PAGES (Count does not include cover sheet) BY: aria Date: ~ ~ ~ ~~ ls/ ~~ Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include co er sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: aria Date: 1 ~ ~ t~~ /s/ ~~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III IIIII IIIII IIIII Resca,~ned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: o a,.~,e~~ed iuomiiuumii 10/6/2005 Well History File Cover Page.doc Regg, James B (DOA) Page 1 of 1 •�� From: NSK Problem Well Supv [nl617 @conocophillips.com] 1� Sent: Wednesday, December 22, 20104:07 PM 1C% To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2Z -01A (PTD 207 -111) Report of failed TIFL Attachments: 2Z -01A schematic.pdf Guy, Tom, Jim Kuparuk gas lifted producer 2Z -01A (PTD 207 -111) fail a diggnostic TIFL on 12/21/10. The well was already SI prior to the test. The TIO pressures prior to the test were 1925/1770/0. A leaking GLV is suspected. Slickline will troubleshoot and repair if possible. ' Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 L.� 12/23/2010 KRU 2Z -01A PTD 2071110 12/22/2010 TIO Pressures Plot TRN -ANNL ANNULUS PRESSURE TRENDS TRN._PTIL.._IMIT n0. WELL NAME WLKRU2Z -01 3000. 3000 ?O0. 3000. 3000. 2700 3nnn. 2400 - - -- 3000. • 2100 -- - -- - ---- - -.. -- - - -- - - -- -- ---- - -- --- - - -- --- -- -- ---- - 1000 - ----- - -- -- ... - -- -- ------ ------ ------ .°_-- -------- _..------- ..-------- Al%A 1200 --ALI t 900 - t - - - - _ - -- ---- - 0. 600 1. ^., 0. 300 0. 0 . 0 --- --- -------- --- -- -- -- --- - ----- ----- -------- --- --- --- - - -- - -- -- ---- -- -- -- --- --- ---- -•------ ------ ------------- ------- ---- -- - - - - --- - ----- ------ 0' PLOT START TIME MINOR TIME ON PLOT END TIME 23- SEP -10 12:32 MAJOR TIME WEEK +02160:00:0[x, HRs2 -AQ_12:32 PICK TIRE: 10 16:03:25 c, r m m mmmm • Sc TAG HAKE DESCRIPTION P- -VALUE LA "1- T DRILLSITE WELL ® WL2Z -01 -CHOKE FLOW TUBING CHOKE 77777 77 PREV WELL SCRATCH 66 FLOW TUBING PRESSURE ? ? ? ? ? ?? 2z 01 - SCRATCH 66 FLOW TUBING TEMP ???? ??? ® NEXT WELL ® AI- P2Z5002 -01 GL CASING PRESSURE ? ?? ? ? ?? ® ? ? ? ? ? ?? ENTRY TYPE OPERATOR ® ? ? ? ? ? ?? PW OPERATOR VERIFIED ® SCRATCH-66 INNER ANNULUS PRES ? ? ? ? ? ?? PW SYSTEM AUTO ENTRY SCRATCH 66 OUTER ANNULUS PRES ? ? ? ? ? ?? PW BOTH KUP 2Z -01A "WY #Y� �Z l/ $ �Ta a ,.. { irk -? 7r i" - � Inc, Wellbore API /UWI Field Name Well Status Inc/ (*) MD(ftKB) Act Btm (ftKB) 500292095301 KUPARUK RIVER UNIT PROD 40.12 2,491.80 7,559.0 . * Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Weli.canf:D aTEO -zzotA anato4 >o;tw.ts SSSV:TRDP 40 1/13/2010 LastWO: 9124/2007 36.00 5/19/1983 SchamaTlc „ Annotation Depth (ftKB) End Date lAnnotation Last Mod.. ' End Date Last Tag: 6,774.0 8/6/2010 Rev Reason: GLV C /O, TAG Imosbor 8/8/2010 HANGER, 25 C .StC S Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Third CONDUCTOR 16 15.062 30.0 80.0 80.0 62.50 H 40 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third SURFACE 103/4 9.794 30.0 2,900.0 2,660.7 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION Post 7 6.276 36.0 4,000.0 3,531.4 26.00 J -55 BUTT WO Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINDOW A 7 6.000 1 3,710.0 1 3,723.0 1 3,300.7 Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 51/2 4.950 3,552.5 6,948.0 6,214.1 1 15. 1 L -80 Hydril511 CONDUCTOR, 6 .,r Top Depth (TVD) Top Incl Nooml Top (ftKB) (ftKB) V) Item Description Comment ID (in) SAFETY VLV, 3,552.5 3,166.3 38.33 PACKER 5.5" X 7" LTP "CHIP" C -2 profile w/ 6' ext. Est 5.5" ID 5.500 2,106 3,563.0 3,174.5 38.30 HANGER HMC liner hanger - 5.5" Vam p X p 4.960 Tubill .Str11 j Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 25.0 6,434.6 5,766.0 9.30 L - IBTM GAS LIFT, t Istlxstsil�l .r , To Depth 2,780 _ (TVD) Top Incl Nomi... Top (ftKB) (ftKB) V) Item Description Comment ID (in) _ 25.0 25.0 -0.02 HANGER FMC 3.5" Gen IV Tbg Hanger EUE 8rd 3.500 SURFACE, 30 -2,900 2 ,106.3 2,036.5 30.66 SAFETY VLV 3.5" SCSSV TRMAXX -5E w/ 2.812" X profile IBTM Sr# HZS -403 2.812 w' 6,358.1 5,700.4 31.28 PBR BOT 80 -40 PBR w/ Special Trim OD, EUE 8rd Mod. 3.000 6,371.6 5,712.0 31.24 ANCHOR BOT KBH -22 Anchor 40FA36, EUE 8rd Mod. Box up 3.040 6,372.4 5,712.6 31.24 PACKER BOT SABL -3 Production Packer 44SABL36X27, box down 2.760 Y 6,376.6 5,716.9 31.92 X/O BUSHING BOT XO bushing 3.5" NU pin X EUE 8rd pin ( 3.78" OD / 2.97" ID) 2.970 6,422.4 5,755.6 31.44 NIPPLE Halliburton 3.5" X 2.75" "X" Nipple 2.750 6,433.8 5,765.3 31.32 WLEG 3.5" Wireline Entry guide, EUE 8rd tbg 4.40" OD, 3.375" ID 3.375 Pertoratic�r &Sets 4 " WINDOW A, y Shot - 3,710 -3,723 1 Top (TVD) Btm (TVD) Dens PRODUCTION Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh. Type Comment Post WO, = 6,732 6,752 6,022.9 6,040.3A- 4,2Z -01A 11/13/2007 6.0IPERF ALTERNATING 3s -a,000 HYPERJET /POWERJET CHARGES 60 DEGREE PHASING r y p L„ G ?I t>t @8. GE3C1 @E: it ` i AS LIFT. o i � � 4,183 End Date Annotation 9/29/2007 NOTE: ** *WARNING * * ** LIMIT IA PRESSURE TEST TO 2500 psi DUE TO LINER TOP PACKER NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 5,104 GAS LIFT, 5,816 GAS LIFT, 6,277 N: PBR, 6,358 a ' ANCHOR, 6,372 PACKER, 6,372 X/O BUSHING, 6,377 �1 t IYIlAndCet��.� f,7e "* Top Depth Top ,. Port NIPPLE, 6,422 (TVD) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) V) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,779.7 2,568.0 39.77 CAMCO KBMG 1 GAS LIFT GLV BK -5 0.156 1,336.0 8/6/2010 WLEG, 6,434 2 4,183.2 3,693.2 26.51 CAMCO KBG -2 -9 1 GAS LIFT GLV BTM 0.156 1,317.0 8/6/2010 3 5,103.8 4,553.8 18.84 CAMCO KBG -2 -9 1 GAS LIFT GLV BTM 0.156 1,299.0 8/6/2010 41 5,815.61 5,218.0 25.52 CAMCO KBG -2 -9 1 GAS LIFT GLV BTM 0.188 1,319.0 8/7/2010 IPERF, 6,732 -6,752 5 6,276.5 5,629.6 28.64 CAMCO KBG -2 -9 1 1 1 GAS LIFT JOV BTM 0.188 0.0 8/7/2010 I LINER, 3,552 -6,948 TD (2Z -01A), 6,950 ~.~ ~ r. ~~ ~,~ ~. _~. ~ ~~ ~~ ~ f. _ .. ~ .~ ~.a:` ,~ ~"~~ ~, ~ `. +,„~' ~ `" ~, ~ .{;. ~~. ,~ ~~ ~ MICROFILMED 6!30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfiim_Marker.doc ~ l_..~ ~ • • Conc~coPhillips Ala~~ka P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~O ~ ~ ~~ t c~~f ~ ~ ~ Enclosed please find a spreadsheef with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 20th and October 13th 2009. The corrosion inhibitor/seala.nt was pumped October 15th and 31 St + November 1~ and 2"d 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have a.ny questions. ~mcerely, ~ Perry Kle~in~ r~ L ~~~ ~~,~~~~~ `°~O~,~ ~. ;~ ~(l(s~ ~~~~~,, ''•a~ ~ ~~,~~ ~~~~, ~6~Cf1TT11SSl4t~ ~1t1C~4f~~~ ~~~~.% ' ~-~ '' ~ ~# ~~`~~ ~ ;~ r~u~' ~ ~` ~. ,~ Y;?..;,~id ti+l ConocoPhillips Well Integrity Projects Supervisor . ~ ~ .~..~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C, 2D, 2Z & 3K Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top ofF date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10l15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10131/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10l31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/172009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530't00 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11l212009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11 /2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11/1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" ~ NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2Z-OlA May 15, 2009 AK-MW-5160206 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 2Z-OlA 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50-029-20953-01 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50-029-20953-01 2" x 5" MD BAT Logs: 1 Color Log 50-029-20953-01 2" x 5" TVD BAT Logs: 1 Color Log 50-029-20953-01 Digital Log Images 1 CD Rom 50-029-20953-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 ® -~:,, BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Brv~ai~. ~ n.com _. . ~ _~ AY ~ ~ ZG9 Date: . e _ - °_~ J! ~a~ Ors. Oot~issior~ ~~char~ Signed: ~o~ - l L ~ ~~au f DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071110 Well Name/No. KUPARUK RIV UNIT 2Z-01A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20953-01-00 MD 6950 TVD 6216 Completion Date 11/13/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su ey Yes DATA INFORMATION ' Types Electric or Other Logs Run: GR/Res, CBL, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Dat Digital Dataset Log Log Run Interval OH / T e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Sonic 5 Col 1 100 6790 Open 10/19/2007 USIT, Isolation Scanner 27 Sep-2007 C 15565 Report: Final Well R Open 10/23/2007 Final Well Report, Table of ~ Content, Equip & Crew, ~I Well Details, Geo Data, Pres/Form Strength Data, i Drilling Data, Daily Reports w/PDF, LAS and TIF images and graphics FiD, C 15565 Mud Log 2 Col 3723 6950 Open 10/23/2007 MD Formation Log E, b/ C 15565 Mud Log 2 Col 3723 6950 Open 10/23/2007 TVD Formation Log ~D~ C 15565 Mud Log 2 Col 3723 6950 Open 10/23/2007 MD LWD Conbo Log ~ F,/~// C 15565 Mud Log 2 Col 3723 6950 Open 10/23/2007 TVD LWD Conbo Log EB'/ C 15565 See Notes 2 Col 3723 6950 Open 1,0/23/2007 MD Gas Ratio ED C 15565 See Notes 2 Col 3723 6950 Open 1b/23/2007 TVD Gas Ratio El~/C 15565 See Notes 2 Col 3723 6950 Open 10/23/2007 MD Drilling Dynamics E>? C 15565 See Notes 2 Col 3723 6950 Open 10/23/2007 TVD Drilling Dynamics og Production Blu 100 6800 Case 11/27/2007 Production Profile !Press / Temp / Gradio /Spinners / , Deft 16 Nov, 2007 D Asc Directional Survey 28 6850 Open 12/3/2007 pt Directional Survey 28 6850 Open 12/3/2007 pt LIS Verification 3695 6892 Open 2/29/2008 LIS Vei, FCNT, NCNT, RHOB, DRHO, NPHI, GR, ROP, RPS, RPM, RPX, FET, RPD I ~_ I DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071110 Well Name/No. KUPARUK RIV UNIT 2Z-01A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20953-01-00 MD 6950 TVD 6216 Completion Date 11/13/2007 Completion Status 1-OIL Current Status 1-OIL UIC N D C Lis 15980 Induction/Resistivity 3695 6892 Open 2/29/2008 LIS Vei, FCNT, NCNT, RHOB, DRHO, NPHI, GR, ~ 1` ~(' ~R Ct~~.1 4 Y f ROP, RPS, RPM, RPX, FET, RPD ' og 5 Blu 100 6750 Case 3/25/2008 PPL, Pres, Temp, Gradio, Spin, Deft, 11-Mar-2008 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~_~ Analysis V`%'I~- Received? Comments: Daily History Received? lY~` Formation Tops ~/ N compnance rceviewea tsy: Date: ~~r~~~~~ri~~~ ~ ~.{'` ~C f`,'. ~~ ~~~~~ NO. 4639 Schlumberger -DCS a,~E+~ ir:~; 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/20/08 2W-11 11996609 LDL - 03/17/08 1 3J-19 11996610 PROD PROFILE - ~~( 03/18/08 1 2Z-O1A 11994631 PROD PROFILE 03/11/08 1 1E-08 11994632 INJECTION PROFILE 03/12/08 1 2U-12 11994638 PROD PROFILE - 03/16/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ ~ WELL LOG TRANSMITTAL To: State of Alaska February 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2Z-OlA AK-MW-5160206 1 LDWG formatted CD Rom with verification listing. API#: 50-029-20953-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Ancho e, Alaska 99518 ~k ,-~ ; -~ ~ ~ Date: -~~, ~ :n ~nn~ sue-- ~ ~ •~ „v t:3 _. Signed: ~p~-- t t D ~ t 5 ~~d ConocoPhillips December 12, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2Z-01A Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2Z-01A. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~ ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling ~. ~~~C ~. "~ ~E~I~r ~taska Oil ~a Oas ~r~~~. ,,:-~r;f~s¢a~ RT/skad Ancharag ~~~~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEC ~ `Z 207 WELL COMPLETION OR RECOMPLETION REP~~~, ~`(!~'~`n~Qrh~miscinn 1a. Well Status: Oil a Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 ~"'-- GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well CI s11s: velopm~f"C~r~~ ---€xplodatat~'- ^ .? Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Com ., Sus ., ~~ iytz P P /I~o y. /.~ orAband.: S~tsr~-h~eR9, 2007 12. Permit to Drill Number: 207-111 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 19, 2007 13. API Number: 50-029-20953-01 4a. Location of Well (Governmental Section): Surface: 1770' FSL, 577' FEL, Sec. 11, T11 N, R09E, UM 7. Date TD Reached: September 24, 2007 ` 14. Well Name and Number: 2Z-01A - Top of Productive Horizon: 721' FNL, 472' FEL, Sec. 14, T11 N, R09E, UM 8. KB (ft above MSL): 101' . Ground (ft MSL): 73' 15. Field/Pool(s): Kuparuk River Field Total Depth: 822' FNL, 446' FEL, Sec. 14, T11 N, R09E, UM 9. Plug Back Depth (MD + TVD): 6751' MD ! 6040' TVD Kuparuk Oil Pool Y 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529131 ~ y- 5966527 Zone- 4 10. Total Depth (MD + TVD): ~" 6950' MD / 6216' TVD ` 16. Property Designation: ALK 25653 TPI: x- 529248 y- 5964037 Zone- 4 Total Depth: x- 529274 - 5963936 •` Zone- 4 11. SSSV Depth (MD + TVD): Camco SSSV @ 2106' MD / 2036' TVD 17. Land Use Permit: 2579 18. Directional Survey: Yes ~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1400' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~ j~ ~ ~~ ,• ~7~p ~-''1f> GR/RES, CBL, USIT ';7~,p 22. CASING, LINER AND CEMENTING RECORD !t • /.t ~a7 SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 80' Surf. 80' 24" 305 sx AS 11 10.75" 45.5# K-55 Surf. 2900' Surf. 2663' 13.5" 1200 sx Fondu, 250 sx PF C 7" 26# J-55 Surf. 7559' Surf. 6582' 8.5" 550 sx Class G, 250 sx PF C 5.5" 15.5# L-80 3552' 6948' 3166' 6215' 7" 460 sx Class G window @ 3710'-3723' MD 23. Open to production or injection? Yes / No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top 8 Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 6435' 6373' d 6732'-6752' MD 6023'-6040' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production November 15, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 11/17/2007 Hours Tested 22.5 hours Production for Test Period --> OIL-BBL 221 GAS-MCF 927 WATER-BBL 0 CHOKE SIZE 176 Bean GAS-OIL RATIO 4529 Flow Tubing press. 144 psi Casing Pressure 851 Calculated 24-Hour Rate -> OIL-BBL 227 GAS-MCF 1003 WATER-BBL 0 OIL GRAVITY -API (corn) 24 deg. 27. CORE DATA Conventional Core(s) Acquired? Yes No 0 Sidewall Cores Acquired? Yes No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. s----•^ Cv~PLEilON ~~~ b NONE ~ 1fERiF ---~,--' Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE 6D ~~ • tIC..•o7 .~ ~~~? ~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground Surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1405' 1400' TVD needed, and submit detailed test information per 20 AAC 25.071. Kuparuk D top 6524' 5843' Kuparuk B top 6613' 5920' Kuparuk A4 top 6726' 6018' Kuparuk A3 top 6773' 6059' N/A Formation at total depth: Kuparuk A4 ; 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Narraa.~,_ R Thomas Title: Drillino Team Leader t ~~~ 2~~ ~ ~ Signature ~ i~ l~ Phone L(@ S` ~~ ;~ Date INSTRUCTIONS Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 1 J Ca-noca-Ph-ilps Time Log Summary WelN7ew Web ReAO?7/ng Well Name: 2Z-01 Job Type: DRILLING SIDETRACK ---- ------- Time Los _ Date From To Dur S. Depth E. De th Phase Code Subcode T COM _____ ____ 09/15/2007 00:00 10:00 10.00 0 0 MIRU MOVE MOB P Rig was released from 1J-107 for 11 mile move to 2Z-01A. Preparing rig to move. Move the rig in 2 convoy's. The first convoy consisted of the 2 pipe shed pieces, boiler house and rockwasher, arrived on location @ 0230 hrs. Go back and get next convoy. The second convoy consisted of the pits, pumps, motor, and subbase/derrick. Arrived on location @ 1000 hrs. Mats were Iayed f/ 2Z-01A while moving rig. 38 additional mats were rented f/ GBR for the move to use on the roads. 10:00 11:00 1.00 0 0 MIRU MOVE MOB P Set derrick module over the hole. 11:00 16:00 5.00 0 0 MIRU MOVE MOB P Set mats, then set the pit module, pump room, set the motors, boiler house, then both pipe sheds. Set the rockwasher.Rig up and complete the Rig acceptance checklsit. Note: Rig accepted @ 1600 hrs 9/15/2007. 16:00 18:00 2.00 0 0 MIRU WELCT OTHR P PU lubricator. Rig up 2" high pressure lines to the tubing and RU on the annulus to the choke. Pull the bpv, showing 150 psi on the tubing, 150 psi on the IA, 300 si on the OA. 18:00 18:15 0.25 0 0 MIRU WELC SFTY P PJSM on checking the pressure and bleedin off. 18:15 19:30 1.25 0 0 MIRU WELCT OTHR P Pressure test pump line to 1000 psi, OK. Open up the well to the choke, monitor with no returns. 3-1/2" 9.2 ppf J-55 BTC tubing had been cut 15' below GLM #8 @ original RKB depth of 6283'. Pressure of 60 psi, casing pressure of 30 psi. (Choke panel: DP pressure of 30 =zero pressure, csg ressure of 40 =zero ressure . Page 1 oaf ~3 ~~ Time Logs _ _ Date From To Dur S. De th E. D th Phase Code Subcode T COM 09/16/2007 09:30 13:30 4.00 0 0 MIRU WELCT BOPE ~ P Testing BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Test to 250 psi low and 3000 psi high, hole each test 5 min. Chart test. Tested the annular to 4"and 3-1/2". Tested upper pipe rams to 4" and 3-1/2", tested blinds. Tested choke manifold, kill lines and choke lines. Floor dart valve and TIW valve. Upper and lower IBOP on the top drive. Koomey tested: initial 3000 psi, after closing 1800 psi, 200 psi buid up in 34 seconds, full charge 2 min 44 seconds. Five bottle average 2150 psi. Tested as and H2S alarms. 13:30 13:45 0.25 0 0 MIRU WELC SFTY P PJSM on pulling tubing hanger 13:45 14:45 1.00 0 0 MIRU WELCT OTHR P Remove blanking plug, attempt to pull BPV. No success ullin the BPV. 14:45 15:30 0.75 0 0 MIRU RPCOh PULD P Work the string 3 times f/ 87k to 35k. Pull hanger to the floor. Pulled free 87k. 15:30 16:15 0.75 0 0 MIRU RPCOh RURD P RU casing tools and spool to roll up control line. 16:15 17:00 0.75 0 0 SURFA RPCO PULD P Lay down tubing hanger w/ pup and a 6' pup jt below same .Lay down crossovers made up into top of the han er. 17:00 21:00 4.00 0 0 SURFA RPCOti PULD P POOH lay down 63 jts of 3-1/2" 9.2 ppf J-55 buttress casing plus sssv, and 1 GLM. Total length of tubing removed from the well is 1962.92' + RKB of 25.23' to the LDS of the tubing s ool. 21:00 21:15 0.25 0 0 SURFA RPCOh SFTY P PJSM on running Baker "ES retrievamatic f/ 7" 26 f. 21:15 21:45 0.50 0 0 SURFA WELC OTHR P PU/MU 2 jts of 4" XT 39 w/ x-o to 3-1 /2" IF on bottom and floor safety valve on top. MU to Baker "EA" retievamatic w/ x-o on the bottom to 3-1/2" IF to 3-1/2" buttress, made up to remainin tubin in the hole. 21:45 22:00 0.25 0 0 SURFA WELCT OTHR P RIH and set Baker "EA" retievamatic by turning 3/4" to the left. PU wt 67k, SO wt 58k. Center of the element 75.89' from ri floor. 22:00 22:15 0.25 0 0 SURFA WELC BOPE P Test the backside to 1000 psi w/the annular.Test for 5 min. OK. Bleed off the ressure. 22:15 22:45 0.50 0 0 SURFA WELCT OTHR P Turn string to the right 11-1/2 turns. POOH w/ 2 jts of dp and x-o's. Left the top of twin head 68.45' from the rig floor. 22:45 23:45 1.00 0 0 SURFA WELCT OTHR P Lay down 2 joints of 4" Weatherford dp and Baker twin thread safe 't .69' . I~~€~~ 3 ~f 13 ~~ Time Logs ~ __ D to From To D r S. De th E. De th Phase Code Subcode T COM 09/17/2007 20:00 20:30 0.50 0 0 SURFA WELCT OTHR P _ Rig up to test lower pipe rams, choke hose, u er i e rams, and annular. 20:30 22:30 2.00 0 0 SURFA WELCT BOPE P Test bottom 4" pipe rams to 250 psi low and 3500 psi high. Hold each test 5 min. Change out test joint. Test upper pipe (3-1/2" x 6" variables) with a 5.5" test joint, test annular to 5.5" and test choke line. Hold each test 5 min. Chart test. Witness of test waived by AOGCC inspector Lou Grimaldi. 22:30 23:00 0.50 0 0 SURFA WELCT OTHR P Pull test plug. Install FMC Wear bushing CPAI part # 10629637, (6-5/16" ID x 6-16/16" OD x 8" long .67' ,run in 2 lock down screws. 23:00 23:30 0.50 0 0 SURFA WELCT OTHR P Clear floor. 23:30 00:00 0.50 0 0 SURFA WELC NUND P Blow down chole manifold, line up choke manifold to drill. 09/18/2007 00:00 02:15 2.25 0 0 SURFA WELCT OTHR P MU safety valve on storm packer retrieving tool and RIH to 68', latched onto storm packer, released same and POOH LD storm packer, had to remove bell guide on top drive to MU safe valve, re-installed same. 02:15 09:00 6.75 0 0 SURFA RPCOI~ TRIP P Held PJSM then cont. to POOH LD 3 1/2" completion, LD an add. 137 jts of 3 1/2", 9.2#, buttress tbg, 7 GLM's and 1 cut jt. recovered a total of 4,274.64'. Total overall recovered 200 jts tbg, 8-GLM's, SSSV, and cut off jt 6,237.56' 09:00 11:00 2.00 0 0 SURFA RPCOh OTHR P Unloaded pipe shed and cleared rig floor. 11:00 16:30 5.50 0 0 SURFA RPCOh TRIP P MU 6 1/8" bit on 7" csg scraper and RIH singling in hole with 4" XT-39 DP out of the pipe shed, RIH and tagged upon 3 1/2" tbg stub at 6,284'. st wt u 125K, do wt 95K 16:30 17:15 0.75 0 0 SURFA RPCO CIRC P Circ 2X the hole capacity at 6,284', circ at 500 gpm at 1,150 psi. Circ to clean hole and 4" DP. 17:15 21:00 3.75 0 0 SURFA RPCOh TRIP P POOH and LD bit and scraper, cleared ri floor. 21:00 22:00 1.00 0 0 SURFA EVALIPo RURD P Held PJSM then RU Schlumberger wireline (SWS) and MU Baker 7" K-1 CIBP on GR/CCL to in tool. 22:00 23:00 1.00 0 3,727 SURFA EVALV~ ELOG P RIH with CIBP and set same at 3,727' WL, set CIBP 3' above collar at 3,730', correlated to CBL log from 6/7/1983, CBL showed TOC to be est. at 5,500', POOH with wireline. 23:00 23:30 0.50 3,727 3,727 SURFA EVALVI~ RURD P RD SWS wireline and scheaves 23:30 00:00 0.50 3,727 3,727 SURFA RPCO DHEQ P Tested CIBP at 3,727' and 7" csg to 3,000 si for 15 min, ood test. Page 5 oaf 13 ., Time Logs Date From To Dur S De th E. D th Phase Code Subcode T COM 09/19/2007 00:00 02:30 2.50 0 0 SURFA RPCOh OTHR P PU and stood back 4 stds of HWDP and 4 stds hybrid push pipe 2-DC's-1-HWDP 02:30 03:00 0.50 0 0 PROD1 STK OTHR P Pu whipstock equip. to rig floor. 03:00 08:00 5.00 0 138 PROD1 STK PULD P MU Baker's 7" btm trip whipstock and milling assembly with MWD RIH to 138'., oriented to WS and uploaded MWD. 08:00 08:30 0.50 138 138 PROD1 STK OTHR P RIH to 330' and shallow tested MWD and ck'd ok. 08:30 09:30 1.00 138 1,408 PROD1 STK PULD P Fin MU BHA #1, RIH with HWDP and hybid push pipe then PU 15 jts of 4" DP out of the i e shed RIH to 1,408' 09:30 11:00 1.50 1,408 3,562 PROD1 STK TRIP P RIH with WS from 1,408' to 3,562' 11:00 12:00 1.00 3,562 3,562 PROD1 STK CIRC P Flushed mud pumps and displaced hole over from seawater to 9.6 ppg LSND mud. 12:00 12:15 0.25 3,562 3,710 PROD1 STK TRIP P Oriented whipstock to 49 deg. left of high side, RIH and tagged CIBP at 3,727', set 10K wt down to set btm trip anchor and set 20K down and sheared off bolt was set to shear at 35K . 12:15 12:30 0.25 3,710 3,710 PROD1 STK CIRC P Took SPR's. 12:30 16:30 4.00 3,710 3,723 PROD1 STK WPST P Milled window in 7" csg from 3,710' to 3,723'. 16:30 20:45 4.25 3,723 3,763 PROD1 STK WPST P Drilled 40' of new formation from 3,723' to 3,763', saw 1,800 units of gas while drilling new hole. Pumped 2 sweeps and saw no increase in cuttin s. 20:45 22:00 1.25 3,763 3,763 PROD1 STK CIRC P Worked mills thru window while circ hole clean, circ at 300 gpm, 1,500 psi and 90 rpm's, worked mills thru window with no pump or problems and ck'd ok. 22:00 22:45 0.75 3,763 3,690 PROD1 DRILL LOT P Stood back 1 std and RU and performed a LOT to 14.3 ppg EMW with 810 psi, 3,290' TVD and 9.6 ppg mud. 22:45 23:00 0.25 3,690 3,690 PROD1 STK OTHR P Monitored well-static, pumped dry job and blew down to drive. 23:00 00:00 1.00 3,690 2,900 PROD1 STK TRIP P POOH from 3,690' to 2,900' 09/20/2007 00:00 01:00 1.00 2,900 554 PROD1 STK TRIP P Cont. to POOH with BHA #1 from 2,900' to 554'. 01:00 01:45 0.75 554 138 PROD1 STK PULD P POOH LD 9 - 4 3/4" DC's and 5 jts of HWDP 01:45 04:15 2.50 138 0 PROD1 STK PULD P Fin. POOH and LD BHA #1, LD bumper jars, downloaded MWD and LD same, LD milling assembly and upper mill was in gauge, cleared and cleaned ri floor. 04:15 05:30 1.25 0 0 PROD1 STK OTHR P Pulled wear bushing and flushed out BOP stack, re-installed wear bushin . ~~ Page 6 cif 'f 3 ~~ Time Logs i Date From To Dur S De th E. De th Ph e Code Subcode T COM 09/20/2007 05:30 11:30 6.00 0 788 PROD1 DRILL PULD P PU and MU BHA #2 RIH to 788', MU bit #1, 6" x 7" Bi-center bit on 4 3/4" motor with 1.83 bend, Quad combo logging string, oriented and uploaded MWD, shallow tested same, held PJSM then loaded radioactive sources, fin RIH with NMFDC's, HWDP and ~ars to 788'. 11:30 13:45 2.25 788 3,763 PROD1 DRILL TRIP P RIH with BHA #2 from 788' to TOW at 3,710' ,oriented BHA to 43 deg. left of HS and RIH thru window and to btm at 3,763' with no roblems. 13:45 00:00 10.25 3,763 4,440 PROD1 DRILL DDRL P Directionally drilled 7" hole with bi-center bit and 1.83 deg motor per directional plan from 3,763' to 4,440' MD! 3,925' TVD (677') ART 6.09 hrs, AST 1.84 hrs, total 7.93 hrs. ave MW 9.8 ppg MW, ECD 11.62 ppg, ave bgg 90 units, max gas 460 units from 4,207'. 09/21/2007 00:00 12:00 12.00 4,440 5,001 PROD1 DRILL DDRL P Directionally drilled 7" hole with bi-center bit and 1.83 deg motor per directional plan from 4,440' to 5,001' MD/ 4,456' TVD (561') ART 7.62 hrs, AST 1.33 hrs, total 8.95 hrs. ave MW 10.1 ppg MW, ECD 11.9 ppg, ave bgg 25 units, max as 107 units. 12:00 00:00 12.00 5,001 5,479 PROD1 DRILL DDRL P Drilled 6" x 7" hole from 5,001' to 5,479' MD/4,906' TVD (478'), ART 7.66 hrs, AST 1.95 hrs, 9.61 total hrs. ave 10.2 ppg MW, ave ECD 12.1 ppg, ave BGG 25 units max as 70 units. 09/22/2007 00:00 12:00 12.00 5,479 5,906 PROD1 DRILL DDRL P Directionally drilled 7" hole with bi-center bit and 1.83 deg motor per directional plan from 5,479' to 5,906' MD/ 5,300' TVD (427') ART 8.13 hrs, AST 1.98 hrs, total 10.12 hrs. ave MW 10.5 ppg MW, ECD 12.2 ppg, max as 155 units. 12:00 23:30 11.50 5,906 6,313 PROD1 DRILL DDRL P Drilled 7" hole from 5,906' to 6,313' MD/5,660' TVD (407') ART 7.75 hrs, AST 2.19 hrs, total hrs 9.94., ave 11.3 ppg MW, ECD 13.0 ppg, ave BGG 50 max gas 182. Had 1-conn. gas to 509 units. Pum ed 35 bbl hi vis swee . 23:30 00:00 0.50 6,313 6,313 PROD1 DRILL CIRC P Fin. circ out high vis sweep and was clean at the shakers, had 10% increase in cuttings back from the sweep, circ hole at 265 gpm, 2,825 si and 40 r ms with 5K ft-Ibs for ue. 09/23/2007 00:00 01:00 1.00 6,313 4,910 PROD1 DRILL WPRT P Monitored well-static, st wt up 140K, do wt 101 K wiped hole 15 stds from 6,313' to 4,910' with no problems, st wt u 118K, do wt 90K. 01:00 01:30 0.50 4,910 6,313 PROD1 DRILL WPRT P RIH to btm at 6,313' with no problems. Pace 7 o~t ~13 L l Time Logs _ Date From To Dur S De th E. De th Ph e Code Subcode T COM 09/25/2007 01:30 03:00 1.50 188 188 PROD1 DRILL SRVY P _ _ Plug In -Down Load MWD 03:00 04:00 1.00 188 0 PROD1 DRILL PULD P Breah Out and LAy down BHA #2 - Bat Sonic, TM, Nuke ALD/CPN, PWD, SP$, Stab, DM, NM Flt sub, Mud Motor & Bit. 04:00 04:30 0.50 0 0 PROD1 DRILL PULD P Clean and Clear Rig floor -Decision made to make clean out run due to bit condition .125 under au e. 04:30 05:00 0.50 0 580 PROD1 DRILL PULD T PU DI clean out and hole gauge assy. 6.125" bit, bit sub, Flt sub, XO, 6 stds HWDP w/Jars. 05:00 08:00 3.00 580 6,950 PROD1 DRILL TRIP T TIH f/ 557' to 6950' MD -Fill DP every 20 stds (Hole fill Calu 40 bbl, actual 42 bbls. No ti ht hole noted. 08:00 09:00 1.00 6,950 6,950 PROD1 DRILL CIRC T Pump Hi Vis sweep and circu to surface -Had large recovery of materal from well - PR 270 gpm, PP 1410 psi, 90 RPMs, 5K torq. Up wt 145k, Dn wt 95k, Rot wt 110k 09:00 12:00 3.00 6,950 932 PROD1 DRILL TRIP T Flow Check well "Static" -Blow Dn TD -POOH f/ 6950' to 932' - Calcu HF 34 bbls, actual 32 12:00 12:30 0.50 932 0 PROD1 DRILL TRIP T Con't POOH - LD -Clean Out Assy. 12:30 12:45 0.25 0 PROD1 CASIN RURD P Clean Rig Floor 12:45 13:30 0.75 0 0 COMPZ CASIN RURD P RU to run 5.5" 15.5# L80 Hyd511 cs liner on DP 13:30 13:45 0.25 0 0 COMPZ CASINC SFTY P PJSM w/Crew and Vendors -Discuss runnin detail and know hazards. 13:45 14:00 0.25 0 159 COMPZ CASINC RUNL P PU & Run 4 jts liner - Ck floats - "OK" 14:00 18:45 4.75 159 3,582 COMPZ CASINC RUNL P PU & Run 5.5" Liner 159' to 3582' - Lost 15 bbls mud while picking up and runnin cs . 18:45 20:15 1.50 159 3,582 COMPZ CASINC RUNL T PU Liner pkr and attempted to run same. The pkr would not go below well head. The BOP stack was drained and no obstruction could be seen iron the rig floor. The liner hanger was pulled back to the rig floor where it was noted that the wear bushing lip had been rolled over and the hanger slips were hanging on this because of the reduced "ID". ID of wear bushing 6.375" - Largest OD on Hanger is 6.14" -- 7" Cs ID is 6.276" 20:15 21:30 1.25 3,582 3,582 COMPZ CASINC RURD T LD Csg Hanger and Wear Bushing - ""'NOTE"' Pkr and Hanger assy will have to be returned to Baker shop to be reset and then brought back. - While gone rig will do slops as ossible. F+ar~e 9 of 13 i Time Logs __ D to From To Dur __ S De th E. Depth Phase Code Subcod. T COM 09/25/2007 21:30 22:15 0.75 3,582 3,582 COMPZ CASIN( OTHR T PU XO to 5.5 csg and ported circu sub w/joint of DP. Lower circu sub to well head and circu and clean area from 7" csg head to bushing profile. This should clean up any debris or cuttin s. PR 320 m, PP 400 si 22:15 23:30 1.25 3,582 3,582 COMPZ RIGMN SVRG P Slip and Cut Drill Line 23:30 00:00 0.50 3,582 3,582 COMPZ RIGMN SVRG P Service Top Drive 09/26/2007 00:00 03:30 3.50 3,582 3,582 COMPZ DRILL WOEO T SIOPS -Waiting on LTP to be rebuilt and re-pined - Stag well adapter in . cellar - (Precautionary) Go thru #2 MP mud end -Clean suction screens on both MPs -Change oil & filters on #2 Cat DE - Serv To Drive 03:30 04:15 0.75 3,582 3,670 COMPZ CASIN RUNL T PU rebuilt LTP - MU on Liner -Run 1 std DP and MU to To Drive 04:15 06:45 2.50 3,670 3,670 COMPZ CASIN CIRC P Circu Liner volume - PR .75 bpm w/ 65% loss of returns - Up wt 85k, Dn wt 60k 06:45 07:00 0.25 3,670 3,670 COMPZ CASIN RUNL P L/D Top single std #3 and MU Baker Cmt head - Sta eon i e skate 07:00 11:00 4.00 3,670 6,920 COMPZ CASINC RUNL P RIH w/ 5.5" liner on DP f/ 3670' to 6920' -Running speed very slow due to micro clearance of annulus (.136 ") Loss of 65-70% returns. Calcu disp 17.1 bbls, actual returns 6.18 bbls = Loss 10.8 bbls 11:00 12:00 1.00 6,920 6,950 COMPZ CASIN RURD P PU Baker Cmt head and single dp 6920' to 6950' -Circu PR 3/4 bpm , PP 360 , U wt 147k, Dn wt 85k 12:00 14:45 2.75 6,950 6,950 COMPZ CEME~ CIRC P Con't to Recip Liner and work PR up to 30 SPM, 850 psi ,showing 25% losses. Worked string up and down slowly @ this rate but Lost all returns @ 14:00 hrs. Slow PR to 10 spm and con't to work pipe very slowly. Still No Returns. U wt 140k, Dn wt 85k 14:45 17:30 2.75 6,950 6,948 COMPZ CEME CIRC P Start Cmt per Dowell -Pump 5 bbls water -Test Lines - It was noted that the CMT standpipe hose had a pin hole just below the fitting. CO hose and continue with test to 3500 psi "OK". Pump 25 bbls CW100, 25 MudPush @13.5 ppg, Pump 96.5 bbls 15.74ppg cmt slurry. Av rate 3 bpm.- Drop Dart -Dowell displace cmt Rate av 3 bpm, Starting ciru psi 600 ,Final psi 1250. Bump wiper 117 bbl. Pressure to 3500 psi per Baker rep. 3 min -Bleed ressure -Floats held. i~ag~ 1t3 of 13 J Time Logs __ __ D to From To Dur S De th E. D th Phase Code Subcode T COM 09/26/2007 17:30 18:00 0.50 6,948 3,552 COMPZ CEMEf` PACK P Rotate to the right 5 rounds and set Hanger, Pump to 1000 psi and slowly PU to clear liner tool. Whem dogs are clear, maintain 30 spm and set dogs do 30k to LTP to set same. PU and set down 30k on LTP. Paker is set. 18:00 18:30 0.50 3,552 3,552 COMPZ CEME CIRC P Circu BU + down DP- PR 300 gpm, 700 psi - No cmt returns to surface. We did see a small amount of cutting and debris. - RU and reverse Circu pumping down annulas 1 full circulation +. 18:30 20:00 1.50 3,552 3,552 COMPZ CEME RURD P LD Baker cmt head, bleed hose and Cmt hose -Blow Down TD 20:00 22:00 2.00 3,552 0 COMPZ CEME TRIP P POOH standing back DP - LD running tool 22:00 22:30 0.50 0 0 COMPZ CEME RURD P Clean and clear rig floor of all e ui ment and tools. 22:30 22:45 0.25 0 0 COMPZ DRILL SFTY P PJSM -Discuss task at hand -Identify all know hazards and inch oints. 22:45 00:00 1.25 0 0 COMPZ DRILL PULD P LD 18 jts DP out of derrick 09/27/2007 00:00 00:15 0.25 0 0 COMPZ DRILL SFTY P PJSM -Discuss task at hand - Discuss all know hazards and pinch oints -Make sure work area is safe. 00:15 03:45 3.50 0 0 COMPZ DRILL PULD P Con't LD 4" DP out of derrick w/ mouse hole. Laid down 198 jts 4" Dp, 17 'ts 4" HWDP & Jars 03:45 04:15 0.50 0 0 COMPZ DRILL SFTY P Clean and clear rig floor. 04:15 04:30 0.25 0 0 COMPZ DRILL PULD P Install wear bushing (6.375" ID ) 04:30 04:45 0.25 0 0 COMPZ RPCOb RURD P RU tbg running equipment 04:45 10:30 5.75 0 6,828 COMPZ RPCO PULD P MU mule shoe - PU and run 210 jts 3.5" 9.3# L80 IBTM tbg, XO subs and 8 jts 4" DP -Tag LC @ 6828' MD ( Measurment by Tbg strap) Csg Detail de th 6822' MD 10:30 12:00 1.50 6,828 6,828 COMPZ RPCO CIRC P Circu and condition mud -Displace hole over to 8.4+ sea water 12:00 13:45 1.75 6,828 6,828 COMPZ RPCOh CIRC P Con't to displace to 8.5ppg sea water. Pumped total 498 bbls sea water. Returns clean. 13:45 14:15 0.50 6,828 6,828 COMPZ RPCOh OWFF P Observe Well -Static 14:15 15:00 0.75 6,828 6,828 COMPZ RPCOti RURD P RU power tongs and Tbg running e ui ment. 15:00 19:00 4.00 6,828 0 COMPZ RPCOh TRIP P POOH w/Tbg and Std Bk in derrick to run USIT to 19:00 19:30 0.50 0 0 COMPZ RPCOh RURD P Clean and clear all tools from rig floor. 19:30 20:00 0.50 0 0 COMPZ RPCOh SFTY P PJSM - Wireline hazards - RU wire line 20:00 23:00 3.00 0 0 COMPZ EVALV~ ELOG NP Run #1 - TIH w/ Wire line -Run USIT f/ 6790' to 4800' -Top of CMT @ 5300' - POOH Pa€~e 11 ~,f i3 C~ Time Logs __ Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/27/2007 23:00 00:00 1.00 0 0 COMPZ EVALVI~ ELOG NP Run #2 - MU Isolation Scanner tool 09/28/2007 00:00 02:30 2.50 0 0 COMPZ EVAL ELOG T Con't Logging #2 run -Running Isolation Scanner 02:30 03:00 0.50 0 0 COMPZ EVALVI~ RURD T RD Wireline equipment. 03:00 03:15 0.25 0 0 COMPZ CASIN( NUND P RU Test joint w/ puller - Retreive Wear bushin 03:15 03:30 0.25 0 0 COMPZ CASIN( PUTB P PJSM -Discuss Tbg running detail - Discuss all know hazards and pinch oints - 03:30 12:00 8.50 0 5,472 COMPZ CASIN( PUTB P PU and Run 180jts 3.5", 9.3#, L80, IBT-M SCC, er detail. 12:00 12:30 0.50 5,472 6,434 COMPZ CASIN PUTB P Con't running 3.5", 9.3#, L80, IBT-M SCC, SCSSV, 1- KBMG GLM, 4 - KBG2-9 GLM, and Baker SABL-3 production packer and anchor assy. Ran total 198 jts Tbg. Total of 70 stainless steel bands used on 1/4" SSV control line. 12:30 14:00 1.50 6,434 6,434 COMPZ CASIN PUTS P PU Landing jt & Hanger -Connect control line to hanger port - PU Landing jt -Blow down choke and Kill lines -Drain stack -Land Tbg com letion on han er -RILDS 14:00 14:45 0.75 6,434 6,434 COMPZ CASIN DHEQ P Pressure up 4500 psi set packer - PBRsheared @ 4200 psi -Bleed psi - BOLDS - P/U to verify PBR sheared "OK" - PU 80K. 14:45 15:30 0.75 6,434 6,434 COMPZ CASINC CIRC P Circu and spot 1 % Corrosion Inhibitor 10 bbl pill across PBR, PR 3 bpm, 360 si 15:30 16:30 1.00 6,434 6,434 COMPZ CASINC DHEQ P Land Tbg on hanger -RILDS -Test tbg to 2500 psi "OK", Hold 15 min on chart .Bleed tbg back to 1500 psi shut in. Pressure test 7" X 3.5" annulus to 2500 psi on chart and hold 30 min. "OK" 16:30 17:15 0.75 6,434 6,434 COMPZ CASINC DHEQ P Bleed pressure off Tbg and shear RP valve. Pump down tbg to verify shear"OK" Pressure up to 2500 on tbg and annulus and shut in same. Closed SSSV valve, bleed pressure off tbg. Hold 5 min. SSSV valve held "OK" 17:15 18:45 1.50 6,434 6,434 COMPZ CASIN( RURD P RD Landing jt. -Remove elevators & bails. Clear rig floor of all non-needed tools. 18:45 20:30 1.75 6,434 6,434 COMPZ CASIN NUND P ND BOPS and Adapter spool 20:30 23:00 2.50 6,434 6,434 COMPZ CASIN NUND P NU production tree and adapter. 4" - 5K-Orient to Flow Lines 23:00 00:00 1.00 6,434 6,434 COMPZ CASIN DHEQ P Test Hanger seals to 5000k for 10 min "OK" -Pull BPV -Set Tree test plug - Pre for test -Fill tree with diesel. 09/29/2007 00:00 00:45 0.75 0 0 COMPZ CASIN NUND P Test tree (Chart) 250 Low, 5000 psi high held 5 min "OK" -Pull tree plug - O en SSSV i t~~g~ ~2 raf 13 2Z-01A Post-Rig Summary DATE Summary 10/11/07 PULLED BALL & ROD, RHC PLUG @ 6422' RKB. PULLED DCK @ 6277' RKB, SET BTM LATCH DV. MITIA 3500 PSI, PASSED. DRIFTED TBG WITH 21' x 2.735" BARBELL DRIFT TO TD @ 6811' SLM. READY TO PERFORATE. 10/25/07 FCO'D LINER TO 6798' CTMD, PUMPED 290 BBLS SSW /125 BBLS DIESEL, WELL BORE LOADED WITH DIESEL FROM TD TO SURFACE, TURN WELL OVER TO DSO, READY FROM SLICKLINE. ((COMPLETE)) 10/28/07 REPLACED STA #1 DV WITH GLV .156" PORT,TRO=1340# @ 2780' RKB.STA #3 DV WITH GLV .156" PORT TRO=1320 @ 5104' RKB AND STA #5 DV WITH .188" ORFICE @ 6277' RKB. PERFORMED DRAWDOWN TEST ON IA- LOOKS GOOD. JOB COMPLETE. 11/12/07 ATTEMPTED TO PERFORATE 6732'-6752'. GUN MISFIRED. APPEARS MISFIRE CAUSED BY GUN FLOODING DUE TO BROKEN O-RING AT BOTTOM NOSE OF GUN. ALSO FLOODING DAMAGE TO SECURE DETONATOR. DIRECTED NEW GUN BE BUILT IN DEADHORSE TO FINISH THE JOB THE FOLLOWING DAY. 11/13/07 PERFORATED: 6732' TO 6752', 6 SPF WITH ALTERNATING BH & DP CHARGES, POWERJET & HYPERJET ~ POST PERF SBHP AT 6627'= 3158.4 PSIA, TEMP= 157.6 DEGF POST PERF SBHP AT 6742'= 3201.3 PSIA, TEMP= 160.9 DEGF 11/16/07 RAN PRODUCTION PROFILE WITH OILPHASE DOWNHOLE FLUID SAMPLING. RESULTS: TOOK FLUID SAMPLE AT 6731' JUST ABOVE TOP PERFORATIONS. GLM #5 LIFTING AT THE OV. TOP 12' OF PERFORATIONS PRODUCING HYDROCARBON FROM 6732-6744'. 11/18/07 BRUSHED TBG AND "X" NIPPLE. TAGGED AT 6814' SLM. SET EST AND GAUGES ON X LOCK AT 6422' RKB (13' OAL). *"""`NOTE: TOOLS PROGRAMMED TO SHUT IN WELL AT 1510 HRS, 11/20/07. DSO TO SHUT IN WING AND UG NO EARLIER THAN 1540 HRS. TOOL REOPENS AT 1510 HRS, 11/23/07. 11/25/07 PULL 2.75" "XX" LOCK, DHSIT AND GAUGES FROM 6422' RKB. JOB COMPLETE. 11/27/07 TAGGED @ 6812' SLM, OBTAINED SAMPLE. SET 2.75" PXX PLUG @ 6422' RKB, SET AVA STYLE CATCHER ON PLUG. PULLED OV @ 6277' RKB &GLVs @ 5104' & 2780' RKB. 11/28/07 SET DVs @ 5104', 2780' RKB, DID CIRC OUT 200 BBLS DIESEL, SET DV @ 6277' RKB, PASSED MITxIA, PASSED MITT, PULLED CATCHER @ 6422' RKB, PULLED 2.75" PXX PLUG @ 6422' RKB, DRIFTED HANGER W/ 2.93" GAUGE RING, "SET DOWN @ 6' SLM", SET FRAC SLEEVE @ 2106' RKB, RDMO. 11/30/07 A Sand fracture treatment flush job to completion, with 60 bbls including 47 bbls freeze protection. Pumped a total of 183500# of 16/20 carbolite 1300# left in WB with 12 PPA on formation 1616 bbl of SW, with an average pressure of 4856 psi. ISIP=3190 psi, 5 min pressure = 3143 psi. Estimated initial BHP = 3109 psi. 12/5/07 Utilize 75 bbls of flozan and 207 bbls of SSW to cleanout heavy frac sand down to PBTD @ 6815' CTMD (6822' RKB). Well left SI and freeze protected w/60 bbls of diesel. 12/7/07 Pulled ISO sleeve from SSSV @ 2106' RKB. Tagged @ 6751' SLM. Pull DVs @ 6277', 5104' & 2780' RKB. Set OV @ 6277', GLVs @ 5104' & 2780' RKB. Bled fluid-packed IA to verify GLVs set. Complete. • ;-~ ' ~r~nc~ctiPhi~lp-s Ataska, InC. 2z-off i nor i ~nnxnnos~m i wou Tvnc• I oRnn KRU 2Z-01 A nnnla fnl TR• I rian fnl 2Z-OlA SIDETRACK 3-''/z" TRMAXX-SE SSSV w/ 2.812" "X" profile (5.176" O.D.) @ +/- 2,106' MD 3-''/z" x 1" KBMG, (5.39" O.D.) IBTM,Camco GLM inside 7" 10-3/4" 45.5# K-55 casing @ 2,900' MD / 2,663' TVD TOL @ +/- 3,552' MD Sidetrack KOP w/window in 7" @ +/- 3,710' MD Baker "K-1" CIBP below set point for whipstock 3,727' I ~'ubing cmt retainer @ 6,686' MD Perfs @ ~~ 6,759' - 6,840' 'u~p @ 6,858' MD (removed) Bttm of tubing 6,903' MD I Tubing chemical cut @6,283' i st. TOC on 7" csg. @ 3,818' MD I i~ J I I . • 7" x 10-'/a" annulus Arctic packed in 1983 w/ 42 bbls cmt + 87 bbls diesel Est. TOC @ 2,040' MD . GLM Placement 2,779' 3-''/z" x 1" KBMG GLM (inside 7" csg.) 4,183' 3-'h" x 1" KBG2-9 GLM (inside 5-1/2" csg.) 5,104' 3-'/2" x 1" KBG2-9 GLM (inside 5-1/2" csg.) 5,815' 3-''/2" x 1" KBG2-9 GLM (inside 5-1/2" csg.) 6,276' 3-'h" x 1" KBG2-9 GLM (inside 5-1/2" csg.) (This mandrel will have the annulus to tubing shear) +/- 6,351' Tubing ~, 3-'h" 9.3#, L-80, IBT~VI w/ 3.865" O.D. Special Clearance couplin s i i t TOC @ +/- 5,300' MD I << I 2.75" "X„Nipple In tubing tail ' ;.. ' 3-1/2" x 5-1/2" ' Retainer Production Packer @ 6,372' MD I Estimated BHP 10.5 PPG ~ 5-1/2" 511 15.5# Casing set @ 6,948' MD • Halliburton Company Survey Report Company: G~nacoPhillips Alaska Ina Uate: 10/10/2007 Time: 10'37:36 P;ige: I Field: Kuparuk River Unit Co -n rdinafc(1E1 R efcrenre: Well: 2Z-01, True North Site: Kuparuk 2Z Pad ~ e rtical (T~'I)i fte fcrence: 2Z-01A (D141 ( 72.8+2°)1100.2 Well: 2Z-01 Sec tion I~~S) ILrG~ mncc Well (O.QON,O.OOE,177.05Azi) Wellpath: 2Z-01A Su n~ey (calculation ftitethod: Minimum Curva ture Ilh: Oracle Field: Kuparuk River Unit ___-- __ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 2Z-01 Slot Name: Well Position: +N/-S 0.00 ft Northing: 5966526.92 ft Latitude: 70 19 10.651 N ~ +E/-W 0.01 ft Easting : 529130.69 ft Longitude: 149 45 49.854 W Position Uncertainty: 0.00 ft -~ Wellpath: 2Z-01A Drilled From: 2Z-01 50-029-20953-01 Tie-on Depth: 3700.00 ft Current Datum: 2Z-01 A (D141 (7 2.8+28)) Height 100.80 ft Above System Datum: Mean Sea Level .- Magnetic Data: 9/14/2007 Declination: 23.08 deg j Field Strength: 57613 nT Mag Dip Angl e: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg -- 28.00 0.00 0.00 177.05 i Survey Program for Definitive Wellpath Date: 10/10/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 91.80 3691.80 2Z-01 (91. 80-7491.80) (0) BOSS-GYRO Sperry-Sun BOSS gyro multishot 3710.00 6913.00 2Z-01A (3710.00-69 13.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Intl ~zim T~'I1 Sys TVD \iS E~~~ ~I.~~iA MapE ~I~nol ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -72.80 0.00 0.00 5966526.92 529130.69 - TIE LINE j 91.80 0.42 112.40 91.80 -9.00 -0.09 0.22 5966526.83 529130.91 BOSS-GYRO 191.80 0.33 111.90 191.80 91.00 -0.34 0.82 5966526.59 529131.51 BOSS-GYRO 291.80 0.37 113.20 291.80 191.00 -0.57 1.39 5966526.36 529132.08 BOSS-GYRO 391.80 0.42 105.20 391.79 290.99 -0.79 2.04 5966526.14 529132.73 BOSS-GYRO I 491.80 0.45 101.20 491.79 390.99 -0.97 2.78 5966525.97 529133.47 BOSS-GYRO 591.80 0.38 84.19 591.79 490.99 -1.01 3.49 5966525.93 529134.18 BOSS-GYRO 691.80 0.27 97.11 691.79 590.99 -1.00 4.05 5966525.93 529134.75 BOSS-GYRO ~ 791.80 0.25 90.90 791.78 690.98 -1.04 4.51 5966525.90 529135.20 BOSS-GYRO 891.80 0.42 115.31 891.78 790.98 -1.20 5.06 5966525.75 529135.75 BOSS-GYRO 991.80 1.25 151.61 991.77 890.97 -2.31 5.91 5966524.63 529136.60 BOSS-GYRO 1041.80 2.22 168.00 1041.75 940.95 -3.74 6.37 5966523.21 529137.07 BOSS-GYRO 1091.80 3.85 178.70 1091.68 990.88 -6.37 6.61 5966520.58 529137.32 BOSS-GYRO 1141.80 5.18 180.60 1141.52 1040.72 -10.30 6.62 5966516.65 529137.35 BOSS-GYRO 1191.80 7.03 179.81 1191.24 1090.44 -15.62 6.61 5966511.33 529137.36 BOSS-GYRO 1241.80 j~8.75 179.50 1291.80 10.75 182.50 1240.76 1290.04 1139.96 1189.24 -22.48 -30.94 6.65 6.48 5966504.47 529137.43 5966496.01 529137.29 BOSS-GYRO BOSS-GYRO 1341.80 '12.43 183.89 1339.01 1238.21 -40.97 5.91 5966485.98 529136.76 BOSS-GYRO 1391.80 x,4.15 184.89 1387.67 1286.87 -52.43 5.03 5966474.52 529135.92 BOSS-GYRO i 1441.80 16.13 187.00 1435.94 1335.14 -65.42 3.66 5966461.53 529134.60 BOSS-GYRO 1491,80 17.60 187.89 1483.78 1382.98 -79.80 1.77 5966447.14 529132.77 BOSS-GYRO 1541.80 19.65 187.50 1531.16 1430.36 -95.62 -0.36 5966431.31 529130.70 BOSS-GYRO 1591,80 21.47 186.10 1577.98 1477.18 -113.06 -2.43 5966413.87 529128.70 BOSS-GYRO 1641.80 23.12 185.60 1624.24 1523.44 -131.93 -4.36 5966394.99 529126.84 BOSS-GYRO 1691.80 24.37 185.89 1670.00 1569.20 -151.96 -6.38 5966374.96 529124.90 BOSS-GYRO 1741.80 25.37 186.10 1715.37 1614.57 -172.87 -8.58 5966354.04 529122.79 BOSS-GYRO 1791.80 26.50 .186.80 1760.33 1659.53 -194.60 -11.03 5966332.30 529120.41 BOSS-GYRO 1841.80 27.32 187.39 1804.92 1704.12 -217.06 -13.83 5966309.84 529117.70 BOSS-GYRO 1891.80 27.68 187.30 1849.27 1748.47 -239.95 -16.78 5966286.93 529114.84 BOSS-GYRO • Halliburton Company Survey Report __ Company: ConocoPhillips P,laska Inc. note: 10/10!2007 time: 10:37:36 Page: Ficlct: Kuparuk River Unit Co-ordinate(NE) Reference: WeIL 2Z-01`°True North ~itr: Kuparuk 2Z Pad Vertical (TVA) Reference: 2Z 01A (D14i (72.8+28)) 100.3 ~'~ WeII: 2Z-01 Section (VS)I2eE'erence: Well (O.OON,O.OOE,177.05Azi) Wellpath: 2Z-01A Survey Calcai:~tian Dlcthod: Minimum Curvature I)h: Oracle _____ Sung vin Intl lzim llD SysT~~l) V/S E1l~' ~1;ip,~ vlanE Tool ft deg dey ft ft ft ft ft ft -- _ _---- ,I 1941.80 28.67 187.69 1893.34 1792.54 -263.36 -19.86 5966263.51 529111.85 BOSS-GYRO 1991.80 29.25 188.30 1937.09 1836.29 -287.33 -23.23 5966239.53 529108.58 BOSS-GYRO 2041.80 29.52 189.00 1980.66 1879.86 -311.59 -26.92 5966215.26 529104.98 BOSS-GYRO 2091.80 29.87 189.10 2024.09 1923.29 -336.05 -30.82 5966190.79 529101.18 BOSS-GYRO 2141.80 31.85 189.80 2067.01 1966.21 -361.34 -35.03 5966165.48 529097.06 BOSS-GYRO i 2191.80 33.52 190.10 2109.09 2008.29 -387.94 -39.70 5966138.87 529092.50 BOSS-GYRO 2241.80 34.88 190.19 2150.44 2049.64 -415.60 -44.65 5966111.19 529087.66 BOSS-GYRO 2291.80 36.30 190.60 2191.10 2090.30 -444.22 -49.90 5966082.55 529082.52 BOSS-GYRO 2391.80 39.43 191.10 2270.04 2169.24 -504.50 -61.46 5966022.24 529071.19 BOSS-GYRO 2491.80 40,12 191.39 2346.90 2246.10 -567.24 -73.94 5965959.45 529058.96 BOSS-GYRO 2591.80 40.00 191.69 2423.43 2322.63 -630.30 -86.82 5965896.35 529046.33 BOSS-GYRO 2691.80 39.58 191.60 2500.27 2399.47 -692.98 -99.73 5965833.63 529033.66 BOSS-GYRO 2791.80 39.72 191.69 2577.27 2476.47 -755.48 -112.61 5965771.09 529021.02 BOSS-GYRO 2891.80 39.33 192.89 2654.40 2553.60 -817.66 -126.16 5965708.86 529007.72 BOSS-GYRO 2991.80 39.82 192.80 2731.48 2630.68 -879.77 -140.32 5965646.70 528993.80 BOSS-GYRO 3091.80 39.63 193.19 2808.39 2707.59 -942.05 -154.69 5965584.38 528979.67 BOSS-GYRO 3191.80 39.42 193.19 2885.53 2784.73 -1004.01 -169.21 5965522.36 528965.39 BOSS-GYRO 3291.80 39.07 193.00 2962.97 2862.17 -1065.63 -183.55 5965460.70 528951.30 BOSS-GYRO 3391.80 38.87 193.10 3040.72 2939.92 -1126.90 -197.75 5965399.38 528937.34 BOSS-GYRO ~ 3491.80 38.53 193.00 3118.76 3017.96 -1187.80 -211.87 5965338.42 528923.46 BOSS-GYRO 3591.80 38.20 193.00 3197.17 3096.37 -1248.28 -225.83 5965277.90 528909.73 BOSS-GYRO i 3691.80 37.92 192.80 3275.91 3175.11 -1308.37 -239.59 5965217.76 528896.20 BOSS-GYRO 3710.00 37.86 192.80 3290.27 3189.47 -1319.27 -242.07 5965206.85 528893.77 MWD+IFR-AK-CAZ-SC 3747.38 37.23 191.50 3319.91 3219.11 -1341.54 -246.86 5965184.57 528889.06 MWD+IFR-AK-CAZ-SC 3841.17 33.72 187.89 3396.29 3295.49 -1395.15 -256.10 5965130.93 528880.03 MWD+IFR-AK-CAZ-SC 3934.48 31.34 183.76 3474.96 3374.16 -1445.03 -261.25 5965081.03 528875.08 MWD+IFR-AK-CAZ-SC 4028.50 29.38 178.94 3556.10 3455.30 -1492.50 -262.42 5965033.56 528874.09 MWD+IFR-AK-CAZ-SC 4122.59 26.94 177.00 3639.04 3538.24 -1536.87 -260.88 5964989.20 528875.80 MWD+IFR-AK-CAZ-SC 4215.80 26.28 173.02 3722.39 3621.59 -1578.44 -257.27 5964947.65 528879.58 MWD+IFR-AK-CAZ-SC 4309.57 23.31 168.73 3807.51 3706.71 -1617.25 -251.12 5964908.87 528885.88 MWD+IFR-AK-CAZ-SC ~ 4403.31 22.18 167.46 3893.96 3793.16 -1652.72 -243.65 5964873.44 528893.48 MWD+IFR-AK-CAZ-SC 4497.26 20.53 156.57 3981.49 3880.69 -1685.16 -233.24 5964841.04 528904.01 MWD+IFR-AK-CAZ-SC 4589.01 19.91 151.18 4067.59 3966.79 -1713.61 -219.31 5964812.64 528918.05 MWD+IFR-AK-CAZ-SC 4684.90 19.95 145.08 4157.75 4056.95 -1741.33 -202.08 5964784.99 528935.39 MWD+IFR-AK-CAZ-SC 4778.64 19.01 141.49 4246.13 4145.33 -1766.39 -183.42 5964760.01 528954.15 MWD+IFR-AK-CAZ-SC 4872.77 18.93 139.93 4335.14 4234.34 -1790.07 -164.04 5964736.40 528973.61 MWD+IFR-AK-CAZ-SC 4966.38 18.71 139.83 4423.75 4322.95 -1813.17 -144.58 5964713.39 528993.16 MWD+IFR-AK-CAZ-SC 5059.82 18.94 142.74 4512.19 4411.39 -1836.69 -125.73 5964689.94 529012.10 MWD+IFR-AK-CAZ-SC ~ 5153.00 18.73 144.39 4600.38 4499.58 -1860.89 -107.87 5964665.82 529030.06 MWD+IFR-AK-CAZ-SC ~, 5248.34 19.78 143.52 4690.39 4589.59 -1886.30 -89.36 5964640.47 529048.66 MWD+IFR-AK-CAZ-SC 5341.28 19.82 145.68 4777.84 4677.04 -1911.96 -71.13 5964614.89 529066.99 MWD+IFR-AK-CAZ-SC 5436.33 21.27 150.33 4866.85 4766.05 -1940.25 -53.51 5964586.67 529084.72 MWD+IFR-AK-CAZ-SC 5530.98 22.09 152.35 4954.80 4854.00 -1970.94 -36.75 5964556.05 529101.59 MWD+IFR-AK-CAZ-SC 5623.77 22.62 152.43 5040.62 4939.82 -2002.21 -20.39 5964524.85 529118.07 MWD+IFR-AK-CAZ-SC 5718.07 22.46 152.93 5127.71 5026.91 -2034.32 -3.80 5964492.80 529134.78 MWD+IFR-AK-CAZ-SC 5810.50 23.42 156.52 5212.84 5112.04 -2066.90 11.55 5964460.29 529150.26 MWD+IFR-AK-CAZ-SC 5903.71 25.86 163.12 5297.57 5196.77 -2103.35 24.84 5964423.89 529163.69 MWD+IFR-AK-CAZ-SC 5997.00 26.22 167.28 5381.40 5280.60 -2142.93 35.29 5964384.36 529174.29 MWD+IFR-AK-CAZ-SC 6090.12 26.61 170.55 5464.80 5364.00 -2183.57 43.24 5964343.76 529182.40 MWD+IFR-AK-CAZ-SC 6184.99 28.14 169.38 5549.04 5448.24 -2226.52 50.85 5964300.84 529190.18 MWD+IFR-AK-CAZ-SC 6276.89 28.64 168.04 5629.89 5529.09 -2269.36 59.41 5964258.03 529198.90 MWD+IFR-AK-CAZ-SC 6373.37 31.24 164.85 5713.49 5612.69 -2316.14 70.74 5964211.30 529210.41 MWD+IFR-AK-CAZ-SC j Halliburton Company Survey Report Cump:in~-: Con~soPhlllips A.laSka InC. Uate: 10!10/2007 Time: 10:37'36 Page: 3 field: Kuparuk Rlver Unit Co-o rd in:~tc(NE)Reference: Well: 2Z-O1, True North Site: Kuparuk 2Z Pad ~~n-tic:al (7~~"D) Reference: 2Z-01A (D141 (72.8+2E}) 100.8 ~~'ell: 2Z-01 ticction~~ti~Reference: Well (O.QON.O.OOE,177.05Azi) ~~cllpath: 2Z-01A SurveyCakulationMethod: Minimum,Gurvature Db: Oracie tiur~ e~ AID Inc! ~ lzim l~~`U Sy, "fell ~lS E/W ft deg deg ft ft ft ft 6465 .42 30.98 168.74 5792. 31 5691. 51 -2362. 42 81. 61 6560 .50 29.97 169.74 5874. 26 5773. 46 -2409. 79 90. 62 6652 .15 30.11 167.87 5953. 60 5852. 80 -2454. 79 99. 52 6744 .22 29.44 167.75 6033. 51 5932. 71 -2499. 49 109. 18 6840 .14 26.28 164.84 6118. 31 6017. 51 -2543. 03 119. 74 6913 .00 27.87 163.53 6183. 18 6082. 38 -2574. 93 128. 78 .6950 .00 27.87 163.53 6215. 89 6115. 09 -2591. 52 133. 69 11apA _- - ~'Tapf foul ft ft 5964165.07 529221.46 MWD+IFR-AK-CAZ-SC 5964117.74 529230.65 MWD+IFR-AK-CAZ-SC 5964072.78 529239.73 MWD+IFR-AK-CAZ-SC 5964028.13 529249.56 MWD+IFR-AK-CAZ-SC 5963984.63 529260.28 MWD+IFR-AK-CAZ-SC 5963952.77 529269.45 MWD+IFR-AK-CAZ-SC 5963936.20. 529274.42 e PROJECTED to TD 19-Nov-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2Z-01A Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,691.80' MD Window /Kickoff Survey 3,710.00' MD (if applicable) Projected Survey: 12,073.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~~ Date ~ ~`c~7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment{s) u ~? -~ i ~ 1 11 /26/07 ~~~~~~~i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.4513 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2N-310 11839685 PERF RECORD/SBHP SURVEY r~ F^':~ -",w'_~, "•", 11/17/07 1 2Z-01A 11837536 PRODUCTION PROFILE '?~j""~ --' 11/16/07 1 3R-14 11839686 LDL ~~- `.> -- '°~.r~"~ 11/18/07 1 2M-10 11839687 PRODUCTION PROFILE ?~=), `°' ~ 11/19/07 1 3J-10 11837539 PRODUCTION PROFILE is <~4 °~-~,1~`" l' % 11/19/07 1 2A-20 11839688 INJECTION PROFILE ~-=,:,~a ~~> %° .- w ='° - ~ 11/20/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~Q1"tOCt~~l1~~1 5 TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: 2Z-01A DATE: 10/23/2007 Tarn 2Z-01A ~~~~ /~~, E~1 '~- ~~~Tei~. k ~£ ~~;s~ ~ ~. q~~S ~, c ~~ ~, :: ; ~~, TO: Christine Mahnken AOGCC 333 W. 7~' Ave., Suite 100 Anchorage, Rlaska 99501-3539 Report, color mudlog prints, CDROM Epoch End of Well Report, 2Z-01 A, O'Fallon/Winkelman, 09/2412007; table of contents, equipment and crew, well details, geological data, pressure/formation, drilling data, daily reports, formation logs: Formation MD, TVD; LWD Combo MD and TVD; gas ratio MD and TVD; Drilling dynamics MD and TVD. CDrom contains: Final welt report, morning reports, LAS data, pdf files, DML data; remarks files. Please check off each item as received, promptly sign and return transmittal if not done at time of data delivery. To al/ data recinients.~ All data is confidentia/until State ofA/aska designated ADGCC release date CC: Derik Kleibacker, CPAI Geolo ist ~ ~' ~ / g ~ ~ f r OCT ~ 4 2007 Receipt: ~ Date: alaska Uii has tort, ~c~r~rry;issic~, 1~{~-~- GIS-Technical Data Management ~ C~c~i~t~iil/ips (Anchorage, A/aska ~ Ph,• 9D7.265.6947 Sandra.D.LemkeCa~Conoco~hillips com c~0~ -III ~ 155 Cos 10/15/07 i ~,,,,k~x~_ - Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ` 'S C - 08108107 1 1 B-14 11837493 PRODUCTION PROFILE ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE (7- 08130107 1 1Y-18 11837499 PRODUCTION PROFILE C ' - 08130107 1 1G-14 11839652 INJECTION PROFILE ~ ~ ?j- 08/31/07 1 1A-01 NIA USIT - 08131/07 1 1Y-04 11839653 INJECTION PROFILE f'~ ~ 09/01107 1 1Y-32 11839655 PRODUCTION PROFILE '`6 - 09102/07 1 2T-TAB-01 11839656 INJECTION PROFILE C. - - 09/03/07 1 2K-25 11846439 INJECTION PROFILE U = f 09/06/07 1 2K-18 11846440 INJECTION PROFILE / -~ 09107/07 1 1B-18 11846441 PRODUCTION PROFILE ~/- (p 09108/07 1 2T-20 11846442 PRODUCTION PROFILE ~ 's - 09/09107 1 2N-310 11850433 SONIC SCANNER ~b'~-(~ b 09/16107 1 2N-310 11850433 SONIC SCANNER-FMI "~ - C~`~ (~ 09/16107 1 1J-176 11846443 USIT "~ -p 09117107 1 1E-29 NIA UCI ~ - ~ 09/19/07 1 3F-21 11837503 RSTI WFL - 09/20107 1 2B-10 11839661 INJECTION PROFILE ~ - 09/22/07 1 1G-05 11837506 INJECTION PROFILE ~J ~ t_` . 09/23107 1 2H-13 11839662 INJECTION PROFIL ~ - 09/23107 1 16-05 11837508 INJECTION PROFILE LC" 09124/07 1 3H-08 11839663 PRODUCTION PROFILE - ~ 09/24107 1 1Y-31 11839664 PRODUCTION PROFILE ~ ri` - 09125107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - (( 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER ~<(_ 09128/07 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE - 6 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. i • ~ ~ I- SARAH PALIN GOVERNOR ~~..~~ t DiI[1-7~ O~ oisD ~ 333 W. 7th AVENUE, SUITE 100 CO1QSFiRQA'1'IO1Q COMDiISSIOI~T ~ pHONE~ 907) 279-114339501-3538 { FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2Z-OlA ConocoPhillips Alaska, Inc. Permit No: 207-111 Surface Location: 1770' FSL, 577' FEL, SEC. 11, T11N, R09E, UM Bottomhole Location: 4269' FSL, 391' FEL, SEC. 14, T11N, R09E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9079-3607 (pager). J DATED this day of August, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 285-6830 Fax: (907) 265-1535 Email: randy.I.thomas@conocophillips.com August 13, 2007 Alaska Oil and Gas Conservation Commission 333 West 7`~ Avenue Suite 100 Anchorage, Alaska 99501 (907)279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 2Z-OlA Dear Commissioner: ~iaska Jii ~ Gas Cons. Commissio Anchorage r ConocoPhillips Alaska, Inc, hereby applies for a Permit to DrilUSidetrack an onshore Producer well, KRU 2Z-OlA, a development well. It is planned to abandon the original wellbore then set a CIPB at +/- 3,700" MD and place a permanent whipstock on top of the CIBP with the whipstock at +/- 3,700' MD. We will then cut and mill a window in the existing 7" production casing with a planned KOP point from the 7" casing is +/- 3,700' MD. The existing 7.0" casing cement job from the original wellbore did not bring the top of cement up as high as the window. The current plan is to mill the window and perform a FIT test/ Leak off, which ever comes first, with a required minimum of 11.5 ppg EMW. ** If the FIT/LOT is too low, a squeeze cement job will be performed placing cement on top of the whipstock and in the milled window and a second FIT/LOT will be performed. After a successful FIT/LOT test the intermediate section will be drilled with a 6" bi-center bit, opening up to 7" Kuparuk C sand and stop at the TD depth of 7,317' (below the A sand). . The logging program will consist of a Quad Combo: Gamma Ray/ Resistivity/Density/ Neutron/Sonic for the entire drilled interval. -`~' The spud date is expected to be approximately September 15`i`, 2007. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincere /'` r~~` t( ~ • / rLCj ~t~~ omas GKA Drilling Team Leader ~c~~vE~ L~~ ~ ~ zoos ~~~ STATE OF ALASKA ~ AU G 1 4 200? ALASKA OIL AND GAS CONSERVATION COMMISSION ~ A4aska Oil & Gas Cons. Commissio PERMIT TO DRILL anchorage 20 AAC 25.005 1a. Type of Work: Drill ^ Re-drill 0 Re-entry ^ 1b. Current Well Class: F~cploratory ^ Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 2Z-01A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 7317' ' ND: 6525' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1770' FSL, 577' FEL, Sec. 11, T11 N, R09E, UM 7. Property Designation: ADL 25653 Kuparuk Oil Pool Top of Productive Horizon: 4550' FSL, 455' FEL, Sec. 14, T11 N, R09E, UM 8. Land Use Permit: ALK 2579 13. Approximate Spud Date: 9/15/2007 Total Depth: 4269' FSL, 391' FEL, Sec. 14, T11 N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529131 y- 5966527 ~ Zone- 4 10. KB Elevation (Height above GL): 102' AMSL ~ feet 15. Distance to Nearest v ~~ 2 ~„ -/~ Well within Pool: 2Z- , ~35' at 6674' 16. Deviated wells: Kickoff depth: 3700' ft. ' Maximum Hole Angle: 40° ~ deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.oas) ~, Z~ Downhole: 3315 psig' Surface: 2652 psig 7 18. Casing Program if S ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 7" 5.5" 15.5# L-80 511 3817' 3500' 3125' 7317' 6525' 300 sx Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 305 sx AS II 80' 80' Surface 2791' 10-3/4" 1200 sx Fondu, 250 sx PF C 2900' 2663' Intermediate 7450' 7" 550 sx Class G, 250 sx PF C 7559' 6582' Production Liner Perforation Depth MD (ft): 6759'-6840', 6974'-6978', 6987'-7016' Perforation Depth ND (ft): 5890'-5963', 6083'-6086', 6094'-6120' 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name ~R dy Thomas ® _ Title Drilling Team/Leader Signature ~~~` ll~--~v~~- "~i'l ~ /~~G~" Phone~tJJ~""~~~b Date G ~y (S~ D nAI D k Commission Use Only Permit to Drill ~] / Number: ~ / ~ / l ~ API Number: 50-~Z! _ ~jq~,3•o/ Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ne, gas hydrates, or gas contained in shales: amples req'd: Yes ^ No M o req'd: Yes ^ No Other: t ;5®~ ~~ ~ ~ ~S~ QS Q 2S measures: Yes 1[~ No it na v req'd: Yes [~ No ^ C/ /~ ' O~ PROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 Sub it in ~Dyuplicate 6~ ~./ d7 • Application for Permit to Drill, Well 2Z-01A Revision No.O Saved: 14-Aug-07 Permit It - Kuparuk We112Z-OlA Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................................2 Requirements of 20 AAC 25.005 (~ .................................................... ................................................................... 2 2. Location Summary ................................:................................:................................:................2 Requirements of 20 AAC 25.005(c)(2) ........:....................................... ................................................................... 2 Requirements of 20 AAC 25.050(b) .................................................... ................................................................... 2 3. Blowout Prevention Equipment Information ........................................................................3 Requirements of 20 AAC 25.005(c)(3) ............................................... .................................................................... 3 4. Drilling Hazards Information .................................................................................................3 Requirements of 20 AAC 25.005 (c)(4) ............................................... ................................................................... 3 5. Procedure for Conducting Formation Integrity Tests .........................................................3 Requirements of 20 AAC 25.005 (c)(S) .............................................. .................................................................... 3 6. Casing and Cementing Program ............................................................................................3 Requirements of 20 AAC 25.005(c)(6) ............................................... .................................................................... 3 7. Diverter System Information ..................................................................................................4 Requirements of 20 AAC 25.005(c)(7) ............................................... .................................................................... 4 8. Drilling Fluid Program ............................................................................................................4 Requirements of 20 AAC 25.005(c)(8) ............................................... .................................................................... 4 9. Abnormally Pressured Formation Information ....................................................................4 Requirements of 20 AAC 25.005 (c)(9) .............................................. .................................................................... 4 10. Seismic Analysis .......................................................................................................................4 Requirements of 20 AAC 25. DOS (c)(10) ............................................ ...................................:................................ 4 11. Seabed Condition Analysis ......................................................................................................4 Requirements of 20 AAC 25.005 (c)(11) ............................................ .................................................................... 4 12. Evidence of Bonding ................................................................................................................5 Requirements of 20 AAC 25.005 (c)(12) ............................................ .................................................................... S 13. Proposed Drilling Program .....................................................................................................5 Requirements of 20 AAC 25.005 (c)(13) ............................................ .................................................................... S 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................6 ORIGINAL 2Z-01A PERMIT IT Page 1 of 6 Application for Permit to Drill, Well 2Z-01A Revision No.O Saved: 14-Aug-07 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................................ 6 15. Attachments ..............................................................................................................................6 Attachment 1 Directional Plan ............................................................................................. 6 Attachment 2 Well Schemaics .............................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2Z-OlA. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ident~'ed in the application: (2) a plat ident~ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,770' FSL, 577' FEL, Sec 11, T11N, R09E, UM ` NGS Coordinates RKB Elevation 102.3' AMSL ` Northings: S, 966, 527 'Eastings: 529,131 - Pad Elevation 72.3' AMSL ` Location at Top of Productive Interval (Ku aruk A-4 Sand) 4,550' FSL, 455' FEL, Sec 14, T11N, R09E, UM NGS Coordinates Measured De th, RKB: 6,740' Northings: 5,964,028 Eastings: 529,265 Total Vertical Depth, RKB: 6,025' Total Vertical De th, SS: 5,925' Location at Total De th 4,269' FSL, 391' FEL, Sec 14, T11N, R09E, UM NGS Coordinates Measured Depth, RKB: 7,317' Northings: 5,963,747 Eastings: 529,330 Total Vertical Depth, RKB: 6,525' Total Vertical Depth, SS: 6,425' and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (IJ include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including al[ adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by cert~~ed mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. ORIGINAL 2Z-01A PERMIT IT Page 2 of 6 • Application for Permit to Drill, Well 2Z-01A Revision No.O Saved: 14-Aug-07 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permitto Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of thz following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine tt, and maximum potential surface pressure based on a methane gradient; BHP data on offset injectors indicates that the current reservoir pressure for 2Z-OlA is < 3,500 psi at 6,200' TVDSS (6,324' TVD), 0.55 psi/ft or 10.6 ppg EMW. -"' The maximum potential surface pressure (MPSP) while drilling 2Z-OlA is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6,027' TVD: MPSP = (6,027 ft)*(0.55 - 0.11 psi/ft) = 2,652 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dri[I must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conductingformation integrity tests, as required under 20 AAC 2~.030(fl; A procedure is on file with the commission for performing LOT's. For 2Z-OlA the procedure will be followed after milling the window, with one exception. The formation at the window depth will be pressured until leak-off occurs or to 15.0 ppg EMW is reached, which ever comes first. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed Casin and Cementin Pro ram Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Length t) Top MD%1'VD (ft) Btm MD/TVD (ft) Cement Program Ori final Wellbore 2Z-Ol 3,125' 13-1/2 45.5 K-55 2,900' surface 2,900' / 2,663' 7" 8-1/2 26 J-55 BTC 7,559' surface 7,559' / 6,582' =Est TOC 3,818' MD 3-1/2 Tubing 9.3 J-55 BTC 6,848' surface 6,848' / 5,970' 2Z-OlA Sidetrack Plan 7" window 8-1/2" 26 J-55 BTC 3,700' surface 3,700' / 3,282' 5.5" flush jt 7" 15.5 L-80 511 3,817' 3,500' / 3,125' 7,317'/ 6,525' 300 sx 15.8 Class G, 1.17 ft3/sk 3-1/2 Tubing 4.75" 9.3 L-80 511 surface 6 130' / 5,544' Packer/PBR w/ wireline entry guide stung below the ZXP OR161NAL 2Z-01A PERMIT /T Page 3 of 6 Application for Permit to Drill, Well 2Z-01A Revision No.O Saved: 14-Aug-07 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an hens already onfile with the commission and ident~~ed in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); This rotary sidetrack will exit pre-existing casing at + 3,700' MD. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) A» application for a Fermit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drillingfluid system, as required by 20 AAC 25.033; Drilling will be done using a LSND mud systems having the following properties: Sidetrack Hole mud ro erties Initial Drillout KOP TD Depth MD/TVD 3,700' MD 7,317 MD / 6,525' TVD Density (ppg) 9.6 - 10 11.3 Funnel Viscosity (seconds) 45 - 55 48 - 56 Yield Point (cP) 22 - 29 22 - 29 Plastic Viscosity (-b/100 s~ 12 - 22 19 - 24 10 second Gel Strength (lb/100 sf) 4 - 8 6 - 10 10 minute Gel Strength (Ib/100 sfj 6 - 15 10 - 15 pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) <6 <6 Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accornpassied by each of the following items, except for an item already on file with the commission and identified iss the application: (9J for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(fl; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) - An application for a Permit to Drill must be accompanied by each of tlse following items, except for ms item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic s•efi•actiass or reflection analysis as required by 20 AAC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Pernsit to Drill must be accompanied by each of the following items, except for ass item ab•eady on file with the commission and ident~ed in the application: (11) for a well drilled from an offshore platform, nsobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); 2Z-01A PERMIT IT Page 4 of 6 Application for Permit to Drill, Well 2Z-01A Revision No.O Saved: 14-Aug-07 N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) gn application for a Permit to Drill must he accompanied by each of the following items, esceptfor an item already on file with the commission and identified in the application: (12) evidence showi»g that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Pre-Rig Well Work: NOTE: test IA +/- 2 weeks prior to rig moving -Wells to supervise that work 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. RU CTU RIH with Inflatable bridge plug and set at 6,600' MD with the top perforations at 6,759'. 3. Squeeze off perforations. Pull above and lay in 50' of cement above plug. 4. Wait 24 hrs. RU Slickline and tag cement plug, pull OV, load IA and tubing with seawater. 5. CMIT against cement plug. (AOGCC present as witness) 6. Freeze protect well with diesel to 2500' MD. 7. RU E-line and chemical cut tubing (below bottom GLM above retainer) 8. Set BPV and VR plug. Current Wellhead: FMC Gen II, 11"x 3K, 7-1/16" x 3K Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MURU Doyon 141. Install blanking plug on top of the back pressure valve. 2. NU and test the 11"x SK BOPE to 250# / 3500#. 3. Engage the 3-1/2" tubing with a spear. L/D the tubing hanger and pull a113-1/2" tubing. 4. Set storm packer. 5. N/D BOP's. Remove FMC Gen II tubing head and replace it with a 11"x 3M x 11"x SM spool. 6. NU Bop's to the 11", 5000 psi flange on the FMC Gen II system & test 250 psi & 3500 psi. 7. PU mill, casing scraper, and 4" DP and RIH to top of tubing stub. POOH. 8. RU wireline set a CIBP inside the 7" casing at +/- 3,700' MD based on casing collar depth. (Note: CIBP must be >_ 2.0' above a casing collar and > 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. Test okay. (If not contact Engineer- discuss will have to get packer and RIH and attempt to find hole in casing.) 9. PU and RIH with Baker's "WindowMaster" whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP set at 3,700' MD. 10. Orient whipstock 45 degrees left of high side, shear off, and POOH. n) ~ ~ 2Z-01A PERMIT IT 'v Page 5 of 6 • Application for Permit to Drill, Well 2Z-01A Revision No.O Saved: 14-Aug-07 11. Displace 8.8 ppg Brine from hole with 9.6 ppg LSND new mud to mill window. Mill window and dri1120' new formation. Dress window. Pump super sweep pill. 12. Perform FIT/LOT. POOH and LD window mill etc. 13. PU bi-center bit & BHA, 4.0" DP, and RIH. ' V~Z.~Z U.(jp~C(4.~ --~~ 14. Drill to TD (7,317' MD / 6,525' TVD). MW expected to be 10.5 to 10.8 ppg. ` > \ ~ 15. POOH & rig up wire line logs. Log with a Dipole Sonic tool from TD to window. U~~ 16. PU 5.5" flush joint liner and RIH. Liner overlap into 7" casing needs to be > 150'. 17. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. Cement the liner bringing cement to above 5,130' MD. 18. Release from liner. Set packer. 19. Displace the well above the TOL with seawater until the returns are clean. Check for flow. POOH. LD/DP. 20. Set storm packer and change out the 11"x3 by 7-1/16" x SM spool and then re-run the tbg head. 21. R/U and RIH with the 3-1/2" tubing tag the TOL. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 3500 psi. Bleed off all pressures. 22. Install a TWC. ND BOPE. NU and test the 3-1/8" (SM) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to + 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid. Install a BPV. R/D and M/O Doyon Rig 141. Post-Rig Well Work: 1. Pull the BPV. R/U SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. 4. Perforate the Kuparuk as directed. R/D E-Line. 5. Install new "S" riser and replace the well house(s). 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission mxd identifted in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation i~a the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary JRIGINAL 2Z-01A PERMIT IT Page 6 of 6 • • Plan: 2Z-01A (wp06) Sperry Drilling Services Proposal Report -Geographic 09 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 2Z Pad 2Z-01 2Z-01 A Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Site Kuparuk 2Z Pad D141 (72.3+28) @ 100.30ft N True API - US Survey Feet Sperry Grilling Servricee ORIGINAL 538 1077 ~""~~ 1615 ~....~/ «--y~y ^ 2154 /r~j c .~..~.. ~ /~'°1 p 2692 ~,J J v .,..~.~ t 3231 O 3769 a~ 4308 H 6462 WELL DETAILS: 2Z-Ol NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level; 72.30 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.00 O.OI 5966526.92 529130.69 70°19'10.651N l49°45'49.854W `' ~ FORMATION TOP DETAILS / \ / \ No. TVDPath TVDSS MDPath Formation 1 5825.30 5725 6508.85 C4 2 5855.30 5755 6543.49 C3 3 5868.30 5768 6558.50 C2 4 5885.30 5785 6578.13 C1 5 5898.30 5798 6593.14 Top B 6 6015.30 5915 6728.24 A5 7 6025.30 5925 6739.79 A4 8 6070.30 5970 6791.75 A3 9 6115.30 6015 6843.71 Base Kupar CASING DETAILS No MD TVD TVDss Name 1 2891.30 2653.91 2553.61 10 3/4" 2 3700.00 3282.27 3181.97 7" 3 7317.00 6525.18 6424.88 51/2" KOP - 7" Casing - 3700' MD; 3282.27' TVD :FSL 456.57', FEL 819.66' - SEC11 - T11 N - R09E 7 5-1/2 Total Depth - 5-1/2" Casing :7317.14' MD; 6525.3' TVD :FSL 4268.96', FEL 390.9' : SEC14 - T11N - R0~ X01 2ti T1 (wp06) -2154 -1615 -1077 -538 -0 538 1077 1615 2154 2692 3231 3769 4308 4846 5385 5923 6462 7000 7538 8077 8615 9154 9692 10231 10769 Vertical Section at 188.81 ° (1400 ft/in) Project: Kuparuk River Unit Site: Kuparuk 2Z Pad Well: 2Z-01 Wellbore: 2Z-01A Plan: 2Z-01A (wp06) ~I'IOCt?~~1~?S Alaska • Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Site Kuparuk 2Z Pad Company: ConocoPhillips Alaska, Inc. ND Reference: D141 (72.3+28) @ 100.30ft Project: H:uparuk River Unit MD Reference: D141 (72.3+28) @ 100.30ft Site: Kuparuk 2Z Pad North Reference: True , Well: ZZ-01 Survey Calculation Method: tAinimum Curvature Wellbore: 2Z-01A Design: ~Z-01A (v/p06) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Poi nt Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2Z 01 Well Position +N/-S 0.00 ft Northing: 5,966, 526.92ft Latitude: 70° 19' 10.651" N +E/-W 0.01 ft Easting: 529, 130.69ft ' Longitude: 149° 45' 49.854" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 72.30ft Wellbore 2Z-01A Magnetics Model Name Sample Date Declination Dip Angle Field Strength „(') (°) (nT) BGGM2006 5/30/2007 23.40 80.84 57,616 Design 2Z-01A (wp06) Audit Notes: , Version: Phase: PLAN Tie On Depth: 3,700.00 Vertical Section : Depth From (ND) +N/-S +E/-W Direction (ft) (ft) lft) (°) 100.30 0.00 0.01 182.81 Plan Summary Measured Dogleg Build Turn Depth Inclination -Azimuth ND NDSS +NI-S +E/_y~l Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft} (ft) (°1100ft) ('1100ft) (°1100ft) (°) 3,700.00 37.89 192.80 3,282.27 3,181.97 -1,313.35 -241.34 0.00 0.00 0.00 0.00 4,664.91 19.37 142.66 4,136.41 4,036.11 -1,738.60 -209.23 3.00 -1.92 -5.20 -148.26 5,308.19 19.37 142.66 4,743.27 4,642.97 -1,908.24 -79.81 0.00 0.00 0.00 0.00 6,277.56 30.00 167.11 5,625.00 5,524.70 -2,274.26 72.59 1.50 1.10 2.52 55.52 7,317.14 30.00 167.11 6,525.30 6,425.00 -2,780.95 188.55 0.00 0.00 0.00 0.00 8/9/2007 9:16:22AM Page 2 of 6 COMPASS 2003.11 Build 48 ORIGINAL T'~./ ~""'1 °o ~,j J '°°®~ + 0 ~~+~ 1 +~ 0 600 \\ 400 200 -200 -400 -600 -800 -1000 -3200 -3400 -3600 -3800 Project: Kuparuk River Unit Site: Kuparuk 2Z Pad Well: 2Z-01 Wellbore: 2Z-01A Plan: 2Z-01A (vup06) N REFERENCEINFORMATION Co-ordinate (N/E) Reference: Site Kuparuk 2Z Pad, True North Vertical (TVD) Reference: D741 (72.3+28) ~ 100.30ft Measured Depth Reference: D141 (72.3+28) ~ 100.30ft Calculation Method: Minimum Curvature WELL DETAILS: ZZAI Ground Level: 72.30 +N/-S +E-W Northing Easting Latittude Longitude Slot 0.00 0.01 5966526.92 529130.69 70°19'IO.65IN 149°45'49.854W CASING DETAILS No MD TVD TVDss Name Size 1 2891.30 2653.91 2553.61 10 3/4" 10-3/4 2 3700.00 3282.27 3181.97 7" 7 3 7317.00 6525.18 6424.88 5 1/2" 5-1/2 g - 3700' MD; 3282.27 TVD :FSL 456.57, FEL 819.66' - SECT l - T11N - R09E rth - 5-1/2" Casing :7317.14' MD; 6525.3' TVD :FSL 4268.96', FEL 390.9' : SECl4 - T11N - R09E T M Azimuths to True North Magnetic North: 23.40° Magnetic Field Strength:57615.7nT Dip Angle: 80.83° Date: 5/30/2007 Model: BGGM2006 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 West(-)/East(+) (700 fi/in) ~'' COr~oCOf~illips aa~a • Halliburton Company Compass Proposal Report -Geographic • Database: .Sperry EDM .11 ' Local Co-ordinate Reference: Site Kuparuk 2Z Pad Company: ConocoPhillips Alaska, Inc. TVD Reference: D141 (72.3+28) @ 100.30ft Project: Kuparuk River Unit MD Reference: D141 (72.3+28) @ 100.30ft Site: Kuparuk 2Z Pad North Reference: True Well: 2Z-01 Survey Calculation Method: Minimum Curvature Wellbore: 2Z 01A Design: 2Z-01A (v/p06) Planned Survey 2Z-01A (wp061 Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) 1ft) 200.00 0.33 112.03 200.00 99.70 -0.12 0.30 5, 966, 526.80 300.00 0.37 112.42 300.00 199.70 -0.35 0.87 5,966,526.57 400.00 0.42 104.83 400.00 299.70 -0.57 1.53 5,966,526.35 500.00 0..44 99.95 499.99. 399.69 -0.74 2.27 5,966,526.19. 600.00 0.37 85.00 599.99 499.69 -0.77 2.98 5,966,526.17 700.00 0.27 96.61 699.99 599.69 -0.77 3.53 5,966,526.16 800.00 0.26 94.20 799.99 699.69 -0.80 3.98 5,966,526.13 900.00 0.48 123.09 899.99 799.69 -0.99 4.55 5,966,525.95 1,000.00 1.41 156.05 999.97 899.67 -2.26 5.43 5,966,524.68 1,100.00 4.08 179.12 1,099.86 999.56 -6.73 6.05 5,966,520.21 1,200.00 7.33 179.75 1,199.37 1099.07 -16.47 6.04 5,966,510.48 1,300.00 11.04 182.77 1,298.08 1197.78 -32.35 5.84 5,966,494.60 1,400.00 14.49 185.30 1,395.61 1295.31 -54.34 4.27 5,966,472.61 1,500.00 17.96 187.82 1,491.57 1391.27 -82.19 0.84 5,966,444.74 1,600.00 21.76 186.01 1,585.57 1485.27 -116.01 -3.34 5,966,410.91 1,700.00 24.54 185.93 1,677.43 1577.13 -155.30 -7.32 5,966,371.61 1,800.00 26.64 186.91 .1,767.61 1667.31 -198.22 -12.07 5,966,328.67 1,900.00 27.85 187.37 1,856.47 1756.17 -243.73 -17.87 5,966,283.14 2,000.00 29.30 188.42 1,944.18 1843.88 -291.30 -24.42 5,966,235.55 2,100.00 30.21 189.23 2,031.12 1930.82 -340.11 -32.08 5,966,186.72 2,200.00 33.76 190.12 2,115.84 2015.54 -392.44 -41.12 5,966,134.36 2,300.00 36.57 190.65 2,197.60 2097.30 -449.06 -51.42 5,966,077.71 2,400.00 39.49 191.13 2,276.26 2175.96 -509.68 -63.10 5,966,017.05 2,500.00 40.11 191.42 2,353.05 2252.75 -572.50 -75.62 5,965,954.19 2,600.00 39.96 191.68 2,429.60 2329.30 -635.54 -88.52 5,965,891.11 2,700.00 39.59 191.61 2,506.48 2406.18 -698.17 -101.42 5,965,828.43 2,800.00 39.69 191.79 2,583.46 2483.16 -760.68 -114.31 5,965,765.88 2,891.30 39.33 192.89 2,653.91 2553.61 -817.42 -126.73 5,965,709.09 10 3/4" 2,900.00 39.37 192.88 2,660.63 2560.33 -822.80 -127.96 5,965,703.71 3,000.00 39.80 192.83 2,737.67 2637.37 -884.97 -142.13 5,965,641.50 3,100.00 39.61 193.19 2,814.60 2714.30 -947.21 -156.53 5,965,579.20 3,200.00 39.39 193.17 2,891.75 2791.45 -1,009.15 -171.04 5,965,517.22 3,300.00 39.05 193.01 2,969.23 2868.93 -1,070.73 -185.35 5,965,455.58 3,400.00 38.84 193.09 3,047.00 2946.70 -1,131.97 -199.55 5,965,394.29 3,500.00 38.50 193.00 3,125.07 3024.77 -1,192.85 -213.65 5,965,333.37 3,600.00 38.18 192.98 3,203.51 3103.21 -1,253.28 -227.61 5,965,272.89 3,700.00 37.89 192.80 3,282.27 3181.97 -1,313.35 -241.34 5,965,212.78 KOP - 7" Casing - 37 00' MD; 3282.27' TVD : FSL 456.57', F EL 819.66' - SEC11 - T11 N - R09E - 7" 3,800.00 35.37 190.07 3,362.52 3262.22 -1,371.80 -253.21 5,965,154.28 3,900.00 32.92 186.99 3,445.29 3344.99 -1,427.28 -261.59 5,965,098.78 4,000.00 30.55 183.48 3,530.34 3430.04 -1,479.63 -266.44 5,965,046.42 4,100.00 28.29 179.46 3,617.44 3517.14 -1,528.71 -267.76 5,964,997.34 4,200.00 26.17 174.82 3,706.37 3606.07 -1,574.38 -265.54 5,964,951.68 4,300.00 24.22 169.46 3,796.86 3696.56 -1,616.52 -259.79 5,964,909.57 4,400.00 22.49 163.27 3,888.67 3788.37 -1,655.01 -250.53 5,964,871.11 4,500.00 21.03 156.20 3,981.56 3881.26 -1,689.75 -237.78 5,964,836.43 4,600.00 19.90 148.24 4,075.27. 3974.97 -1,720.65 -221.58 5,964,805.60 Map Fasting (ft) 529,130.98 529,131.55 529,132.21 529,132.96 529,133.66 529,134.21 529,134.66 529,135.23 529,136.11 529,136.75 529,136.79 529,136.64 529,135.16 529,131.84 529,127; 79 529,123.97 529,119.38 529,113.76 529,107.39 529,099.92 529,091.09 529,081.00 529,069.57 529,057.29 529,044.64 529,031.98 529,019.33 529.007.14 DLSEV Vert Section (°N OOft) (ftl 0.00 0.07 0.04 0.22 0.07 0.33 0.04_ 0.38 0.13 0.30 0.12 0.22 0.01 0.18 0.28 0.29 1.04 1.40 2.84 5.72 3.25 15.35 3.74 31.07 3.50 53.04 3.53 81.09 3.85 115.15 , 2.79 154.59 2.14 197.73 1.23 243.60 1.53 291.61 1.00 341.01 3.57 394.11 2.83 451.64 2.93 513.33 0.65 577.33 0.23 641.60 0.37 705.47 0.15 769.22 0.86 827.19 529,005. 93 0.49 832.69 528,992. 00 0.43 896.30 528,977. 85 0.30 960.01 528,963. 57 0.22 1,023.44 528,949. 50 0.35 1,086.49 528,935. 54 0.22 1,149.18 528,921. 68. 0.34 1,211.50 528,907. 96 0.33 1,273.36 528,894. 46 0.31 1,334.82 528,882.82 3.00 1,394.40 528,874.66 3.00 1,450.51 528,870.01 3.00 1,502.98 528,868.88 3.00 1,551.68 528,871.28 3.00 1,596.47 528,877.19 3.00 1,637.24 528,886.60 3.00 1,673.86 528,899.48 3.00 1,706.23 528,915.80 3.00 1,734.28 8/9/2007 9:16:22AM Page 3 of 6 COMPASS 2003.11 Build 48 '+. < Z ~ 4 • • Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Site Kuparuk 2Z Pad Company: ConocoPhillips Alaska, Inc. TVD Reference: D141 (72.3+28) @ 100.30ft Project: Kuparuk River Unit MD Reference: D141 (72.3+28) @ 100.30ft Site: Kuparuk 2Z Pad North Reference: True Well: 2Z-01 Survey Calculation Method: 1~linimum Curvature Wellbore: 2Z-01A Design: 2Z 01A (wp06) Planned Survey 2Z-01A lwpOfi) Map Map MD Incl Azimuth ND (ft) TVDSS +N!-S +E(_yy Northing Easting DLSEV Vert Section Ift) (°) (°) fft) (ft) (ft) (ftl lft) (°I100ft) (ft) 4,664.91 19.37 142.66 4,136.41 4036.11 -1,738.60 -209.23 5,964,787.69 528,928.22 3.00 1,750.13 4,700.00 19.37 142.66 4,169.51 4069.21 -1,747.85 -202.17 5,964,778.47 528,935.31 0.00 1,758.19 4,800.00 19.37 142.66 4,263.85 4163.55 -1,774.22 -182.05 5,964,752.18 528,955.53 0.00 1,781.17 4,900.00 19.37 142.66 4,358.19 4257.89_ -1,800.59 -161.93 5,964,725.89 528,975..75 0.00 1,804.15. 5,000.00 19.37 142.66 4,452.53 4352.23 -1,826.97 -141.81 5,964,699.60 528,995.97 0.00 1,827.12 5,100.00 19.37 142.66 4,546.87 4446.57 -1,853.34 -121.69 5,964,673.31 529,016.19 0.00 1,850.10 5,200.00 19.37 142.66 4,641.20 4540.90 -1,879.71 -101.57 5,964,647.02 529,036.41 0.00 1,873.08 5,300.00 19.37 142.66 4,735.54 4635.24 -1,906.08 -81.45 5,964,620.73 529,056.63 0.00 1,896.06 5,308.19 19.37 142.66 4,743.27 4642.97 -1,908.24 -79.81 5,964,618.58 529,058.29 0.00 1,897.94 5,400.00 20.18 145.95 4,829.67 4729.37 -1,933.47 -61.70 5,964,593.42 529,076.49 1.50 1,920.09 5,500.00 21.13 149.25 4,923.24 4822.94 -1,963.25 -42.83 5,964,563.71 529,095.48 1.50 1,946.63 5,600.00 22.13 152.27 5,016.20 4915.90 -1,995.42 -24.84 5,964,531.62 529,113.58 1.50 1,975.67 5,700.00 23.19 155.03 5,108.48 5008.18 -2,029.95 -7.77 5,964,497.16 529,130.79 1.50 2,007.17 5,800.00 24.29 157.57 5,200.02 5099.72 -2,066.81 8.39 5,964,460.36 529,147.09 1.50 2,041.12 5,900.00 25.43 159.89 5,290.75 5190.45 -2,105.99 23.63 5,964,421.25, 529,162.48 1.50, 2,077.50 6,000.00 26.60 162.02 5,380.62 5280.32 -2,147.45 37.92 5,964,379.85 529,176.93 1.50 2,116.29 6,100.00 27.80 163.99 5,469.56 5369.26 -2,191.17 51.26 5,964,336.19 529,190.44 1.50 2,157.44 6,200.00 29.03 165.80 5,557.51 5457.21 -2,237.11 63.65 5,964,290.29 529,203.01 1.50 2,200.95 6,277.56 30.00 167.11 5,625.00 5524.70 -2,274.26 72.59 5,964,253.19 529,212.09 1.50 2,236.29 6,300.00 30.00 167.11 5,644.43 5544.13 -2,285.20 75.10 5,964,242.26 529,214.64 0.00 2,246.71 6,400.00 30.00 167.11 5,731.04 5630.74 -2,333.94 86.25 5,964,193.57 529,225.98 0.00 2,293.17 6,500.00 30.00 167.11 5,817.64 5717.34 -2,382.68 97.41 5,964,144.88 529,237.32 0.00 2,339.62 6,508.85 30.00 167.11 5,825.30 5725.00 -2,386.99 98.39 5,964,140.57 529,238.32 0.00 2,343.73 C4 -Kaparuk C4 -Ka paruk C4.1 6,543.49 30.00 167.11 5,855.30 5755.00 -2,403.87 102.26 5,964,123.70 529,242.25 0.00 2,359.82 C3 6,558.50 30.00 167.11 5,868.30 5768.00 -2,411.19 103.93 5,964,116.39 529,243.96 0.00 2,366.80 C2 6,578.13 30.00 167.11 5,885.30 5785.00 -2,420.76 106.12 5,964,106.83 529,246.18 0.00 2,375.92 C1 6,593.14 30.00 167.11 5,898.30 5798.00 -2,428.07 107.79 5,964,099.53 529,247.88 0.00 2,382.89 Top B 6,600.00 30.00 167.11 5,904.24 5803.94 -2,431.42 108.56 5,964,096.18 529,248.66 0.00 2,386.08 6,700.00 30.00 167.11 5,990.84 5890.54 -2,480.16 119.71 5,964,047.49 529,260.00 0.00 2,432.53 6,728.24 30.00 167.11 6,015.30 5915.00 -2,493.92 122.86 5,964,033.74 529,263.21 0.00 2,445.65 A5 6,739.79 30.00 167.11 6,025.30 5925.00 -2,499.55 124.15 5,964,028.12 529,264.52 0.00 2,451.02 A4 -Kaparuk A4 6,791.75 30.00 167.11 6,070.30 5970.00 -2,524.87 129.95 5,964,002.82 529,270.41 0.00 2,475.15 A3 6,800.00 30.00 167.11 6,077.45 5977.15 -2,528.90 130.87 5,963,998.80 529,271.35 0.00 2,478.99 6,843.71 30.00 167.11 6,115.30 6015.00 -2,550.20 135.74 5,963,977.52 529,276.30 0.00 2,499.29 Baso Kuparuk 6,900.00 30.00 167.11 6,164.05 6063.75 -2,577.64 142.02 5,963,950.11 529,282.69 0.00 .2,525.44 8/9/2007 9:16:22AM Page 4 of 6 COMPASS 2003.11 Build 48 ~1~,~~ • • Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Site Kuparuk 2Z Pad Company: ConocoPhillips Alaska, Inc. ND Reference: D141 (72. 3+28) @ 100.30ft Project: Kuparuk River Unit MD Reference: D141 (72. 3+28) @ 100.30ft Site: t:uparuk 2Z Pad North Reference: True Well: 2Z-01 Survey Calculation Method: Minimum Curvature Wellbore: ?Z-01A Design: 2Z-01A (wp06) Planned Survey 2Z-01A iwp06) Map Map MD Incl Azimuth ND (ft) NDSS +N/-S +El-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 7,000.00 30.00 167.11 6,250.65 6150.35 -2,626.38 153.18 5,963,901.42 529,294.03 0.00 2,571.90 7,100.00 30.00 167.11 6,337.25 6236.95 -2,675.12 164.33 5,963,852.73 529,305.37 0.00 2,618.35 7,200.00 30.00 167.11 6,423.86 6323.56 -2,723.86 175.48 5,963,804.04 529,316.71 0.00 2,664.81 7,300.00 30.00 167.11 6,510.46 6410.16 -2,772.60 _ 186.64 5,963,755.34 529,328.06 0.00 2,711.27 7,317.00 30.00 167.11 6,525.18 - 6424,88 -2,780.88 188.53 5,963,747.07 529,329.98 0.00 2,719.16 5 1/2" 7,317.14 30.00 167.11 6,525.30 6425.00 -2,780.95 188.55 5,963,747.00 529,330.00 0.00 2,719.23 Total Depth - 5-1 /2" Casing :7317.14' MD; 6 525.3' ND : FSL 4268.96', FEL 390.9' : SEC14 - T11N - R09E - 2Z-01A T7 (wp06) - TD Geologic Targets 2Z-01A ND NDSS Target Name +N/-S +E/-W Northing Eastiny (ft) (ft) - Shape ft ft (ft) (ft) 5,825.30 Kaparuk C4.1 -2,454.92 189.81 5,964,073.00 529,330.00 - Point 6,525.30 TD -4,204.75 348.25 5,962,323.97 529,495.21 - Point 5,825.30 Ka paruk C4 -2,481.74 123.91 5,964,045.93 529,264.21 - Point 6,525.30 2Z-01A T1 (wp06) -2,780.95 188.55 5,963,747.00 529,330.00 - Point 6,025.30 Ka paruk A4 -2,548.01 189.66 5,963,979.92 529,330.21 - Point Prognosed Casing Points Measured Vertical Casing Hole bepth Depth Diameter Diameter (ft) (ft) (~~) (~~) 2,891.30 2,653.91 10-3/4 13-112 3,700.00 3,282.27 7 8-3/4 7,317.00 6,525.18 5-112 6-1l8 8/9/2007 9:16:22AM Page 5 of 6 COMPASS 2003.11 Build 48 ~~~~~. Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Site Kuparuk 2Z Pad Company: ConocoPhillips Alaska, Inc. TVD Reference: D141 (72.3+28) @ 100.30ft Project: ~:uparuk River Unit MD Reference: D141 (72.3+28) @ 100.30ft Site: ~:uparuk 2Z Pad North Reference: True Well: ;'Z-01 Survey Calculation Method: Minimum Curvature Wellbore: 2Z-01 A Design: 2Z-OiA ("wp06) ~gnosed Formation Intersection Points Measured Depth Inclination Azimuth TVD TVDSS +N/-E (ft) +E/-W (ft) lft) (°) (~? (ft) (ft) Narne 6,508.85 30.00 167.11 5,825.30 -2,386.99 98.39 C4 6,543.49 30.00 167.11 5,855.30 -2,403.87 102.26 C3 6,558.50 30.00 167.11 5,868.30 -2,411.19 103.93 C2 .6,578.13 30.00 167.11 5,885.30 -2,420.76 106.12 C1 6,593.14 30.00 167.11 5,898.30 -2,428.07 107.79 Top B 6,728.24 30.00 167.11 6,015.30 -2,493.92 122.86 AS 6,739.79 30.00 167.11 6,025.30 -2,499.55 124.15 A4 6,791.75 30.00 167.11 6,070.30 -2,524.87 129.95 A3 6,843.71 30.00 167.11 6,115.30 -2,550.20 135.74 Base Kuparuk Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E(-W Comment (ft) (ftl (ft) (ft) 3,700.00 3,282.27 -1,313.35 -241.34 KOP - 7" Casing - 3700' MD; 3282.27' TVD :FSL 456.57', FEL 819.66' -SEC' 7,317.14 6,525.30 -2,330.71 85.51 Total Depth - 5-1/2" Casing :7317.14' MD; 6525.3' TVD :FSL 4268.96', FEL 8/9/2007 9:16.'22AM Page 6 of 6 COMPASS 2003.118ui1d 48 y e F- U a ~ A ~, a 3 ~~~ _ _~~ F c r8N8 ~ ~ 888°° a ~ _ -a C < - - °. = > ~ - - ~' o z Q h z -~€r R ~ ___~~ a ~ - > _ ti ~ w ~. h 4 _ _ a" - F - ~- L ~~ Q r .. r. T. ~ W p ~ G rvr C O O O O O oooO~no~n ~~nOv~ON~nr E.., N ~n r ~--~ ~--~ --, ~IIII I ~ooooo0 0 ~ N Vl n TI ~n w f ~- O ` l~~ ~~ 1~ 11\ ,\ ~ ~ ~ ~ 1 ~ ~`. ~ ~. ~,~ ~ 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 oooo~no~nov~oro~nooooo0000 Q F N 10 ~ O N~ r O N~ N~ r 0 0 0 0 0 0 0 0 ~--~ _ ~--~NNNNNNM7 V'i ~Or0001 .~~ O '~° ~~~ ~IIII IIII N r Z Cy~OOOOOOOOOOO ViOO OO O O v;o~noinov~ov;oro ooog oO cGj L N~ r O N Vi r O N~ N~ 0 0 0 00 0 0 'r ^~ ~ ~--~~--~~--~~NNNN NMr4' ~r0001O (;: j G ~ L L ~ V z '~ o =~= °o N ~ a O ~~~ F ~Ma Z o .. 4 ==~ ~ L aL o ai, ~ o ix ~ \ 'x ~C~ _,~~;~~, ~~,~, 2 ~ 'qR$$3 o q8o O ~gg~E =4-4z - 3~-~E E~~~<° _edd~ ~ _ ~ `s ~~~gn 4~~ v f J~ n N~ n 0 0 0 0 0 0 0 -+ N M R V 1 `D r 0 0 01 O~--~ N JNNN ~~n~roorn~--~-+,--~^-^-~^~^~^-~^~^+NNN ~~ ~ ~ I I I I I I ~ I E u. - ~.~ >OOv~OO >~noro~n > N v1 N ~n r N - OOCOOO 000000 0000 0 0 ~ r 00 0 - ` u 0~4 00000000 00 0000000 0 0 0 0 0 0 0 0 'V V 00 Q 2' O -- O 0 0 0 J N N_.ol~-f4 1 l C - . l 1 Q ~ N r ~r.~ ~ .-.~.-.~N o o N e - - ~ --- ~~ ~. - . -_ a ~ ~ ~ ~ ~ 1 ~ , ~ ~ ~~i ~ U i N O ~O 0 ao 0 u ~7 0~0 ;~ c~ ~ I ~ ~ N 6 /~\/ ~ 01 ~ ~ ~ ~w ~ \ \ \ a?' / s E ~ r % ~' _ 7 ~ ,, V .....~.. ~~ -~ > ~.~\ i , n i / F \~ ~ O o\~~_ ~ ~ N ~ ee Da ~--~ Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Uate: 8!9/2007 1'imc: 09:35:42 Page: t Field: Kuparuk Rive r Unit Reference Si te: Kuparuk 2Z P ad Co -ordinate (NE) Reference: Well: 2Z- 01, True No rth Reference R'ell: 2Z-01 Ve rtical (TV D) Reference: 2Z-01Awp04 100.3 Reference Wellpath: Plan: 2Z-01A Db: Oracle GLOBALSCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 2Z-01Awp06 & NOT PLANNED PR Interpolation Method: MD Inte rval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 3700.00 to 7317.15 ft Scan Method: Trav Cylinder North Maximum Radius: 928.92 ft Error Surface: Ellipse + Casing Casing Points - - _ MD TVD Diameter Bol e Size - Nam e __ ft ft in in i 2891.00 2653.61 10.750 13.500 10-3/4" x 13-1/2" __ 3700.00 3282.21 7.000 8.750 7"x 8 3/4" 7317.15 6525.30 5.500 6.125 5-1/2" x 6-1/8" Plan: 2Z-01Awp06 Date Co mposed: 5/30/2007 Version : 13 Principal: Yes Tied-to: From: Definitive Path Summary <-- ------- --------- O ffsefW'ellpath ---------- ----- > R eference Offset C'tr-Ctr \o-Gn ,4llowahle Site Well Wellpath ~1D 11D Distance Area Deviation Warning ft ft ft ft ft Kuparuk 2Z Pad 2Z-01 2Z-01 VO 3700.02 3700.00 0.21 120.98 -120.77 FAIL: Major Risk Kuparuk 2Z Pad 2Z-14 2Z-14 V1 3706.17 3650.00 653.06 105.49 547.57 Pass: Major Risk Site: Kuparuk 2Z Pad Well: 2Z-01 Rule Ass igned: Major Ris k Wellpath: - , 2Z-01 VO -- - Inter-Site Error: 0.00 ft , Refe rence Offset Scmi 11ajor !xis Ctr-Ch• No-Go 111owable '11D TVD b1D Tt°D Ref Offset 'CFO+A7I 7 F0-[IS Casing/1[Snistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft _- 3700.02 3282.20 - 3700.00 3282.21 - 16.65 16.05 290.07 97.27 0.21 120.98 -120.77 FAIL 3724.98 3302.01 3725.00 3301.95 16.76 16.22 264.70 72.55 0.31 119.80 -119.50 FAIL 3749.97 3321.98 3750.00 3321.72 16.87 16.39 242.81 51.33 0.71 107.39 -106.68 FAIL 3774.94 3342.11 3775.00 3341.50 16.98 16.55 235.15 44.37 1.44 101.51 -100.07 FAIL 3799.90 3362.38 3800.00 3361.31 17.09 16.72 231.99 41.91 2.47 99.33 -96.86 FAIL 3824.82 3382.78 3825.00 3381.14 17.13 16.89 230.36 41.01 3.80 98.23 -94.42 FAIL 3849.71 3403.30 3850.00 3400.99 17.17 17.06 229.37 40.78 5.43 97.93 -92.50 FAIL 3874.55 3423.94 3875.00 3420.87 17.21 17.23 228.71 40.90 7.36 97.96 -90.60 FAIL 3899.34 3444.68 3900.00 3440.76 17.25 17.40 228.23 41.22 9.58 98.17 -88.59 FAIL 3924.08 3465.50 3925.00 3460.67 17.29 17.57 227.85 41.66 12.10 98.43 -86.33 FAIL 3948.74 3486.41 3950.00 3480.60 17.33 17.73 227.54 42.19 14.91 98.76 -83,84 FAIL 3973.34 3507.39 3975.00 3500.55 17.36 17.90 227.26 42.80 18.02 99.14 -81.11 FAIL 3997.85 3528.43 4000.00 3520.52 17.40 18.07 227.03 43.46 21.42 99.56 -78,14 FAIL 4022.28 3549.52 4025.00 3540.51 17.43 18.24 226.83 44.19 25.11 99.96 -74.85 FAIL 4046.62 3570.65 4050.00 3560.52 17.46 18.40 226.66 44.98 29.09 100.39 -71.30 FAIL 4070.86 3591.80 4075.00 3580.56 17.49 18.57 226.51 45.81 33.35 100.86 -67.51 FAIL 4094.99 3612.98 4100.00 3600.62 17.52 18.74 226.37 46.69 37.90 101.35 -63.45 FAIL 4119.01 3634.16 4125.00 3620.69 17.55 18.90 226.23 47.60 42.74 101.78 -59.04 FAIL 4142.91 3655.34 4150.00 3640.76 17.57 19.07 226.07 48.52 47.88 102.19 -54.31 FAIL 4166.69 3676.50 4175.00 3660.85 17.60 19.23 225.91 49.47 53.31 102.60 -49.29 FAIL 4190.33 3697.64 4200.00 3680.95 17.62 19.39 225.75 50.45 59.03 103.02 -44.00 FAIL 4213.84 3718.74 4225.00 3701.05 17.64 19.56 225.60 51.47 65.04 103.42 -38.38 FAIL 4237.20 3739.80 4250.00 3721.18 17.66 19.73 225.46 52.54 71.34 103.79 -32.45 FAIL 4260.41 3760.80 4275.00 3741.31 17.68 19.89 225.33 53.66 77.93 104.20 -26.26 FAIL 4283.47 3781.74 4300.00 3761.46 17.70 20.05 225.22 54.82 84.81 104.63 -19.82 FAIL 4306.37 3802.62 4325.00 3781.64 17.72 20,22 225.11 56.02 91.93 105.05 -13.12 FAIL 4329.12 3823.42 4350.00 3801.85 17.73 20.38 225.02 57.27 99.30 105.42 -6.13 FAIL 4351.72 3844.14 4375.00 3822.10 17.74 20.54 224.94 58.57 106.90 105.82 1.08 Pass 4374.16 3864.78 4400.00 3842.38 17.75 20.70 224.86 59.90 114.75 106.25 8.50 Pass 4396.43 3885.33 4425.00 3862.69 17.77 20.86 224.78 61.27 122.85 106.68 16.17 Pass TRAM ORIGINAL Halliburton Company Anticollision Report Company: Conoco Phillips Alaska lnc. Date: 8/9/2007 Time: 09:35 :42 Page: 2 1 Field: K uparuk River Unit ~ Reference Si te: K uparuk 2Z Pad Co- ord inate(nE) Reference: Well: 2Z- 01, Tr ue No rth Reference ~i'cll: 2Z-01 Ver tical (TV D) Reference: 2Z-0 1Awp04 100.3 Referen ce Wellpat h: P lan: 2Z-01 A - _ _ Db: _____ Oracle Site: Kuparuk 2Z Pad Well: 2Z-01 Rule Ass igned: Major Risk Wellpath: 2Z-01 VO Inter-Site Error: 0 .00 ft Refe rences O ffset Sem i-M ajor Aais Ctr- Ctr No- Gu Allo wable M D fV D ~1 D 7"V D Ref Offset TFO +A7I TP' O-HS Casinglfl~istance Are a Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 4418. 53 3905. 76 4450. 00 3883. 01 17. 77 21. 01 224. 70 62 .67 131. 20 107. 03 24. 17 Pass 4440. 45 3926. 08 4475. 00 3903. 35 17. 78 21. 17 224. 62 64. 10 139. 80 107. 37 32. 43 Pass 4462. 20 3946. 29 4500. 00 3923. 71 17. 79 21. 32 224. 54 65. 56 148. 64 107. 72 40. 92 Pass 4483. 76 3966. 37 4525. 00 3944. 08 17. 79 21. 47 224. 45 67. 05 157. 73 108. 08 49. 65 Pass 4505. 14 3986. 31 4550. 00 3964. 46 17. 80 21. 62 224. 36 68 .55 167. 05 108. 42 58. 64 Pass 4526. 34 4006. 13 4575. 00 3984. 86 17. 80 21. 76 224. 26 70 .07 176. 61 108. 67 67. 94 Pass 4547. 35 4025. 80 4600. 00 4005. 27 17. 80 21. 91 224. 16 71 .62 186. 40 108. 93 77. 47 Pass 4568. 18 4045. 33 4625. 00 4025. 70 17. 80 22. 06 224. 05 73 .19 196. 42 109. 21 87. 20 Pass 4588. 82 4064. 71 4650. 00. 4046. 16 17. 80 22. 20 223. 96 74 .79 206. 65 109. 51 97. 13 Pass 4609. 27 4083. 94 4675. 00 4066. 64 17. 80 22. 35 223. 87 76 .40 217. 09 109. 79 107. 30 Pass 4629. 53 4103. 01 4700. 00 4087. 15 17. 80 22 .49 223. 78 78 .04 227. 75 110. 03 117. 72 Pass 4649. 60 4121. 93 4725. 00 4107. 69 17. 79 22 .63 223. 69 79 .69 238. 60 110. 29 128. 31 Pass 4670. 04 4141. 20 4750. 00 4128. 25 17. 80 22. 78 223. 62 81 .00 249. 64 110. 61 139. 03 Pass 4692. 46 4162. 35 4775. 00 4148. 84 17. 81 22. 96 223. 63 81 .00 260. 71 111. 16 149. 55 Pass 4714. 90 4183. 52 4800. 00 4169. 45 17. 83 23. 13 223. 64 81 .02 271. 73 111. 71 160. 02 Pass 4737. 35 4204. 70 4825. 00 4190. 09 17. 85 23 .30 223. 65 81 .03 282. 73 112. 26 170. 47 Pass 4759. 81 4225. 89 4850 .00 4210. 74 17. 86 23 .47 223. 67 81 .05 293. 71 112. 81 180. 89 Pass 4782. 27 4247. 09 4875 .00 4231. 42 17. 88 23 .65 223. 70 81 .08 304. 67 113. 38 191. 30 Pass 4804. 75 4268. 29 4900 .00 4252. 11 17. 89 23 .82 223. 73 81 .10 315. 62 113. 94 201. 67 Pass 4827. 24 4289. 51 4925 .00 4272. 83 17. 91 24 .00 223. 76 81 .14 326. 53 114. 52 212. 01 Pass 4849. 74 4310. 74 4950 .00 4293 .57 17. 92 24 .17 223. 79 81 .17 337. 42 115. 11 222. 31 Pass 4872. 26 4331. 99 4975 .00 4314 .35 17. 94 24 .35 223. 84 81 .21 348. 27 115. 70 232. 57 Pass 4894. 80 4353. 25 5000 .00 4335 .15 17. 96 24 .53 223. 88 81 .26 359. 10 116. 30 242. 80 Pass 4917. 34 4374. 52 5025 .00 4355 .97 17. 97 24 .70 223 .93 81 .30 369. 90 116. 90 253. 00 Pass 4939. 90 4395. 79 5050 .00 4376 .82 17. 99 24 .88 223. 97 81 .35 380. 68 117. 50 263. 17 Pass 4962. 46 4417. 08 5075 .00 4397 .68 18. 01 25 .05 224. 02 81 .40 391. 43 118. 11 273. 32 Pass 4985. 04 4438. 38 5100 .00 4418 .56 18. 02 25 .23 224. 07 81 .45 402. 16 118. 71 283. 45 Pass 5007 .64 4459. 70 5125 .00 4439 .48 18. 04 25 .40 224 .13 81 .50 412. 85 119. 32 293. 53 Pass 5030 .26 4481. 04 5150 .00 4460 .43 18. 06 25 .57 224 .18 81 .56 423. 49 119. 92 303. 57 Pass 5052 .90 4502. 41 5175 .00 4481 .43 18. 07 25 .75 224 .24 81 .62 434. 07 120. 32 313. 76 Pass 5075 .57 4523 .79 5200 .00 4502 .47 18. 09 25 .92 224 .31 81 .68 444 .61 120. 72 323. 89 Pass 5098 .26 4545 .19 5225 .00 4523 .55 18. 11 26 .09 224 .37 81 .75 455 .09 121. 12 333. 97 Pass 5120 .96 4566 .62 5250 .00 4544 .67 18 .13 26 .26 224 .45 81 .82 465 .54 121. 54 344 .00 Pass 5143 .69 4588 .06 5275 .00 4565 .83 18 .14 26 .43 224 .52 81 .90 475 .94 121. 96 353 .98 Pass 5166 .43 4609 .52 5300 .00 4587 .03 18 .16 26 .60 224 .61 81 .98 486 .29 122. 39 363 .90 Pass 5189 .21 4631 .01 5325 .00 4608 .30 18 .18 26 .77 224 .69 82 .07 496 .56 122. 82 373. 74 Pass 5212 .03 4652 .53 5350 .00 4629 .64 18 .20 26 .94 224 .79 82 .17 506 .74 123. 26 383 .48 Pass 5234 .88 4674 .09 5375 .00 4651 .05 18 .22 27 .11 224 .89 82 .27 516 .84 123. 72 393 .12 Pass 5257 .77 4695 .69 5400 .00 4672 .52 18 .24 27 .27 225 .00 82 .38 526 .85 124. 18 402 .66 Pass 5280 .69 4717 .31 5425 .00 4694 .06 18 .25 27 .43 225 .11 82 .49 536 .77 124. 65 412 .12 Pass 5303 .65 4738 .97 5450 .00 4715 .65 18 .27 27 .59 225 .23 82 .61 546 .61 125 .12 421 .49 Pass 5329 .52 4763 .37 5475 .00 4737 .31 18 .30 27 .76 225 .40 81 .96 556 .31 125 .75 430 .56 Pass 5356 .09 4788 .38 5500 .00 4759 .02 18 .32 27 .93 225 .59 81 .18 565 .80 126 .44 439 .35 Pass 5382 .80 4813 .50 5525 .00 4780 .77 18 .35 28 .09 225 .79 80 .44 575 .08 127 .16 447 .92 Pass 5409 .65 4838 .71 5550 .00 4802 .56 18 .38 28 .25 225 .99 79 .71 584 .18 127 .88 456 .30 Pass 5436 .64 4864 .00 5575 .00 4824 .38 18 .41 28 .42 226 .21 79 .01 593 .08 128 .59 464 .48 Pass 5463 .77 4889 .39 5600 .00 4846 .23 18 .44 28 .58 226 .42 78 .34 601 .79 129 .33 472 .46 Pass 5491 .02 4914 .84 5625 .00 4868 .11 18 .46 28 .74 226 .65 77 .69 610 .31 130 .08 480 .23 Pass 5518 .39 4940 .37 5650 .00 4890 .00 18 .49 28 .90 226 .88 77 .05 618 .66 130 .83 487 .84 Pass 5545 .89 4965 .96 5675 .00 4911 .91 18 .53 29 .05 227 .11 76 .44 626 .83 131 .58 495 .26 Pass ~~+Y~ Halliburton Company Anticollision Report __ _ - Compan~: ConocoPhillips Alaska lnc. Date: 8!9/2007 'I ime: 09:35:42 Page: 3 Field: Kuparuk River Unit Reference Site: Kuparuk 2Z Pad Co-ordinate(NL) Reference: Well: 2Z-01, True North Reference Well: 2Z-01 Vertical (TVD) Reference: 2Z-01Awp04 100.3 Reference W'ellpath: Plan: 2Z-01A Db: OraCle Site: Kuparuk 2Z Pad Well: 2Z-01 Rule Assigned: Major Ris k Wellpath: 2Z-01 VO Inter-Site Error: 0.00 ft Refe rence Offset Se mi-~4 ajorAxis (tr-Ctr No-Go Allo~ti°able I11D TVD 111 D TV D Ref Offs et TFO +AZI 'fF0-IiS Casing/H~ista nce Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 5573. 51 4991.62 5700. 00 4933. 84 18. 56 29. 21 227. 35 75. 85 634. 82 132.35 502.47 Pass 5601. 25 5017.34 5725. 00 4955. 81 18. 59 29. 37 227. 59 75. 29 642. 59 133.14 509.45 Pass 5629. 11 5043.11 5750. 00 4977. 83 18. 62 29. 52 227. 85 74. 75 650. 14 133.92 516.22 Pass 5657. 08 5068.94 5775. 00 4999. 91 18. 66 29. 68 228. 11 74. 23 657.47 134.73 522.73 Pass 5685. 16 5094.82 5800. 00 5022. 03 18. 69 29. 84 228. 38 73. 74 664. 57 135.57 529.01 Pass 5713. 33 5120.71 5825. 00 5044. 16 18. 73 30, 00 228. 66 73. 27 671. 51 136.40 535.11 Pass 5741. 59 5146.63 5850. 00 5066. 30 18. 77 30. 15 228. 94 72. 83 678. 30 137.24 541.06 Pass 5769. 93 5172.55 5875. 00 5088. 45 18. 81 30. 31 229. 23 72. 40 684. 94 138.10 546.84 Pass 5798. 34 5198.49 5900. 00 5110. 59 18. 85 30. 47 229. 51 71. 99 691. 42 138.97 552.46 Pass 5826. 82 5224.42 5925. 00 5132. 75 18. 89 30. 63 229. 81 71. 60 697. 77 139.83 557.94 Pass 5855. 37 5250.34 5950. 00 5154. 92 18 .93 30. 79 230. 11 71. 23 703. 97 140.71 563.26 Pass 5883. 98 5276.25 5975. 00 5177. 10 18 .97 30. 94 230. 42 70. 89 710. 03 141.61 568.42 Pass 5912. 64 5302.14 6000. 00 5199. 29 19 .01 31. 10 230. 73 70. 56 715. 94 142.51 573.43 Pass 5941. 38 5328.03 6025. 00 5221. 53 19 .06 31. 26 231. 06 70. 26 721. 64 143.42 578.22 Pass 5970. 18 5353.90 6050. 00 5243. 83 19. 10 31. 41 231. 39 69. 99 727. 10 144.35 582.75 Pass 5999. 04 5379.74 6075. 00 5266. 19 19 .15 31. 57 231. 74 69. 73 732. 33 145.30 587.03 Pass 6027. 95 5405.56 6100. 00 5288. 60 19 .20 31. 72 232. 09 69. 50 737. 33 146.25 591.08 Pass 6056. 90 5431.32 6125. 00 5311. 06 19 .25 31. 87 232. 46 69. 30 742. 13 147.22 594.91 Pass 6085. 86 :5457.02 6150. 00 5333. 57 19 .30 32. 02 232. 84 69. 12 746. 76 148.22 598.54 Pass 6114. 84 5482.65 6175. 00 5356. 13 19 .35 32. 17 233. 23 68. 97 751. 20 149.23 601.98 Pass 6143. 82 5508.20 6200. 00 5378. 74 19 .40 32. 32 233. 64 68. 84 755. 48 150.25 605.23 Pass 6172. 77 5533.65 6225. 00 5401. 37 19 .45 32. 47 234. 06 68. 74 759. 68 151.28 608.40 Pass 6201. 70 5558.97 6250. 00 5424. 03 19 .50 32. 61 234. 49 68. 67 763. 82 152.33 611.48 Pass 6230. 58 5584.17 6275. 00 5446. 70 19 .55 32. 75 234. 94 68. 62 767. 90 153.40 614.50 Pass 6259. 41 5609.25 6300. 00 5469. 39 19 .61 32. 90 235. 41 68. 60 771. 94 154.48 617.46 Pass 6286. 45 5632.68 6325. 00 5492. 11 19 .66 33. 03 235. 87 68. 76 775. 90 155.51 620.40 Pass 6310. 45 5653.47 6350. 00 5514. 86 19 .70 33. 16 236. 29 69. 18 779. 89 156.42 623.47 Pass 6334. 42 5674.23 6375. 00 5537. 64 19 .74 33. 29 236. 72 69 .61 783. 93 157.35 626.58 Pass 6358. 36 5694.96 6400. 00 5560. 45 19 .78 33. 41 237. 15 70 .04 788. 02 158.28 629.75 Pass 6382. 27 5715.67 6425. 00 5583. 29 19 .83 33. 54 237. 59 70 .48 792. 16 159.20 632.95 Pass 6406. 15 5736.35 6450. 00 5606. 17 19 .87 33. 67 238. 03 70 .92 796. 32 160.13 636.19 Pass 6430. 01 5757.01 6475. 00 5629. 07 19 .91 33. 80 238. 47 71 .36 800. 53 161.07 639.46 Pass 6453. 84 5777.64 6500. 00 5652. 00 19 .96 33. 92 238. 92 71 .81 804. 78 162.00 642.78 Pass 6477. 65 5798.26 6525. 00 5674. 94 20 .00 34. 04 239. 36 72 .25 809. 10 162.92 646.17 Pass 6501. 44 5818.87 6550. 00 5697. 89 20 .04 34. 16 239. 81 72 .70 813. 50 163.84 649.66 Pass 6525. 21 5839.45 6575. 00 5720. 83 20 .09 34. 28 240. 25 73 .14 817. 98 164.76 653.22 Pass 6548. 96 5860.02 6600. 00 5743. 78 20 .13 34. 40 240. 69 73 .58 822. 54 165.66 656.89 Pass 6572. 69 5880.57 6625. 00 5766. 70 20 .17 34. 51 241. 13 74 .02 827. 25 166.54 660.71 Pass 6596. 39 5901.10 6650. 00 5789. 60 20 .22 34. 62 241. 57 74 .46 832. 10 167.41 664.69 Pass 6620. 06 5921.60 6675 .00 5812. 48 20 .26 34 .72 242. 00 74 .89 837. 10 168.28 668.82 Pass 6643. 71 5942.08 6700 .00 5835. 32 20 .31 34 .83 242. 43 75 .32 842. 25 169.13 673.12 Pass 6667. 33 5962.54 6725 .00 5858. 12 20 .35 34 .92 242. 85 75 .74 847. 58 169.96 677.63 Pass 6690. 94 5982.98 6750 .00 5880. 85 20 .40 35 .02 243. 26 76 .15 853. 10 170.77 682.33 Pass 6714 .53 6003.41 6775 .00 5903 .53 20 .44 35 .12 243. 66 76 .55 858. 79 171.57 687.22 Pass 6738 .09 6023.82 6800 .00 5926 .15 20 .49 35 .22 244. 05 76 .94 864. 67 172.36 692.31 Pass 6761. 65 6044.22 6825 .00 5948. 70 20 .53 35 .31 244. 44 77 .33 870. 71 173.13 697.58 Pass 6785. 21 6064.62 6850 .00 5971. 18 20 .58 35 .41 244. 81 77 .70 876. 91 173.88 703.03 Pass 6808 .76 6085.02 6875 .00 5993. 59 20 .62 35 .50 245. 16 78 .05 883. 26 174.61 708.65 Pass 6832 .30 6105.40 6900 .00 6015 .92 20 .67 35 .60 245. 51 78 .40 889. 77 175.33 714.44 Pass 6855 .82 6125.77 6925 .00 6038 .18 20 .71 35 .70 245. 84 78 .73 896. 44 176.04 720.40 Pass 6879 .32 6146.12 6950 .00 6060 .39 20 .76 35 .81 246 .17 79 .06 903. 27 176.75 726.53 Pass i )RIGINAL Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 8/9/2007 Time: 09:35:42 Page: Field: Kuparuk River Unit Reference Site: Kuparuk 2Z Pad Co-ordinate(NE) Reference: Well: 2Z-01, True North Reference Well: 2Z-01 Vertical (TVD) Reference: 2Z-01Awp04 100.3 Reference Wellpath: Plan: 2Z-01A Db: Oracl Site: Kuparuk 2Z Pad Well: 2Z-01 Rule Assigned: Major Risk Wellpath: 2Z-01 VO Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAsis Ctr-Ctr \o-Go Allowable ~1D fVD MD fVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 6902.79 6166.45 6975.00 6082.53 20.81 35.91 246.48 79.37 910.26 177.44 732.82 Pass 6926.24 6186.76 7000.00 6104.60 20.85 36.01 246.79 79.68 917.41 178.12 739.28 Pass 6949.66 6207.04 7025.00 6126.59 20.90 36.12 247.09 79.98 924.73 178.80 745.93 Pass Site: Kuparuk 2Z Pad Well: 2Z-14 Rule Assigned: Major Risk Wellpath: 2Z-14 V1 Inter-Site Error: 0.00 ft Refe rence Of fset Semi-MajorAzis Ctr-Ctr So-Go Allowable ~iD I V D A~1D 1'V ll Rcf Offset TFO+AZI TFO-HS Casing/H~istance Area Deviation ~'f'arning ft ft ft ft ft ft deg deg in ft ft ft 3706.17 3287 .09 3650. 00 3138. 71 16 .67 11. 22 260 .85 68. 21 653 .06 105.49 547. 57 Pass 3723.19 3300 .58 3675. 00 3156. 30 16 .75 11. 27 261 .19 69. 00 664 .35 105.95 558. 40 Pass 3740.12 3314 .09 3700. 00 3173. 90 16 .82 11. 33 261 .52 69. 77 675 .81 106.39 569 .43 Pass 3756.97 3327 .61 3725. 00 3191. 54 16 .90 11. 37 261 .82 70. 54 687 .43 106.80 580 .63 Pass 3773.75 3341 .14 3750. 00 3209. 21 16 .97 11. 42 262 .11 71. 29 699 .20 107.22 591 .98 Pass 3790.45 3354 .69 3775. 00 3226. 91 17 .05 11. 47 262 .37 72. 02 711 .09 107.62 603. 47 Pass 3807.08 3368 .24 3800. 00 3244. 64 17 .10 11. 51 262 .62 72. 75 723 .13 107.79 615 .34 Pass 3823.62 3381 .80 3825. 00 3262. 40 17 .13 11. 56 262 .84 73. 46 735 .29 108.04 627 .25 Pass 3840.09 3395 .35 3850. 00 3280. 19 17 .16 11. 60 263 .05 74. 17 747 .60 108.29 639 .31 Pass 3856.46 3408 .90 3875. 00 3298. 00 17 .18 .11. 64 263 .25 74. 86 760 .03 108.53 651 .50 Pass 3872.76 3422 .44 3900. 00 3315. 83 17 .21 11. 69 263 .42 75. 55 772 .60 108.78 663 .82 Pass 3888.97 3435 .98 3925. 00 3333. 70 17 .24 11. 74 263 .58 76. 23 785 .27 109.02 676 .25 Pass 3905.11 3449 .52 3950. 00 3351. 61 17 .26 11. 78 263 .73 76. 91 798 .05 109.26 688 .79 Pass 3921.16 3463 .04 3975. 00 3369. 56 17 .29 11. 83 263 .87 77. 58 810 .93 109.48 701 .45 Pass 3937.13 3476 .55 4000. 00 3387. 54 17 .31 11. 90 263 .99 78 .24 823 .93 109.75 714 .18 Pass 3952.95 3489 .99 4025. 00 3405. 45 17 .33 12. 01 264 .10 78. 90 837 .17 110.11 727 .06 Pass 3968.59 3503 .33 4050. 00 3423. 26 17 .36 12. 12 264 .19 79. 56 850 .69 110.47 740 .23 Pass 3984.06 3516 .58 4075. 00 3440. 98 17 .38 12. 22 264 .28 80. 20 864 .50 110.82 753 .68 Pass 4000.00 3530 .28 4100. 00 3458. 59 17 .40 12. 35 264 .34 80 .86 878 .58 111.21 767 .37 Pass 4014.44 3542 .74 4125. 00 3476. 15 17 .42 12. 50 264 .42 81 .48 892 .95 111.64 781 .30 Pass 4029.33 3555 .63 4150. 00 3493. 66 17 .44 12. 65 264 .48 82 .12 907 .59 112.08 795 .51 Pass 4044.02 3568 .38 4175. 00 3511. 11 17 .46 12. 81 264 .55 82 .77 922 .51 112.51 810 .00 Pass -1 e ~ 31GINAL Cono-coPhil~ips ~vaSka ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 2Z Pad `v Plan: 2Z-OlAwp06 ..~..w.. 1/4 Mile Pool Scan '' Sperry Drilling Services +~ August 7, 2007 HALLIBURTON Drilling and Formation Evaluation Closest in POOL ~. Closest A roach: Reference Well: 2Z-01Aw 06 Plan Offset Well: 2Z=01 3-D ctr-ctr Distance. ' Meas. De th ncl. Angle RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)/W(-) View VS (176.12°) omments Meas. De th ncl. Angle RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)/W(-) View VS (176.12°) omments - 835.56 603 0 67.1 806.564 964094.4 29250.8 434.865 POOL Min Distance (835.56 ft) in POOL (5725 - 6424.91 TVDss) to 2Z-01 (5725 - 6424.91 TVDss) 674 3.82 07.11 703.24 963721.6 28510.2 753.82 POOL Min Distance (835.56 ft) in POOL (5725 - 6424.91 TVDss) to 2Z- 01Awp06 Plan (5725 6424.91 TVDss) i POOL Summary 2Z-01A (wp06).xls Sl7/2007 1:30 PM • 2Z-OlA Drilling Hazards • High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD tool while higher MW's required ~ drilling across pay interval. Pump and rotate out on trips as a last resort. Barite Sag Low Use Good drilling practices as documented in well plan and keep track of mud ro erties in line with mud program. Differential Sticking HIGH Do not leave pipe static for extended period of time across the C sand. Proper drilling practices and kee connection time to minimum. Hole instability while drilling High Use enough MW to stabilize Kalubick without sustaining losses to Kalubick Shale section lower pressure C-Sand Lost Circulation Moderate Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree ' as needed. '~R161NAL 2Z-OlA SIDETRA~ Baker "K-1" CIBP below set point for whipstock +/- 3,700' Tubing cmt retaine @ +/- 6,600' MD Perfs @ 6,759' - 6,840' Pump @ 6,858' MD (removed) Bttm of tubing 6,903' MD 7" 26# J-55 @ 7,559' MD/6,582' TVD SSSV @ +/- 2,400' MD 7" x 10 '/4" annulus Arctic packed in 1983 w/ 42 bbls cmt + 87 bbls diesel Est. TOC @ 2,040' 10-3/4" 45.5# K-55 casing @ 2,900' MD / 2,663' TVD Sidetrack KOP w/ window in 7" @ +/- 3,700' MD, 3,284' TVD Tubing chemical cut Below lowest mandrel above retainer Est. TOC on 7" csg. @ 3,818' MD Perfs @ 6,974' - 6,978' 6,987 - 7,018' Geo Vann Gun 7,140' - 7,240' MD (O.D. 2" fish) ORIGINAL • KBG29, IBT~~LCamco GLM inside 7" 3-1/2" x 5-1/2" Packer set @ 6,130' MD / 5,544' TVD Estimated BHP 10.5 PPG " West Sak "D" top @ 3,062' MD West Sak "B" top @ 3,160' MD West Sak "A4" top @ 3,210' MD West Sak "A3" top @ 3,270' MD West Sak "A2" top @ 3,370' MD West Sak "A1"top @ 3,525' MD Base of West Sak @ 3,665' MD KBG29-1 R, IBTM,Camco GLM inside 5-1/2" TOC @ +/- 5,130' MD 5-1/2" 511 15.5# Casing set @ 7,317' MD / 6,525' TVD . ' Schlumberger CemCADE Preliminary Job Design 5 1 /2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Client: ConocoPhillips Alaska Revision Date: 8/10/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. 7", 26.0# casing at 3,700' MD < Top of Tail at 5,130' MD < 5 1/2", 15.5# casing in 7" OH TD at 7,317' MD (6,525' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 4.5"- 20.0# drill string. The hole will be drilled with a bi-centered bit to achieve a 7" hole. Job Objectives: To achieve TOC = 5130' MD. Tail Slurry Minimum thickening time: 160 min. (pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.02% B155 + 0.3% D65 + 0.2 gps D47 - 1.17 ft3/sk Annular Volume: 0.1023 ft3/ft x (7317' - 3700') x 1.50 (50% excess) = 335.6 ft3 Shoe Volume: 0.1336 ft3/ft x 80' x 1.00 (no excess) = 10.7 ft3 Totals: 335.6 ft3 + 10.7 ft3 = 346.3 ft3 346.3 ft3/ 1.17 ft3/sk = 296 sks Round up to 300 sks BHST = 139, Estimated BHCT = 109. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Cumulative Stage (bpm) Volume Time Time (bbl) (min) (min) Pressure 10.0 - Test CW100 6 25 4.2 4.2 Start Pumping Wash MudPUSH II 6 25 4.2 8.4 Start Pumping S acer Tail Slurry 6 63 10.5 18.9 Mix and Pump Tail Slurr Drop Top 3.0 21.9 Plu Displacement 5 106 21.2 43.1 Start Displacement Slow Rate 3 10 3.3 46.4 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 11.5 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 perjoint from 5130' MD to TD for proper cement placement. Reciprocation: Reciprocation is essential to achieving an adequate cement job due to centralization restrictions associated with hole size. Cleaning hole prior to cementing should assist in achieving reciprocation for as long as possible. ,..~~~~ b ~ ~ Schlumberger CemCAD E*well cementing recommendation for 5.5" Liner Operator : ConocoPhillips Well 2Z-01A Country Field State :Alaska Prepared for :Mike Greener Location Proposal No. : V3 wp06 Service Point Prudhoe Bay Date Prepared : 08-09-2007 Business Phone (907-659-2434 FAX No. (907) 659-2538 Prepared by :Maureen Torrie Phone 1-907-265-6336 E-Mail Address mtorrie@slb.com ~y`~ ~ ~t, n C FL,9 ~UATE ,/ Disclaimer Notice: This information is presented in goad faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger canassist inselecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ORIGINAL • Client ConocoPhillips Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Section 1: well description Configuration Stage Rig Type Mud Line Total MD BHST Bit Size ft o, 0 0 o' v 0 0 0 ~- Liner Single Land 0.0 ft 7317.0 ft :139 degF . 7 in Well ' C4 TD • Schlumb~rgur Lithology Formation Press. 2Z-01ACement,V3.cfw;08-10-2007; LoadCaseS.SLinerVersionwcs-cem452_07 Page 2 ORIGINAL (x 1000) psi Client ConocoPhillips ~~~I r~~r Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Previous String MD OD Weight ID ft in Ib/ft in 3700.0 7 26.0 6.276 Drill Pipe MD OD Weight ID Grade Collapse Burst ft in Ib/ft in psi (si 3500.0 41/2 20.0 3.640 X-95 16410 15890 Liner Hanger :3500.0 ft Landing Collar MD :7237.0 ft Casing/liner Shoe MD :7317.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in si si 7317.0 51/2 40.0 15.5 4.950 L-80 4470 5690 IBTM Page 3 2Z-01ACement,V3.cfw;08-10-2007; LoadCase5.5Liner;Versionwcs-cem452_07 ~~ • Client ConocoPhillips Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Mean OH Diameter :7.000 in Mean Annular Excess :50.0 Mean OH Equivalent Diameter: 7.640 in Total OH Volume :205.1 bbl (including excess) Max. Deviation Angle : 40 deg Max. DLS :4.128 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 28.0 28.0 0.0 0.0 0.000 53.0 53.0 0.1 111.9 -0.200 78.0 78.0 0.1 111.9 0.200 103.0 103.0 0.2 111.9 0.200 128.0 128.0 0.2 111.9 0.200 153.0 153.0 0.3 111.9 0.200 178.0 178.0 0.3 111.9 0.200 203.0 203.0 0.3 112.0 0.120 228.0 228.0 0.3 112.4 0.041 253.0 253.0 0.3 112.7 0.041 278.0 278.0 0.4 113.0 0.041 303.0 303.0 0.4 112.1 0.083 328.0 328.0 0.4 110.0 0.069 353.0 353.0 0.4 108.0 0.068 378.0 378.0 0.4 106.1 0.067 403.0 403.0 0.4 104.6 0.059 428.0 428.0 0.4 103.6 0.050 453.0 453.0 0.4 102.6 0.050 478.0 478.0 0.4 101.6 0.051 503.0 503.0 0.4 99.5 -0.078 528.0 528.0 0.4 95.6 -0.141 553.0 553.0 0.4 91.3 -0.146 578.0 578.0 0.4 86.7 -0.133 603.0 603.0 0.4 85.3 -0.088 628.0 628.0 0.3 88.0 -0.137 653.0 653.0 0.3 91.1 -0.140 678.0 678.0 0.3 94.9 -0.143 703.0 703.0 0.3 96.4 -0.050 728.0 728.0 0.3 94.9 -0.049 753.0 753.0 0.3 93.4 0.028 778.0 778.0 0.3 91.8 -0.049 803.0 803.0 0.3 95.4 0.103 828.0 828.0 0.3 103.0 0.222 853.0 853.0 0.3 108.8 0.208 878.0 878.0 0.4 113.3 0.232 903.0 903.0 0.5 125.5 0.552 928.0 928.0 0.7 138.5 0.928 953.0 953.0 0.9 145.6 0.964 978.0 978.0 1.1 149.9 0.931 1003.0 1003.0 1.5 157.4 1.518 1028.0 1028.0 2.0 165.3 2.172 1053.0 1052.9 2.6 171.7 2.751 1078.0 1077.9 3.4 176.9 3.454 1103.0 1102.8 4.2 179.2 3.061 1128.0 1127.8 4.8 180.2 2.658 1153.0 1152.7 5.6 180.3 3.160 ~~Irg~r 2Z-OtA Cement, V3.cfw ; 08-10-2007 ; Loadcase 5.5 Liner; Version wcs-cem452_07 Page 4 • • Client ConocoPhillips ~~Im~~~rg~r Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 1178.0 1177.5 6.6 179.9 3.724 1203.0 1202.3 7.4 179.7 3.561 1228.0 1227.1 8.3 179.5 3.442 1253.0 1251.8 9.2 180.3 3.752 1278.0 1276.5 10.2 181.8 4.126 1303.0 1301.0 11.1 182.8 3.754 1328.0 1325.5 12.0 183.5 3.407 1353.0 1349.9 12.8 184.1 3.439 1378.0 1374.3 13.7 184.6 3.470 1403.0 1398.5 14.6 185.4 3.762 1428.0 1422.6 15.6 186.5 4.123 1453.0 1446.7 16.5 187.2 3.565 1478.0 1470.6 17.2 187.6 2.996 1503.0 1494.4 18.1 187.7 3.482 1528.0 1518.1 19.1 187.5 4.128 1553.0 1541.7 20.1 187.1 3.917 1578.0 1565.1 21.0 186.4 3.770 1603.0 1588.3 21.9 185.9 3.556 1628.0 1611.5 22.7 185.7 3.294 1653.0 1634.5 23.4 185.6 2.924 1678.0 1657.4 24.0 185.8 2.501 1703.0 1680.1 24.6 185.9 2.286 1728.0 1702.8 25.1 186.0 2.007 1753.0 1725.4 25.6 186.2 2.148 1778.0 1747.9 26.2 186.6 2.385 1803.0 1770.3 26.7 186.9 2.032 1828.0 1792.6 27.1 187.2 1.728 1853.0 1814.8 27.4 187.3 1.214 1878.0 1837.0 27.6 187.3 0.720 1903.0 1859.1 27.9 187.4 1.333 1928.0 1881.1 28.4 187.5 1.969 1953.0 1903.1 28.8 187.8 1.700 1978.0 1925.0 29.1 188.1 1.297 2003.0 1946.8 29.3 188.4 1.024 2028.0 1968.6 29.5 188.8 0.964 2053.0 1990.3 29.6 189.0 0.718 2078.0 2012.0 29.8 189.0 0.720 2103.0 2033.7 30.3 189.2 2.276 2128.0 2055.1 31.3 189.6 4.044 2153.0 2076.4 32.3 189.8 3.704 2178.0 2097.4 33.1 190.0 3.388 2203.0 2118.3 33.8 190.1 3.048 2228.0 2139.0 34.5 190.1 2.720 2253.0 2159.5 35.2 190.2 2.769 2278.0 2179.8 35.9 190.5 2.925 2303.0 2199.9 36.7 190.6 3.009 2328.0 2219.9 37.5 190.7 3.129 2353.0 2239.6 38.2 190.9 3.158 2378.0 2259.2 39.0 191.0 3.130 2403.0 2278.5 39.5 191.1 1.976 2428.0 2297.8 39.7 191.2 0.764 2453.0 2317.0 39.9 191.2 0.680 2478.0 2336.2 40.0 191.3 0.727 2503.0 2355.3 40.1 191.4 0.411 2528.0 2374.4 40.1 191.5 -0.284 2Z-OtACement,V3.cfiv;08-10-2007; LoadCase5.5Liner;Versionwcs-cem452_07 Page 5 Client ConocoPhillips Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner MD ft Directional Survey Data T1/D Deviation Azimuth ft de de Dogleg Sev. de /100ft 2553.0 2393.6 40.0 191.5 -0.120 2578.0 2412.7 40.0 191.6 -0.284 2603.0 2431.9 40.0 191.6 -0.280 2628.0 2451.0 39.8 191.6 -0.440 2653.0 2470.2 39.7 191.6 -0.400 2678.0 2489.5 39.6 191.6 -0.440 2703.0 2508.7 39.6 191.6 -0.120 2728.0 2528.0 39.6 191.6 0.120 2753.0 2547.2 39.7 191.6 0.160 2778.0 2566.5 39.7 191.6 0.120 2803.0 2585.7 39.7 191.8 -0.525 2828.0 2605.0 39.6 192.1 -0.863 2853.0 2624.3 39.5 192.4 -0.844 2878.0 2643.6 39.4 192.7 -0.861 2891.0 2653.6 39.3 192.8 -0.621 2903.0 2662.9 39.4 192.8 0.500 2921.0 2676.8 39.5 192.8 0.500 2928.0 2682.2 39.5 192.8 0.429 2953.0 2701.5 39.6 192.8 0.480 2978.0 2720.7 39.8 192.8 0.520 3003.0 2739.9 39.8 192.8 0.160 3028.0 2759.1 39.8 192.9 -0.325 '' 3053.0 2778.4 39.7 193.0 -0.325 3078.0 2797.6 39.7 193.1 -0.324 3103.0 2816.9 39.6 193.1 -0.200 3128.0 2836.1 39.5 193.1 -0.200 3153.0 2855.4 39.5 193.1 -0.200 3178.0 2874.7 39.5 193.1 -0.200 3203.0 2894.0 39.4 193.1 -0.280 3228.0 2913.4 39.3 193.1 -0.360 3253.0 2932.7 39.2 193.0 -0.440 3278.0 2952.1 39.1 193.0 -0.320 3303.0 2971.5 39.0 193.0 -0.280 3328.0 2990.9 39.0 193.0 -0.200 3353.0 3010.4 39.0 193.0 -0.200 3378.0 3029.8 38.9 193.0 -0.200 3403.0 3049.3 38.8 193.0 -0.280 3428.0 3068.8 38.7 193.0 -0.360 3453.0 3088.3 38.7 193.0 -0.320 3478.0 3107.8 38.6 193.0 -0.360 3503.0 3127.4 38.5 193.0 -0.320 3528.0 3147.0 38.4 193.0 -0.320 3553.0 3166.6 38.3 193.0 -0.320 3578.0 3186.2 38.2 193.0 -0.360 3603.0 3205.8 38.2 192.9 -0.374 3628.0 3225.5 38.1 192.9 -0.280 3653.0 3245.2 38.0 192.8 -0.373 3678.0 3264.9 38.0 192.8 -0.280 3703.0 3284.6 37.8 192.7 -0.648 3728.0 3304.4 37.2 192.0 -3.042 3753.0 3324.4 36.5 191.4 -2.902 3778.0 3344.6 35.9 190.7 -3.015 3803.0 3364.9 35.3 189.9 -3.134 3828.0 3385.4 34.7 189.2 -2.954 3853.0 3406.1 34.1 188.4 -3.036 r~ 2Z-01A Cement, V3.cfw; 08-10-2007 ; Loadcase 5.5 Liner, Version wcs-cem452_07 Page 6 ~ ~ ~ ' ~ a,. • Client ConocoPhillips Well 2Z-01A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner MD ft Directional Survey Data ND Deviation Azimuth ft (de de Dogleg Sev. de /100ft 3878.0 3426.8 33.5 187.7 -2.894 3903.0 3447.8 32.8 186.8 -3.135 3928.0 3468.9 32.2 186.0 -2.953 3953.0 3490.1 31.7 185.1 -3.033 3978.0 3511.4 31.1 184.3 -2.888 4003.0 3532.9 30.5 183.3 -3.093 4028.0 3554.5 29.9 182.4 -2.943 4053.0 3576.2 29.3 181.4 -2.988 4078.0 3598.1 28.8 180.3 -3.096 4103.0 3620.1 28.2 179.3 -2.913 4128.0 3642.1 27.7 178.2 -3.016 4153.0 3664.3. 27.1 177.0 -3.062 4178.0 3686.6 26.6 175.9 -2.907 4203.0 3709.0 26.1 174.6 -3.081 4228.0 3731.5 25.6 173.4 -2.923 4253.0 3754.1 25.1 172.0 -3.097 4278.0 3776.8 24.6 170.7 -2.910 4303.0 3799.6 24.2 169.2 -3.110 4328.0 3822.4 23.7 167.8 -2.898 4353.0 3845.3 23.3 166.2 -3.099 4378.0 3868.4 22.9 164.7 -2.889 4403.0 3891.4 22.4 163.0 -3.089 4428.0 3914.6 22.0 161.3 -3.010 4453.0 3937.8 21.7 159.6 -2.953 4478.0 3961.0 21.3 157.8 -2.987 4503.0 3984.3 21.0 155.9 -3.044 '~ 4528.0 4007.7 20.7 154.0 -2.990 4553.0 4031.1 20.4 152.0 -3.035 4578.0 4054.6 20.1 150.0 -2.971 4603.0 4078.1 19.9 147.9 -3.028 4628.0 4101.6 19.6 145.8 -2.973 4653.0 4125.2 19.5 143.7 -2.922 4678.0 4148.7 19.4 142.6 -1.506 4703.0 4172.3 19.4 142.6 0.000 4728.0 4195.9 19.4 142.6 0.000 4753.0 4219.5 19.4 142.6 0.000 4778.0 4243.1 19.4 142.6 0.000 4803.0 4266.7 19.4 142.6 0.000 4828.0 4290.3 19.4 142.6 0.000 4853.0 4313.8 19.4 142.6 0.000 4878.0 4337.4 19.4 142.6 0.000 4903.0 4361.0 19.4 142.6 0.000 4928.0 4384.& 19.4 142.6 0.000 4953.0 4408.2 19.4 142.6 0.000 4978.0 4431.8 19.4 142.6 0.000 5003.0 4455.4 19.4 142.6 0.000 5028.0 4478.9 19.4 142.6 0.000 5053.0 4502.5 19.4 142.6 0.000 5078.0 4526.1 19.4 142.6 0.000 5103.0 4549.7 19.4 142.6 0.000 5128.0 4573.3 19.4 142.6 0.000 5153.0 4596.9 19.4 142.6 0.000 5178.0 4620.5 19.4 142.6 0.000 5203.0 4644.0 19.4 142.6 0.000 5228.0 4667.6 19.4 142.6 0.000 r: t ~ ,,~ ~ € '£ is 2Z-01ACement,V3.cfw;08-10-2007; LoadCase5.5Liner;Versionwcs-cem452_07 Page 7 • • Client ConocoPhillips Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. ft ft de de de /100ft 5253.0 4691.2 19.4 142.6 0.000 5278.0 4714.8 19.4 142.6 0.000 5303.0 4738.4 19.4 142.6 0.000 5328.0 4762.0 19.5 143.3 1.178 5353.0 4785.5 19.8 144.3 1.607 5378.0 4809.0 20.0 145.1 1.399 5403.0 4832.5 20.2 146.0 1.541 5428.0 4855.9 20.4 146.9 1.552 5453.0 4879.4 20.7 147.7 1.478 5478.0 4902.7 20.9 148.5 1.488 5503.0 4926.1 21.2 149.3 1.497 5528.0 4949.3 21.4 150.1 1.533 5553.0 4972.6 21.7 150.8 1.434 5578.0 4995.8 21.9 151.6 1.553 5603.0 5019.0 22.2 152.3 1.478 5628.0 5042.1 22.4 153.0 1.487 5653.0 5065.2 22.7 153.7 1.495 5678.0 5088.3 23.0 154.4 1.504 5703.0 5111.3 23.2 155.1 1.540 5728.0 5134.2 23.5 155.7 1.439 5753.0 5157.1 23.8 156.4 1.586 5778.0 5180.0 24.0 157.0 1.483 5803.0 5202.8 24.3 157.6 1.461 5828.0 5225.5 24.6 158.2 1.528 5853.0 5248.2 24.9 158.8 1.505 5878.0 5270.9 25.2 159.4 1.542 5903.0 5293.5 25.5 159.9 1.409 5928.0 5316.0 25.8 160.5 1.586 5953.0 5338.5 26.0 161.0 1.452 5978.0 5360.9 26.3 161.5 1.458 6003.0 5383.3 26.6 162.0 1.495 6028.0 5405.6 26.9 162.5 1.501 6053.0 5427.9 27.2 163.0 1.506 6078.0 5450.1 27.5 163.5 1.512 6103.0 5472.2 27.8 164.0 1.518 6128.0 5494.3 28.1 164.5 1.555 6153.0 5516.3 28.5 164.9 1.420 6178.0 5538.3 28.8 165.4 1.567 6203.0 5560.1 29.1 165.8 1.462 6228.0 5582.0 29.4 166.2 1.466 6253.0 5603.7 29.7 166.7 1.584 6278.0 5625.4 30.0 167.1 1.474 6303.0 5647.0 30.0 167.1 0.000 6328.0 5668.7 30.0 167.1 0.000 6353.0 5690.3 30.0 167.1 0.000 6378.0 5712.0 30.0 167.1 0.000 6393.0 5725.0 30.0 167.1 0.000 6403.0 5733.6 30.0 167.1 0.000 6428.0 5755.3 30.0 167.1 0.000 6453.0 5776.9 30.0 167.1 0.000 6478.0 5798.6 30.0 167.1 0.000 6503.0 5820.2 30.0 167.1 0.000 6508.0 5824.6 30.0 167.1 0.000 6528.0 5841.9 30.0 167.1 0.000 6553.0 5863.6 30.0 167.1 0.000 ~GI r~~r 2Z-01ACemenl,V3.cfw;08-10-2007; LoadCase5.5Liner;Versionwcs-cem452_07 Page 8 Client ConocoPhillips Well 2Z-01A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 6578.0 5885.2 30.0 167.1 0.000 6603.0 5906.9 30.0 167.1 0.000 6628.0 5928.5 30.0 167.1 0.000 6653.0 5950.2 30.0 167.1 0.000 6678.0 5971.8 30.0 167.1 0.000 6703.0 5993.5 30.0 167.1 0.000 6728.0 6015.1 30.0 167.1 0.000 6739.0 6024.6 30.0 167.1 0.000 6753.0 6036.8 30.0 167.1 0.000 6778.0 6058.4 30.0 167.1 0.000 6803.0 6080.1 30.0 167.1 0.000 6828.0 6101.7. 30.0 1.67.1 0.000 6853.0 6123.4 30.0 167.1 0.000 6878.0 6145.0 30.0 167.1 0.000 6903.0 6166.7 30.0 167.1 0.000 6928.0 6188.3 30.0 167.1 0.000 6953.0 6210.0 30.0 167.1 0.000 6978.0 6231.6 30.0 167.1 0.000 7003.0 6253.3 30.0 167.1 0.000 7028.0 6274.9 30.0 167.1 0.000 7053.0 6296.6 30.0 167.1 0.000 7078.0 6318.2 30.0 167.1 0.000 7103.0 6339.9 30.0 167.1 0.000 7128.0 6361.5 30.0 167.1 0.000 7153.0 6383.2 30.0 167.1 0.000 7178.0 6404.8 30.0 167.1 0.000 7203.0 6426.5 30.0 167.1 0.000 7228.0 6448.1 30.0 167.1 0.000 7253.0 6469.8 30.0 167.1 0.000 7278.0 6491.4 30.0 167.1 0.000 7281.0 6494.0 30.0 167.1 0.000 7303.0 6513.1 30.0 167.1 0.000 7317.0 6525.2 30.0 167.1 0.000 MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 6456.0 15.00 8.50 C4 Sandstone 6491.0 15.00 8.50 C3 Sandstone 6506.0 15.00 8.50 C2 Sandstone 6526.0 15.00 8.50 C1 Sandstone 6541.0 15.00 8.50 Top B Sandstone 6676.0 15.00 11.00 A5 Sandstone 6687.0 15.00 11.00 A4 Sandstone 6739.0 15.00 11.00 A3 Sandstone 6791.0 15.00 11.00 Base Kuparek Sandstone 7317.0 15.00 11.00 TD Sandstone clrg~r 2Z-01ACement,V3.cfw;08-10-2007; Loadcase 5.5 Liner Versionwcs-cem452_07 Page 9 ~~ ! • Client ConocoPhillips Schlumberger Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1600.0 1585.3 30 0.3 7317.0 6525.2 139 1.7 ft o- 0 0 o' v O O 0 ao. degF Temperature 0 O o ~ x v U- ~..5 r Hori. Departure 2Z-01 A Cement, V3.cfw ; OB-10-2007 ; toadCase 5.5 Liner ; Version wcs-cem452_07 Page 10 ORIGINAL (x 1 D00) ft • • Client ConocoPhillips Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Section 2: centralizer placement Top of centralization :3530.0 ft Bottom Cent. MD :7267.0 ft Casing Shoe :7317.0 ft NB of Cent. Used :186 Sc~l~~b~rger NB of Floating Cent. :186 Centralizer Placement Bottom MD Nbr. Cent. I Cent. Name Code Min. STO @ Depth ft Joint % ft 7277.0 186 2/1 5.5" LINER 5.5" 0.0 3697.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf 5.5" LINER 5.5" 51/2 6.125 6.125 Yes 5.5" Liner N.A. N.A. N.A. (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications f o- O _ V O O ~- f... T 1 f ~ ~ j I ~ I Deviation (x 1000) ft 0 1 2 3 Hori. Depart. fi~ 0 o ~ r I T 1... ~ i o N I ,_ ~__ In _ ,-. N ~ C.._.:::.:: i .. O 5 H ~ o ~ O O X ~ .~ ~ O N N ~ _ ._'_~:..._i O _ f0 ~ :. .: ... O '. Hori. Departure Page 11 2Z-01A Cement. V3.cfw ; 08-10-~2''"0'0~J7 ; Loa+d/~`alse 5.5 L1Ain\er, Version wcs-cem452_07 / ! \ ~ V • • Client ConocoPhillips Well 2Z-01 A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 11.50 Ib/gal Rheo. Model : GINGHAM P~ :15.000 cP At temp. : 80 degF Tv :20.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type : WBM Job volume :134.0 bbl Water Type :Fresh CW100 DESIGN Fluid No: 2 Density : 8.33 Ib/gal Rheo. Model :NEWTONIAN At temp. : 80 degF Viscosity :5.000 cP Gel Strength : (Ibf/100ft2) Job volume :25.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 13.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 6.92E-2 Ibf.s^n/ft2 At temp. :120 degF n :0.323 Ty :12.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :25.0 bbl G w/GasBLOK DESIGN Fluid No: 4 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL_B. k : 3.87E-3 Ibf.s"n/ft2 At temp. :107 degF n :0.878 Ty :40.461bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type :Fresh water SLURRY Mix Fluid :5.162 gal/sk Yield :1.17 ft3/sk Porosity :59.2 Density :8.321b/gal Job volume :61.7 bbl Quantity : 297.10 sk Solid Fraction :40.8 Base Fluid :2.962 gal/sk 2Z-01ACement,V3.ciw;08-10-2007; LoadCaseS.SLiner;Versionwcs-cem452_07 Page 12 ORIGINA:i. ~ i Client ConocoPhillips ~) r~Yr Well 2Z-01A String 5.5 District Prudhoe Bay Country Loadcase 5.5 Liner Section 4: fluid sequence Job Objectives: To achieve TOC = 5130' MD. Original fluid Mud 11.50 Ib/gal P~ :15.000 cP Tv :20.00 Ibf/100ft2 Displacement Volume 134.0 bbl Drill Pipe Volume 45.0 bbl Total Volume 245.7 bbl TOC 5130.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW 100 25.0 1212.7 3002.3 8.33 viscosity:5.000 cP MUDPUSH II 25.0 915.0 4215.0 13.50 k:6.92E-2 Ibf.s^n/ft2 n:0.323 Tv:12.00 Ibf/100ft2 G w/GasBLOK 61.7 2187.0 5130.0 15.80 k:3.87E-3 Ibf.s^n/ft2 n:0.878 Tv:40.46 Ibf/100ft2 Mud 134.0 0.0 11.50 P~:15.000 cP Tv:20.00 Ibf/100ft2 Static Security Checks Frac 686 psi at 3700.0 ft Pore 394 psi at 6676.0 ft Collapse 3737 psi at 7237.0 ft Burst 5528 psi at 4215.0 ft Cs .Pump out 43 ton Section 5: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. de F CW100 6.0 10.0 1.7 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure Test CW100 6.0 15.0 2.5 25.0 80 MUDPUSH II 6.0 25.0 4.2 25.0 80 G w/GasBLOK 6.0 61.7 10.3 61.7 80 Pause 0.0 0.0 5.0 0.0 80 Drop plug Mud 5.0 114.0 22.8 114.0 80 Mud 3.0 20.0 6.7 134.0 80 Total 01:03 245.7 bbl hr:mn Dynamic Security Checks Frac 87 psi at 3700.0 ft Pore 22 psi at 6687.8 ft Collapse 3607 psi at 3750.9 ft Burst 4773 si at 4215.0 ft 2Z-01ACement,V3.cfw;08-10-2007; Loadcase 5.5 Liner Versionwcs-cem452_07 Page 13 OR161NA~. Client Well String District Country Loadcase • ConocoPhillips 2Z-01 A 5.5 Prudhoe Bay 5.5 Liner Ib/gal ft 8 12 0 Mn. kydrostatic Max.Cynamc Min. Dynarric Frac -Pore - Hydrostatic 0 0 o- v O O W- Fluid Sequence 0 0 0 Dynamic Well Security • Schlumherger 16 ~ ~ Calc. Rmp Ress. - Calc. VVFiP 0 _Op X ~ ~ ,N _:....... a,n ao 2 0 0 100 200 300 Pumped Volume (bbl) De th = 7317 ft o OM -Annular Velocity c N T O i ~ O ~ C C Q . O 0 100 200 300 Pumped Volume (bbl) veom = f a I r n ~o y n ~~ a` `_, o Pumped Volume (bbl) m +a a~ ~~ ~ N a~ c c Q 27C Pumped Volume (bbl) Page 14 2Z-OtACement,V3.cfw;08-10-2001: Load Case 5.5 Liner; Versionwcs-cem452_07 a~ • • Client Well String District Country Loadcase Secti ft o -, 0 0 o- v 0 0 0 ~- ConocoPhillips 2Z-Ot A 5.5 Prudhoe Bay 5.5 Liner on 6: WELLCLEAN II Simulator Fluid Sequence Cement Coverage Fluids Concentrations 5200 5400 5&00 5800 saoo t 8200 r o fi400 0 6ii00 saoo ,QOo '200 0 z ~ Mud Q MUDPUSH II D G wlGasBLOK ~ Cw100 deg ~chlumhurgur Uncontaminated Slurry Deviation R isk M ud on the WaN 'fit` x°. 5204 s 5200 5600- I 5800 svoa- saoo r o s2oa- a,oa = ~ szoo r fi4oo 0 6fi04- 6 fi00 6606- 8800 ,ooa- ~ f- saoo ~zoa- ~ ~soo o° o a _ ~ o x 0 High Low ~ Medium ~ None Page 15 2Z-01A Cement, VO.cfw; 00-10-2007: Loadcase 5.5 Liner; Version wcs-cem452_07 ORIGINAL • • TRANSMITTAL LETTER CHECKLIST WELL NAME /~ l~ ~/l ~ ~ -~ PTD# ?ice ~ "~ _ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full. compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception.. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until. after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCom~any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev:7/l3/2007 WELL PER lT CHECKLIST Field & Pool Well Name: KUPARUK RIV UNIT 2Z-01A Program DEV Well bore seg ^ PTD#:2071110 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit fee attached NA --- - - - 2 Lease number appropriate_ - - . - - - Yes Top_prod_interyalond TD in ADL 025653.. - - - - - . - -- 3 Uniquewell_nameandnumber_____________________________ _________ Yes_ ______-___- 4 Well located in.a_defned-pool- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - - - KUPARUK RIVER~KUPA_RUK_RVOIL- 490100, governed by Cgnservati_on Order No. 432C._ - - 5 Well located proper distance from drilling unitboundary- - - - - - -- - - - - - -- - - - - - - --- Yes - - - - - - .Conservation Order No. 432G contains no spacing restrictions with respect-to drilling unit boundaries. - . - - - 6 Well located proper distance from other wells_ - - _ _ - - - Yes Conservation Order No. 4320 has_no intenvell_spacing_restrictions, -------------------- 7 Sufficient acreage available in-drilling un_it_ Yes - - . - - ..Conservation Order No. 4320 has no intenyell_spacing_restrictions- - - - - - - - - - - - - 8 If_deviated, is wellbore plat_included Yes - _ - - - - . an external property line-where_ownership or_lan_downership_changes. 9 Operator only affected party- - - - - Yes - - - - -------------------------- 10 Operator has_appropriate.bondinforce- ----- - -- .._...- - -- Yes- ----- -- ------------- ----------- - -- -------- ---- ------- - - 11 Permit can be issued_w_ithoutconservationorder___________________ ________ Yes_ ____- - -- - -- Appr Date 12 Pe[mitcanbeissued_w_ithoutadministrativ_e_appr_oval________________ _________Yes_ ___-_-__--.--_--_--_--_-_____________-___-_-__-__--__----.-_---_- SFD 811412007 13 Can permit be approved before 15-day wait Yes 14 Well.located within area and-strata authorized by Injection Order ~ (put 10# in_comments)_ (For_ NA _ _ - - - _ - - _ - - 15 Allwells.within1l4.milearea_ofreyiewidentified(Forsetuieewellonly)______ _________NA_ ______-___--______-_.-..--.__________-___-___-_________-___-__._..---,---- 16 Pre-produced injectgr. du[atio-n-of p[e;production less than 3 months-(Fgr service well only) NA_ - - - - - - - - - - - - - - 17 Nonconven: gas conforms to AS31,05,030(j.1_.A),Q.2.A-D) NA - - - - - - Engineering 18 Conductor string.provided------------------------_-___-_ _________ NA__ ______Con_ductgr_setin2Z-01(183-073).-___-___-____________________ 19 Surface-casingproieetsalLknpwn USDWs_____________________ _____NA_ __-Allaqu'rfers exempted, 40CFR-147.103(b)(3)._______________--_-_-_-___-.---_____ 20 CMT.voladequate-tocircul_ate_onconductor&surf_csg_______________ ______ __NA- --_--_Surfacecasingset in 2Z-01,_____ __ _-__-_----.__-.-__-__-_- --__,- 21 CMT_vol adequate-to tie-in long string to surf csg- - - - - - - - - - - - - - - - - - - No_ Liner will be set above-7" window. - - _ _ - _ - _ - - 22 CMT-willcoverallkno_wn_productivehorizon_s_____________________ ______ __Yes_ ___---_-------_--______________________ - - 23 Casing desigtrs adequate for C, T, B &-permafrost Yes - - - - - 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - - - Yes - Rig is_equipped with steel_pits.- No reserve_pit_planned. All waste to_appr_oved disposal well(s).- - - - _ - - - 25 If_a_re-drill,has_a10-403forabandonmentbeenapprov_ed_----------- ---------Yes,_ _--_307-264_________ __-_,___--__-.---.--,--_-____--__--__--__ _-.-- 26 Adequate wellbore separatjon_p[oposed _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity analysis performed: Nearest segment is abandoned portion_ of 2Z-01 and_ paths diverge._ _ _ _ - _ - _ 27 Ifdiverterrequired,doesitmeetregulations______________________ _________ NA__- __-._BOPstackwillalreadybe_inplace._______________-,--__-____--_---__---_--___ Appr Date 28 Drilling fluid_ program sehematic.& equip list adequate. - - - - - - Yes - - . _ . .Maximum expected formation pressure 10.6 EMW._ MW planned up-to 11.3 ppg__ _ _ __ _ _ __ _ _ _ _ _ _ _ _ _ _ _ TEM 8/16/2007 29 BOPEs,-do they meet regulation - Yes - - - - - A 30 _B_OPE_press rating appropriate; test to.(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ _ _ MASP calculated at 2652psi, 3500-psi_BOP tesiplanned, _ _ _ _ _ - _ _ _ _ - _ _ _ _ - - _ - _ - - _ _ - - - _ _ _ _ _ 31 Choke manifold complies wlAPI. RP-53 (May 84) Yes - - - - -- 32 Work will occur w~hout operation shutdown- - - Yes - - -- 33 Is presence_ of H2S gas probable - - - - - - - - - - - - - - - - - - - - Yes - - - - - - H2S is reported-on 2Zpad.- Mud_ should preclude_Fl2$_on ng._ Rig has sensors and_alarms._ .. - - .. - - - 34 Mechanical-condition of wells withinAORyerified(FOrservicewellonly)----- --------- NA__- ____-________-________-__---__--___----.-_-_--___-__- Geology 35 Permit can be issued wlo- hydrogen-sulfide measures - No- _ - --- - _ _ - - KRU 2Z-01 measured 230 ppm H2$ on_ 1011.312006-- - - - - - - - - - - - - - - - - - - - - 36 Data_presented ora potential overpressure zones - - - - - - - - - - - - - - Yes Expected reservoir-pressure is 10.6ppg EMW; will be drilled with 11.3 ppgmud. - Appr Date 37 Seismic_analysisofshallewgas-zones--.--..--______________ _ NA __ -_-___---_--- SFD 8114/2007 38 Seabed conditionsurvey_(ifoff-shore)-_______----__----_--__ __-_ __-_ NA___ _______________ 39 Contact name/phoneforweekly-progress reports[exploratoryonly]________ ________ NA--_ --__--__- -_____________ _____--_---_-----_-___--_-_-_---_ Geologic Engineering Public Date: Date Date Redrill of onshore Ku aruk C and A roducer. p p Commissioner: Commissioner: Co finer • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Welt Permitting Process but is part of the history file. To improve the readability of the Well History file and to sirnpRfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. 2z-Ola.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb Ol 15:11:59 2008 Reel Header Service name .............LISTPE Date . ...................08/02/01 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/02/01 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LI5 writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 w-0005160206 T. GALVIN D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2z-OlA 500292095301 ConocoPhillips Alaska, Inc. Sperry Drilling Services Ol-FEB-08 11 11N 9E 1770 577 100.80 72.80 Page 1 ~o? -! l Job ~ l5~'~a 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 2z-Ola.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 7.000 3710.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE - NO DATA ARE PRESENTED. THE TOP OF THE WHIP- STOCK WAS AT 3710'MD/3290'TVD. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON (CTN), BI- MODAL ACOUSTIC TOOL (BAT) IN RECORDED MODE ONLY, AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2 REPRESENT WELL 2Z-OlA WITH API#: 50-103-20953-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6950'MD/6216'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. Page 2 2z-Ola.tapx DENSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. DTCP = SMOOTHED COMPRESSIONAL WAVE SLOWNESS POST-WELL PROCESSED. DTSP = SMOOTHED SHEAR WAVE SLOWNESS POST-WELL PROCESSED. VPVS = RATIO OF COMPRESSIONAL AND SHEAR VELOCITIES. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6~~ X 7~~ BI-CENTERED BIT (7~~ HOLE SIZE) MUD WEIGHT: 9.6-11.3 PPG MUD SALINITY: 600-1100 PPM CHLORIDES FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FCNT 3695.0 6854.0 NCNT 3695.0 6854.0 PEF 3700.0 6869.0 RHOB 3700.0 6869.0 DRHO 3700.0 6869.0 NPHI 3700.0 6854.0 GR 3706.0 6892.5 ROP 3710.5 6950.0 RPS 3713.0 6899.5 RPM 3713.0 6899.5 RPx 3713.0 6899.5 FET 3713.0 6899.5 RPD 3713.0 6899.5 DTC 3790.0 6824.5 DTSH 3808.5 6824.5 SCRA 3808.5 6824.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3695.0 6950.0 Page 3 • $ 2z-Ola.tapx REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction. .Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 DTC MWD USPF 4 1 68 12 4 DTSH MWD USPF 4 1 68 16 5 RHOB MWD G/CM 4 1 68 20 6 DRHO MWD G/CM 4 1 68 24 7 RPD MWD OHMM 4 1 68 28 8 RPM MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 RPX MWD OHMM 4 1 68 40 11 FET MWD HOUR 4 1 68 44 12 GR MwD API 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 ROP . MWD FT/H 4 1 68 56 15 NPHI MWD PU-S 4 1 68 60 16 SCRA MWD 4 1 68 64 17 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 3695 6950 5322.5 6511 3695 6950 FONT MWD CNTS 3.16 45.01 10.2732 6148 3695 6854 NCNT MWD CNTS 459.75 1434.86 756.514 6148 3695 6854 DTC MWD USPF 69.5988 130.844 109.209 6070 3790 6824.5 DTSH MWD USPF 120.869 281.5 230.673 5613 3808.5 6824.5 RHOB MWD G/CM 0.023 2.939 2.31637 6339 3700 6869 DRHO MWD G/CM -3.525 0.324 0.0669579 6339 3700 6869 RPD MWD OHMM 0.7 53.78 3.32834 6374 3713 6899.5 RPM MWD OHMM 0.64 59.98 3.18718 6374 3713 6899.5 RPS MWD OHMM 0.67 63.62 3.20091 6374 3713 6899.5 RPX MWD OHMM 0.64 48.38 3.1473 6374 3713 6899.5 FET MWD HOUR 0.36 25.59 1.86715 6374 3713 6899.5 GR MwD API 33.56 555.89 127.549 6374 3706 6892.5 PEF MWD BARN 2.23 14.66 5.02094 6339 3700 6869 ROP MWD FT/H 0.16 206.79 59.4774 6480 3710.5 6950 NPHI MWD PU-S 10.86 66.5 34.3177 6309 3700 6854 SCRA MWD 1.5117 2.6562 2.11695 5613 3808.5 6824.5 First Reading For Entire File..........3695 Last Reading For Entire File...........6950 Page 4 r~ U 2z-Ola.tapx File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DRHO 3695.0 6869.0 NCNT 3695.0 6854.0 NPHI 3695.0 6854.0 FCNT 3695.0 6854.0 PEF 3695.0 6869.0 RHOB 3695.0 6869.0 GR 3706.0 6892.5 ROP 3710.5 6950.0 FET 3713.0 6899.5 RPD 3713.0 6899.5 RPS 3713.0 6899.5 RPX 3713.0 6899.5 RPM 3713.0 6899.5 DTC 3790.0 6824.5 SCRA 3808.5 6824.5 DTSH 3808.5 6824.5 LOG HEADER DATA DATE LOGGED: 24-SEP-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6950.0 TOP LOG INTERVAL (FT): 3763.0 BOTTOM LOG INTERVAL (FT): 6950.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.7 MAXIMUM ANGLE: 37.2 Page 5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN BAT EWR4 ALD 2z-Ola.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Bi-modal Acoustic Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 TOOL NUMBER 64001 10603684 145211 228501 10508942 7.000 3710.0 Polymer 10.50 45.0 9.5 600 3.5 4.900 72.0 2.371 156.0 1.960 72.0 1.930 72.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 DTC MWD020 USPF 4 1 68 12 4 DTSH MWD020 USPF 4 1 68 16 5 RHOB MWD020 G/CM 4 1 68 20 6 DRHO MWD020 G/CM 4 1 68 24 7 RPD MWD020 OHMM 4 1 68 28 8 RPM MWD020 OHMM 4 1 68 32 9 RPS MWD020 OHMM 4 1 68 36 10 RPX MWD020 OHMM 4 1 68 40 11 FET MWD020 HOUR 4 1 68 44 12 Page 6 • 2z-Ola.tapx GR MwD020 API 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 ROP MWD020 FT/H 4 1 68 56 15 NPHI MwD020 Pu-s 4 1 68 60 16 SCRA MWD020 4 1 68 64 17 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3695 6950 5322.5 6511 3695 6950 FCNT MWD020 CNTS 3.16 45.01 10.2732 6148 3695 6854 NCNT MWD020 CNTS 459.75 1434.86 756.514 6148 3695 6854 DTC MWD020 USPF 69.5988 130.844 109.209 6070 3790 6824.5 DTSH MwD020 USPF 120.869 281.5 230.673 5613 3808.5 6824.5 RHOB MwD020 G/CM 0.023 2.939 2.31293 6349 3695 6869 DRHO MWD020 G/CM -3.525 0.324 0.0638052 6349 3695 6869 RPD MWD020 OHMM 0.7 53.78 3.32834 6374 3713 6899.5 RPM MWD020 OHMM 0.64 59.98 3.18718 6374 3713 6899.5 RPS MWD020 OHMM 0.67 63.62 3.20091 6374 3713 6899.5 RPX MWD020 OHMM 0.64 48.38 3.1473 6374 3713 6899.5 FET MwD020 HOUR 0.36 25.59 1.86715 6374 3713 6899.5 GR MWD020 API 33.56 555.89 127.549 6374 3706 6892.5 PEF MwD020 BARN 2.23 14.66 5.0326 6349 3695 6869 ROP MWD020 FT/H 0.16 206.79 59.4774 6480 3710.5 6950 NPHI MWD020 Pu-S 10.86 66.5 34.3326 6319 3695 6854 SCRA MwD020 1.5117 2.6562 2.11695 5613 3808.5 6824.5 First Reading For Entire File..........3695 Last Reading For Entire File...........6950 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/01 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................08/02/01 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Page 7 • i 2z-Ola.tapx Comments .................STS LIS writing Library. scientific Technical services Physical EOF Physical EOF End Of LIS File Page 8 ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 2Z-01 A Provided by: [~ EPOCH Approved by: Compiled by: Brian O'Fallon Ralph Winkelman Date: 09/24/07 Distribution:~od~oc%oc ConocoPhillips Alaska, Inc. 2Z-01 A i TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW .................................................................. ..2 1.1 Equipment Summary ......................................................................................... ..2 1.2 Crew .................................................................................................................. ..2 2 WELL DETAILS ....................................................................................................... ..3 2.1 Well Summary ................................................................................................... ..3 2.2 Hole Data ........................................................................................................... ..3 3 GEOLOGICAL DATA ............................................................................................... ..5 3.1 Lithostratigraphy ................................................................................................ ..5 3.2 Mudlog Summary ............................................................................................... ..6 3.3 Connection Gases ............................................................................................. .. 9 3.4 Trip (Wiper) Gases ............................................................................................ ..9 3.5 Sampling Program /Sample Dispatch ............................................................... 10 4 PRESSURE /FORMATION STRENGTH DATA ..................................................... 11 4.1 Pore pressure evaluation .................................................................................. 11 5 DRILLING DATA ...................................................................................................... 12 5.1 Survey Data ....................................................................................................... 12 5.2 Bit Record .......................................................................................................... 13 5.3 Mud Record ....................................................................................................... 14 6 MORNING REPORTS ............................................................................................. 15 • Enclosures 2"/100' Formation Log {MD) 2"/100' Drilling Dynamics Log 2"/100' LWD / Lithology Log 2"/100' Gas Ratio Log • ~ ~P~CH ConocoPhillips Alaska, Inc. 2Z-01A • 1 MUDLOGGING EQUIPMENT 8~ CREW 1.1 Eauipment Summary • • Parameter Equipment Type t Position TO~I Downtime Comments QGM Agitator (Mounted in possum Ditch as g belly) 0 Flame ionization total gas 8~ chromato rah . Effective Circulating Density From Sperry-Sun 1389' to TD 0 ECD Hoak Load / Wei ht on bit Totco Watts Feed 0 Mud Flow In Derived from Strokes/Minute and 0 Pum Out ut Mud Flow Out Totco Watts Feed 0 Mudlogging unit computer HP Compaq Pentium 4(X2, DML 8~ 0 s tem Ri watch Mudlo in unit DAC box gg g In-unit data collection/distribution 0 center Pit Volumes, Pit Gain/Loss Totco Watts Feed 0 Pum Pressure Totco Watts Feed 0 Pum stroke counters Totco Watts Feed 0 Totco Well Monitoring Totco computer networked in 0 Com onents Mudlo in Unit Rate of enetration Totco Watts Feed 0 RPM Totco Watts Feed 0 Tor ue Totco Watts Feed 0 1.2 Crew Unit Type Unit Number ~ ML030 Mudloggers Years =~ Da s .~ Sample Catchers Years Days Technician Days Brian O'Fallon 18 9 Nick Moir .2 10 Dan Lee Z Ral h Winkelman 16 10 Mike Marsh .Z 10 'Years experience as Mudlogger '~ Days at wellsite between spud and total depth of well ~ EPOCH ConocoPhillips Alaska, Inc. 2Z-01A • 2 WELL DETAILS 2.1 Well Summary C Well: 2Z-01A API Index #: 50-029-20953-01 Field: Kuparauk River Field Surface Co-Ordinates: 1770'FSL, 577'FEL, Sec 11, T11 N, R09E, UM Borough: North Slope Primary Target Depth: A4 Sand, 6739' MD, 6025'TVD State: Alaska TD Depth: 6950' MD Rig Name /Type: Doyon 141, Arctic Triple Suspension Date: Primary Target: A Sands License: Spud Date: 9/19/2007 Ground Elevation: 72.3' MSL Completion Date: 9/24/2007 RT Elevation: 100.3' MSL Completion Status: Ran 5.5" Liner to TD. Secondary Target: De the None Classification: Production TD Date: 9/24/2007 TD Formation: Base Kuparuk Days Testing: NONE Days Drilling: 6 2.2 Hole Data H l Maximum De th TD Mud Casin Shoe De th LOT o e Section MD TVDSS Formation Weight ~v o. (inc) Corin g g/ MD TVDSS (ppg) ft ft ~ppg) Liner ft ft 7" 6950' 6116 Bas U 11 3 27.87 none 5.5" 3710 3190 14.3 r k K . Additional Comments The 2Z-01A was drilled by setting a whipstock in the e~asting 7fl casing and milling a window. TOW = 3710' BOW = 3723'. 40' new formation was drilled to 3763' and aFIT = 14.3 EQMW was established.. A 15 stand wiper trip was performed at 6312' with no problems. No problems were encountered in the drilling of this well. • EPOCH ConocoPhillips Alaska,lnc. ZZ-01A Daily Activity Summary: 9/17/2007; Finish Rip Up Epoch Unit. Wait on Phone Llne. Phone Line installed, and Totco Wttts feed setup. Rig nippling up and testing BOP. 9/18/2007: Pulled test plug, retrieved and L/D storm packer, and L/D 3112" tubing. M/U and RIH with scraper assembly to 6284', picking up drill pipe. Circulate 2 bottoms up, max 28 units of gas, and POOH. RIH with wireline and set CIBP at 3727'. POOH and test CIBP and casing to 3000 psi. 9/19/2007: Pick up HWDP and DC and makeup 7"whipstock assembly. Trip in hole to 3710' and mill to 3763'. Pump high vis sweep, and rig up and perform FIT to 14.3 EMW. Begin POOH with mill assembly. 9/20!2007: POOH with Mill Assembly, mill bit in gauge. Make up directional assembly with Mud Motor, new bit no. 1, LWD and MWD. RIH and drill, rotating and some sliding, from 3763 to 4439', dropping angle. 9/21/2007: Drill from 4439' to 5478', rotating and some sliding, dropping angle to approximately 19 degrees, maintaining tangent, and begin building angle. 9/22/2007: Drill from 5478 to 6313', rotating and some sliding, building angle to begin tangent. Begin 15 stand wiper trip. 9123/2007: Complete 15 stand wiper trip, trip gas 740 units. Drill from 6313' to 6773', rotating and minor sliding, maintaining tangent at approximately 30 degrees 9/2412007: Drilled, rotating, from 6773' to 6950' (total depth). Wiper trip 12 stands, pump sweep and circulate, trip gas 1476u. POOH. 9/25/2007: L/D BHA, M/U and RIH with clean out assembly. Pump Hi-V~s sweep, 726 units of trip gas. POOH and L/D clean out assembly. RN anf RIH with 5.5" liner. Test floats. MN hanger packer. Packer damaged and L/D packer. Slip and cut drilling line. Wait on new Packer 9/2612007: Epoch released to rig down. • ~ EPOCH 4 ConocoPhillips Alaska, Inc. u-o1A 3 GEOLOGICAL DATA 3.1 Lithostratiaraahv • LWD tops refer to provisional picks by the mudlogger. PROGNOSED LWD PICK FORMATION MD ft TVD ft MD ft TVD ft Top HRZ 5980 5290 6125 5496 Base HRZ 6250 5560 6352 5696 K-1 6370 5728 6460 5788 G4 6508 5825 6535 5853 C3 6543 5855 C2 6558 5858 C1 6578 5885 Top B 6593 5898 AS 6728 6015 6710 6004 A4 6739 6025 A3 6791 6070 Base Kuparuk 6843 6115 TD 7317 6525 6950 6216 ~ EPOCH ConocoPhillips Alaska,lnc. 2Z-01A 3.2 Mudlop Summary Casing Point to top HRZ 3710' to 6125' MD 3190' to 5396' TVDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 225 9 74 1069 6 144 This interval includes siltstone, claystone, sand, and sandstone, until approximately 5500', when carbonaceous shale is encountered similar to the underlying HRZ. One notable oil sand occurred at 4190' to 4220', and other scattered oil shows are minor. Sands are light to medium gray with various brownish hues. Above the show sand, sands are very fine to medium lower, and below fine to very fine. The show sand includes fine to coarse lower grains. Grains are dominantly clear to translucent, mostly quartz. Other grains include lithics, carbon lithics, silicates, and locally some scattered pyrite, scattered calcite, and some possible siderite. The show sand which peaked with 460 units of gas, had a faint petroleum odor, and exhibited a uniform bright orangish yellow fluorescence and bright yellowish white instantaneous cut fluorescence and weak straw cut. A trace of dark brown to black tarry oil was also observed. Clays were light to medium gray, with some brownish hues, typically shapeless and hydrated in samples, to occasionally firmer and exhibiting shaliness, especially in lower samples, and non to slightly calcareous. Textures were smooth to clayey to gritty. Traces to slight carbon matter and flakes were commonly noted, and up to 10% of the sample from 4750 to 4780, and of course abundant below 5500'. Some shell fragments and calcite are occasionally noted, and abundant calcite noted in the 4650-4680' sample. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3738 1069 146282 6077 6465 2999 3735 2092 2984 3784 456 71550 1555 1295 600 815 613 605 4207 460 68417 691 632 467 728 637 642 5839 155 21660 2065 1118 148 304 76 77 HRZ to K-1 Marker 6125' to 6460' MD (5595.51' to 5687.26' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 74 11 39 568 33 79 The HRZ includes carbonaceous shales and some interbedded sands and minor ash fall tuff. The shale is typical HRZ, variably organic claystone with slight to moderate and rare bookleaf partings of carbon matter or carbon residue, and traces of pyrite associated with the carbon matter. Some thin laminations of sandstone, siltstone, and ash, also with carbon partings, and some interbedded sandstone is also noted. Above the K-1 marker is some light tan to light brown calcareous mudstone, and common calcte fracture in the • shales. [~ EPt~~H 6 ConocoPhillips Alaska, Inc. 2z-o1a ~./ • Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 6354 568 80498 6096 2312 244 511 119 123 6399 207 31763 2106 843 101 234 71 78 6422 178 25123 1659 691 90 211 64 71 Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 80 18 38 1900 61 123 K-1 Marker (Kalubik Shale) to Kuparuk "C" 6460' to 6538' MD 5595.81' to 5754.24' TVDSS This is primarily a shale section with dark grayish brown to dark brownish gray to brown shales, carbonaceous in part, and some slightly to moderately calcareous grading to mudstone. Occasional interlaminated siltstone and sandstone, and traces of calcite fracture fill were noted. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 6469 290 38373 4000 2067 303 657 200 211 6487 1900 280616 20043 8613 1199 2768 924 784 6510 417 62910 4307 1600 208 422 138 144 Kuparuk "C" to Base Kuparuk "A" 6538' to 6750' MD 5754' to 5938' TVDSS Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 63 7 ZO 444 54 146 Kuparuk "C" (6535-6595') The Kuparuk "C" was light brownish gray to light olive gray with the brownish coloring due largely to oil staining, and the olive coloring due to glauconite and oil. The top of the sandstone was poorly to moderately consolidated, and matrbc and grain supported with a light gray firm to slightly brittle greasy clay matrix. Grains in the upper sandstone were fine to coarse with scattered pebbles, including mostly quartz, but abundant glauconite, especially at the top of the sand. The sample taken from 6510 to 6540' included consolidated matruc supported sandstone and loose grains, many frosted with clay, and a weak petroleum odor. Successive samples were dominantly quartz, with minor glauconite and other silicates and lithics. The sample taken from 6540' to 6570' included dominantly very fine upper to fine loose grains, some frosted, and had a fair petroleum odor. The sample from 6570 to 6600', began to include some very fine to fine grained moderately consolidated sandstone, and with a faint odor. Overall grains were rounded to subangular, moderately well to well sorted, and gradually fining downward. Estimated porosity and permeability varied from poor to good, increasing below the top of the sandstone with decreasing matroc, than overall gradually decreasing as fining downward. Fluorescence was a faint uniform dull orange with a light yellow instantaneous to diffuse cut. The Kuparuk section below the "C° Sand and above the "A" continues to fine downward and is dominantly shale, with some interbedded sitstone and very fine grained sandstone. Kuparuk "A" (6710-6750') The Kuparuk "A" was a moderate brown to brownish gray with brown coloring due in large part to oil staining. Grains were very fine to fine lower, dominantly very fine upper, subangular to subrounded, very ~1 EP~J~H 7 Conoco`Phillips Alaska, Inc. 2Z-01A . slightly to some moderately argillaceous with some brownish gray mottling, dominantly quartz and minor other silicates and lithics. Observed porosity and permeability was very poor to poor. Fluorescence was a very faint dull orange brown, with a moderate instantaneous to diffuse yellow cut, with a brown inner ring. The poor fluorescence and brown inner ring suggests a relatively low API, but not necessarily a viscous heavy oil. Peaks De h TG C1 C2 C3 C41 C4N C51 C5N 6584 444 56630 6478 3688 597 1369 440 486 6625 279 38953 4242 2671 488 1188 436 501 6710 203 32411 3406 1793 266 597 193 215 6730 221 31738 3334 1771 274 609 202 221 Base Kuparuk "A" to Total Depth 6750' to 6950' MD (5938.24' to 6115.59' TVDSS) Drill Rate ftlhr Total Gas units Maxmum Minimum Avera a Maximum Minimum Avera e 41 7 15 353 8 40 Two distinct shale lithologies are indicated by LWD data below the Kuparuk, from 6750-6822' with some sandstone at the base, and 6822' to total depth. The upper shales from 6750-6822' have distinctive brown hues, from moderate brown to light brown to dusky brown to light brownish gray, subplaty to splintery, with a smooth to silty to locally gritty texture. The lower shales to total depth are generally darker, from grayish brown to grayish black to brownish gray to dark gray, and with smooth to slightly gritty texture. Peaks De th TG C1 CZ C3 C41 C4N C51 C5N 6753 252 34292 3650 1994 316 729 249 281 6784 294 39694 4114 2214 338 765 252 279 6815 353 49354 4521 2472 390 923 318 374 • [~ EP~3CH $ CanocoPhillips Alaska. Inc. 2Z-01A 3.3 Connection Gases 1 unit = 0.05°~ Methane Equivalent De th Gas over BGG De th Gas over BGG feet units feet units 3783 48 5376 6 3876 43 5470 5 3970 100 5564 4 4063 25 5657 0 4156 25 5751 0 4250 25 5844 0 4344 12 5938 0 4438 10 6031 0 4531 15 6125 509 4626 5 6220 304 4719 46 6406 1160 4813 53 6500 1330 4907 62 6593 1144 5000 11 6687 750 5094 26 6781 270 5188 17 6875 138 5282 3 3.4 Trip IWiaeri Gases 1 unit = 0.05% Methane Equivalent De th Tri to Gas Downtime feet feet units hours 3763 0 196 12 hrs 6313 4910 740 2 hrs 6950 5565 1476 2 hrs [~ EPOCH ConocoPhillips Alaska, Inc. 2Z-01A • r 3.5 Sampling Program /Sample Dispatch Set T e / Pu ose Fre uenc Interval Dis tched to CPAI Washed screened & dried 30' y,,;~, ~eobg. ny A Reference Samples 3720' - 6950' 619 East Ship Creek Ave Ste 14 Set Owner CPAI Anchorage, AK 99501 Attn: D. P Id 265-6340 CPAI Washed, screened & dried 30 Bayview Geologic Faci{ity B Reference Samples 3720' - 6950 619 East Ship Creek Ave Ste 14 Set owner: CPAI Anchorage, AK 99501 Attn: D. P "265-6:140 Sample frequency was locally altered according to drill rate constraints and zones of interest. ~ EPOCH 10 Cond~hillips A9aska, inc. 2Z-01 A 4 PRESSURE /FORMATION STRENGTH DATA s Connection gas occurred through most of the drilling, but peaks were consistently sharp and dropped off quickly, indicating pore pressure remained below mud weight throughout. Connection gas was encountered from the start of the well while drilling with a 9.7 ppg mud, but eventually dropped out as mud weight was increased to 10.4 ppg at 5657'. Therefore, pore pressure is estimated to have varied from 9.4 to 10.0 from casing point to the HRZ, remaining just below the mud weight until mud weight reached 10.4. High connection gas with an 11.0 ppg mud at the top of the HRZ indicates a sharp pressure increase, and continued high connection and trip gases to total depth indicate pore pressure probably remained just under mud weight, which varied from 11 to 11.3+, and pore pressure perhaps 10.7 to 11.1 ppg. 4.1 Pore pressure evaluation Primary Secondary Interval To s Pore Pressure EMW T d Formation Interval Lithology ~%~ Lithology %~ MD ft TVD ft Min Max Trend ren Indicators Kick off Point CI st/Sh 60% Sltst/Sst 40% 3710 3290 9.4 10.0 Sli U BG,CG HRZ Sh 70% Sst 10% 6125 5496 10.7 10.8 U BG,CG,TG Ku aruk C Sh 60% Sst 30% 6535 5853 10.8 11.1 Flat BG,CG, TG Total De th 6950 6216 11.1 11.1 Flat NOTE: Clyst = Claystone/Clay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Sst =Sandstone, Ash =Ash Fall Tuff ~~~~H 11 Conoco`Phillips Alaska,inc. u-o1a DRILLING DATA • • 5.1 Survey Data Measured Depth ft Ino I' () Azorr>t' () True Vertical De th ft Latitude (ft) N+,S- Departure (ft) E+,W- Vertical Section ft Dogleg Rate °/10Qft 3710.00 37.86 192.80 3290.27 -1319.27 -242.07 1340.78 0.33 3747.38 37.23 191.50 3319.91 -1341.54 -246.87 1363.52 2.71 3841.17 33.72 187.89 3396.28 -1395.15 -256.10 1417.92 4.36 3934.48 31.34 183.76 3474.96 -1445.03 -261.25 146$.00 3.49 4028.50 29.38 178.94 3556.09 -1492.50 -262.43 1515.09 3.32 4122.59 26.94 177.00 3639.04 -1536.87 -260.88 1558.70 2.77 4215.80 26.28 173.02 3722.39 -1578.44 -257.27 1599.22 2.04 4309.57 23.31 168.73 3807.51 -1617.25 -251.12 1636.63 3.70 4403.31 22.18 167.46 3893.96 -1652.72 -243.65 1670.54 1.31 4497.26 20.53 156.57 3981.49 -1685.16 -233.25 1701.00 4.56 4589.01 19.91 151.18 4067.59 -1713.61 -219.32 1726.98 2.14 4684.90 19.95 145.08 4157.75 -1741.33 -202.08 1751.74 2.17 4778.64 19.01 141.49 4246.13 -1766.39 -183.42 1773.64 1.62 4872.77 18.93 139.93 4335.14 -1790.07 -164.04 1794.08 0.55 4966.38 18.71 139.83 4423.75 -1813.17 -144.59 1813.92 0.24 5059.82 18.94 142.74 4512.19 -1836.69 -125.74 1834.28 1.03 5153.00 18.73 144.39 4600.38 -1860.89 -107.87 1855.45 0.61 5248.34 19.78 143.52 4690.39 -1886.30 -89.37 1$77.74 1.14 5341.28 19.82 145.68 4777.84 -1911.96 -71.13 1900.30 0.79 5436.33 21.27 150.33 4866.84 -1940.25 -53.51 1925.56 2.30 5530.98 22.09 152.35 4954.80 -1970.94 -36.75 1953.31 1.17 5623.77 22.62 152.43 5040.62 -2002.21 -20.40 1981.71 0.57 5718.07 22.46 152.93 5127.71 -2034.33 -3.81 2010.91 0.26 5810.50 23.42 156.52 5212.84 -2066.90 11.55 2040.74 1.84 5903.71 25.86 163.12 5297.57 -2103.35 24.84 2074.73 3.94 5997.00 26.22 167.28 5381.40 -2142.93 35.28 2112.24 1.99 6090.12 26.61 170.55 5464.80 -2183.57 43.24 2151.18 1.62 6184.99 28.14 169.38 5549.04 -2226.52 50.85 2192.46 1.71 6276.89 28.64 168.04 5629.89 -2269.36 59.41 2233.49 0.88 6373.37 31.24 164.85 5713.49 -2316.14 70.74 2277.98 3.16 6465.42 30.98 168.74 5792.31 -2362.42 81.60 2322.05 2.20 6560.50 29.97 169.74 5874.26 -2409.79 90.61 2367.48 1.19 6652.15 30.11 167.87 5953.60 -2454.80 99.52 2410.59 1.03 6744.22 29.44 167.75 6033.51 -2499.49 109.17 2453.27 0.73 6840.14 26.28 164.84 6118.31 -2543.03 119.73 2494.69 3.59 6913.00 27.87 163.53 6183.18 -2574.93 128.78 2524.83 2.33 PROJ ECTED SURV EY TO TOTAL DEPTH 6950.00 27.87 163.53 6215.89 -2591.52 133.68 2540.47 0.00 [~ EPOCH 12 • 5.2 Bit Record Cona~illips f Alaska, Inc. 2Z-01A Bit Size Make Type / S# Jets / TFA Depth In Total Bit ROP WOB RPM PP Wear BHA MD / Footage Hrs ft/hr (Klbs) (psi) 1 „ „ 6 x l Reed, CSDX213S-A/ 5X10 3763 3187 79.74 40 2 - 30 60 1 8-6-RO-A-X- 2 Gent er Hycalog 3317682 3500 1 /8-BU-TD ~ EPQ~H 13 • 5.3 Mud Record Contractor: MI SWACO Mud Type: LSND Cono~hillips Alaska, Inc. 2Z-01 A Date Depth MW ECD VIS s/ t PV YP Gels FL cc FC Sols % O/W Ratio Sd % pH CI ml/I Ca ml/I 9/19107 3727 9.6 9.6 47 13 15 2/3/4 5.7 2 5.5 /95 .125 10.3 900 80 9/20/07 3810 9.6 10.94 45 13 14 3/4/4 5.7 2 5.5 /95 .125 10.1 1100 120 9/20/07 4430 9.8 10.94 46 17 18 4/6/ 5.2 2 5.5 /95 .125 10.5 950 40 9/21 /07 4920 10.1 11.05 48 18 16 4/6/8 4.4 2 10 1 /90 .125 10.0 1000 60 9/21 /07 5081 10.1 11.05 49 20 16 4/7/10 4.6 2 9 /91 .125 10.3 1000 140 9/22/07 5909 10.6 12.18 47 19 16 4/5/6 4.8 2 10.5 1 /89 .125 9.4 850 160 9/22/07 6313 11.3 12.18 46 20 17 5/6/8 3.6 2 16 /84 .125 10.0 800 120 9/23/07 6618 11.3 11.98 46 20 15 4/5/6 3.4 2 14.5 1 /85 .125 9.7 700 260 9/23/07 6775 11.3 11.98 45 18 13 3/4/5 3.5 2 16 /84 .125 9.5 600 200 9/24/07 6913 11.3 42 14 15 36/4/5 3.4 2 15 1 /85 .125 9.8 650 80 9/24/07 6950 11.3 43 15 15 3/4/5 3.6 2 15 1 /85 .125 9.8 650 80 9/25/06 6950 11.3 49 17 18 5/8/11 3.2 2 15.5 /85 .25 9.8 600 60 Abbreviations MW =Mud Weight WL = Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength Sd =Sand content ECD =Effective Circulating Density CI =Chlorides VIS =Funnel Viscosity FC =Filter Cake PV =Plastic Viscosity Sols =Solids O/VV =Oil to Water ratio ~P~~H 14 • • Daily Report Page 1 of 1 CPAI DAILY WELLSITE REPORT ~~~~~ 2Z 01A REPORT FOR DATE Sep 17, 2007 DEPTH 0 ' PRESENT OPERATION Nipple Up TIME 23:59 ,YESTERDAY-0 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT ..FOOTAGE. HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE. CURRENT AVG RATE OF PENETRATION @ @ SURFACE TORQUE @ @ FT/HR WEIGHT ON BIT @ @ AMPS ROTARY RPM @ @ KLBS PUMP PRESSURE @ @ RPM PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) -.HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ PROPANE (C-3) @ @ AVG CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Finish Rip Up Epoch Unit. Wait on Phone Llne. Phone Line installed, and Totco Witts feed setup Rig SUMMARY nippling up and testing BOP. . EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2770 REPORT BY Brian O'Fallon file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\Morning Repor... 9/19/2007 • • Daily Report Page 1 of 1 CPAI Kuparuk DAILY WELLSITE REPORT ~ ~,~~~~ 2Z_01A REPORT FOR Dearl Gladden, Pete Wilson DATE Sep 18, 2007 DEPTH 3727 PRESENT OPERATION Finish Testing CIBP and Casing TIME 23:59 YESTERDAY 3727 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 6600' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6 1/8" LS, 6.151" US MILL DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6600 MW 8.6 VIS 27 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 28u@6284' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ , HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Pulled test plug, retrieved and L/D storm packer, and L/D 3 1/2" tubing. M/U and RIH with scraper assembly to SUMMARY 6284', picking up drill pipe. Circulate 2 bottoms up, max 28 units of gas, and POOH. RIH with wireline and set CIBP at 3727'. POOH and test CIBP and casing to 3000 psi. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $3020 REPORT BY Brian O'Fallon • file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20070918.htm 9/19/2007 • Daily Report Page 1 of 1 CPAI Kuparuk DAILY WELLSITE REPORT ~,~{~~~ 2Z_01A REPORT FOR Dearl Gladden, Pete Wilson DATE Sep 19, 2007 DEPTH 3763.00000 PRESENT OPERATION POOH w/Mill Assembly TIME 23:59 YESTERDAY 3710.00000 24 HOUR FOOTAGE 53 CASING INFORMATION 7" @ 3719' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3691.8' (tie in) 37.92 192.8 3275.9' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/BIC PULLED 1 6.125" LS, 6.151" US MILL 3710 3763 53 7.8 BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 75.6 @ 3750.00000 0.7 @ 3714.00000 12.0 8.96138 FT/HR SURFACE TORQUE 1 @ 3725.00000 0 @ 3727.00000 0.6 0.44711 AMPS WEIGHT ON BIT 5 @ 3737.00000 0 @ 3739.00000 1.6 3.14029 KLBS ROTARY RPM 91 @ 3761.00000 89 @ 3730.00000 76.4 90.48223 RPM PUMP PRESSURE 1517 @ 3719.00000 1334 @ 3733.00000 1208.2 1447.65601 PSI DRILLING MUD REPORT DEPTH 3727 MW 9.6 VIS 47 PV 13 YP 15 FL 5.7 Gels 2/3/4 CL- 900 FC 2l SOL 5.5 SD 0.125 OIL 0/95 MBL 5.0 pH 10.3 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1069 @ 3738.00000 0 @ 3710.00000 157.7 TRIP GAS CUTTING GAS 0 @ 3762.00000 0 @ 3762.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 146282 @ 3738.00000 32 @ 3711.00000 20716.9 CONNECTION GAS HIGH ETHANE (C-2) 6077 @ 3738.00000 10 @ 3711.00000 759.1 AVG PROPANE (C-3) 6465 @ 3738.00000 8 @ 3711.00000 796.1 CURRENT BUTANE (C-4) 6734 @ .3738.00000 6 @ 3711.00000 856.2 CURRENT BACKGROUND/AVG 103/158 PENTANE (C-5) 5255 @ 3742.00000 0 @ 3712.00000 677.3 HYDROCARBON SHOWS None INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY 50% Sand, 30% Siltstone, 20% Claystone and Shale PRESENT LITHOLOGY 50% Sand, 30% Siltstone, 20% Claystone and Shale DC and make up 7" whipstock assembly. Trip in hole to 3710' and mill to 3763'. Pump high DAILY ACTIVITY Pick up HWDP and SUMMARY vis s . weep, and rig up and perform FIT to 14.3 EMW. Begin POOH with mill assembly. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $3020 REPORT BY Brian O'Fallon C, file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20070919.htm 9/20/2007 Daily Report ~~ LJ • Page 1 of 1 CPAI Kuparuk DAILY WELLSITE REPORT ~~~~~ 2Z_01A REPORT FOR Dearl Glad den, Pete Wilson DATE Sep 20, 2007 DEPTH 4439.00000 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 3763.00000 24 HOUR FOOTAGE 676 CASING INFORMATION 7" @ 3719' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3841.17 33.72 187.89 3396.28 4028.50 29.38 179.03 3556.09 SURVEY DATA 4215.80 26.28 173.13 3722.39 4309.57 23.31 168.85 3807.51 4403.31 22.18 167.57 3893.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6" (7" bi-center) HYC CSDX213S-A 3317682 5X10 3763 676 7.93 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 225.1 @ 3786.00000 6.3 @ 3763.00000 106.6 86.51766 FT/HR SURFACE TORQUE 190 @ 4026.00000 0 @ 3994.00000 7.4 1.13936 AMPS WEIGHT ON BIT 16 @ 4253.00000 -3 @ 4356.00000 4.8 7.54073 KLBS ROTARY RPM 75 @ 4123.00000 4 @ 4067.00000 47.6 60.04810 RPM PUMP PRESSURE 3004 @ 4369.00000 10 @ 4389.00000 2223.3 2566.02588 PSI DRILLING MUD REPORT DEPTH 4430 MW 9.8 VIS 46 PV 17 YP 18 FL 5.2 Gels 4/6/ CL- 950 FC 2/ SOL 5.5 SD 0.125 OIL 0/95 MBL 9.0 pH 10.5 Ca+ 40 CCI MWD SUMMARY INTERVAL 3763 TO Present TOOLS Bit #1 and Mud Motor, MWD (Surveys), and LWD (Gamma, Resistivity, Neutron, Density, ECD, Caliper) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 460 @ 4207.00000 30 @ 4428.00000 122.2 TRIP GAS 196u CUTTING GAS 0 @ 4439.00000 0 @ 4439.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 71550 @ 3784.00000 5038 @ 4428.00000 18742.6 CONNECTION GAS HIGH ETHANE (C-2) 1555 @ 3784.00000 65 @ 4344.00000 322.3 AVG 0 PROPANE (C-3) 1295 @ 3784.00000 30 @ 4428.00000 272.5 CURRENT BUTANE (C-4) 1416 @ 3784.00000 66 @ 4428.00000 371.6 CURRENT BACKGROUND/AVG 44u/90u PENTANE (C-5) 1279 @ 4207.00000 127 @ 4428.00000 360.9 HYDROCARBON SHOWS Sand: 4195-4220',460u, spotty oil (see log) INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 40% Sand and Sandstone, 25% Siltstone, 30%Claystone, 5% Shale PRESENT LITHOLOGY 40% Sand and Sandstone, 20% Siltstone, 20% Claystone, 20% Shale DAILY ACTIVITY POOH with Mill Assembly, mill bit in guage. Make up directional assembly with Mud Motor, new bit no. 1, LWD SUMMARY and MWD. RIH and drill, rotating and some sliding, from 3763 to 4439', dropping angle. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3020 REPORT BY Brian O'Fallon file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\C... 9/21/2007 Daily Report • • Page 1 of 1 CPAI ruk K DAILY WELLSITE REPORT ~~~~~ upa 2Z_01A REPORT FOR Dearl Gladden, Pete Wilson DATE Sep 21, 2007 DEPTH 5478.00000 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 4439.00000 24 HOUR FOOTAGE 1039 CASING INFORMATION 7" @ 3710' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4589.01 19.91 151.18 4067.59 4872.77 18.93 139.93 4335.14 SURVEY DATA 5059.82 18.94 142.74 4512.19 5248.34 19.78 143.52 4690.39 5436.33 21.27 150.33 4866.84 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6"(7" bi-center) HYC CSDX213S-A 3317682 5X10 3763 1715 26.09 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 135.2 @ 4745.00000 11.9 @ 5191.00000 66.3 14.20376 FT/HR SURFACE TORQUE 2 @ 4765.00000 0 @ 5056.00000 1.2 1.45755 AMPS WEIGHT ON BIT 25 @ 5477.00000 -1 @ 4874.00000 7.0 16.15838 KLBS ROTARY RPM 63 @ 5233.00000 0 @ 5393.00000 53.1 61.12480 RPM PUMP PRESSURE 3218 @ 5424.00000 1778 @ 4636.00000 2762.2 3172.45605 PSI DRILLING MUD REPORT DEPTH 4920 MW 10.1 VIS 48 PV 18 YP 16 FL 4.4 Gels 4/6/8 CL- 1000 FC 2/ SOL 10.0 SD 0.125 OIL .1/90 MBL 13.0 pH 10.0 Ca+ 60 CCI MWD SUMMARY INTERVAL 3763 TO Present TOOLS Bit#1 a nd Mud Motor, MWD (Surveys), and LWD (Gamma, Resistivity, Neutron, Density, ECD, Caliper) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 84 @ 4722.00000 9 @ 5388.00000 32.0 TRIP GAS CUTTING GAS 0 @ 5478.00000 0 @ 5478.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10678 @ 4722.00000 1503 @ 5388.00000 4711.3 CONNECTION GAS HIGH 62u ETHANE (C-2) 379 @ 4773.00000 52 @ 4457.00000 186.0 AVG 20u PROPANE (C-3) 165 @ 5436.00000 15 @ 4528.00000 71.7 CURRENT 5u BUTANE (C-4) 97 @ 5237.00000 11 @ 5388.00000 45.6 CURRENT BACKGROUND/AVG 20u/30u PENTANE (C-5) 183 @ 4439.00000 9 @ 5388.00000 54.6 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 40% Sandstone and Sand, 20% Siltstone, 30% Claystone, 10% Shale PRESENT LITHOLOGY 40% Sandstone and Sand, 30% Siltstone, 10%Claystone, 20% Shale DAILY ACTIVITY Drill from 4439' to 5478', rotating and some sliding, dropping angle to approximately 19 degrees, maintaining SUMMARY tangent, and begin building angle. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3020 REPORT BY Brian O'Fallon file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20070922.htm 9/22/2007 Daily Report • • Page 1 of 1 CPAI Kuparuk DAILY WELLSITE REPORT ~+~~~~ 2Z_01A REPORT FOR Dearl Gladden, Pete Wilson DATE Sep 22, 2007 DEPTH 6313.00000 PRESENT OPERATION Wiper Trip TIME 23:59 YESTERDAY 5478.00000 24 HOUR FOOTAGE 835 CASING INFORMATION 7" @ 3710' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5530.98 22.09 152.35 4954.80 SURVEY DATA 5718.07 22.46 152.93 5127.71 5903.71 25.86 163.12 5297.57 6090.12 26.61 170.55 5464.80 6276.89 28.64 168.04 5629.89 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T1B/C PULLED 1 6"(7" bi-center HYC CSDX213S-A 3317682 5X10 3763 2550 45.95 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 104.5 @ 5913.00000 6.6 @ 6247.00000 50.8 59.75500 FT/HR SURFACE TORQUE 6 @ 6279.00000 0 @ 6137.00000 4.2 5.65449 AMPS WEIGHT ON BIT 26 @ 6245.00000 -2 @ 6062.00000 7.3 10.36130 KLBS ROTARY RPM 64 @ 5611.00000 6 @ 5659.00000 51.2 62.42153 RPM PUMP PRESSURE 3654 @ 6214.00000 2255 @ 5940.00000 3120.7 3296.55908 PSI DRILLING MUD REPORT DEPTH 6313 MW 11.3 VIS 46 PV 20 YP 17 FL 3.6 Gels 5/6/8 CL- 800 FC 2/ SOL 16 SD 0.125 OIL 0/84 MBL 22.5 pH 10.0 Ca+ 120 CCI MWD SUMMARY INTERVAL 3763 TO Present TOOLS Bit #1 and Mud Motor, MWD (Surveys), and LWD (Gamma, Resistivity, Neutron, Density, ECD, Caliper) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 182 @ 6187.00000 8 @ 5566.00000 59.4 TRIP GAS CUTTING GAS 0 @ 6311.00000 0 @ 6311.00000 0.0 WIPER GAS 740u @ 6313' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 27492 @ 6187.00000 1413 @ 5566.00000 8783.7 CONNECTION GAS HIGH 509u ETHANE (C-2) 2404 @ 6187.00000 94 @ 5479.00000 778.7 AVG 150u PROPANE (C-3) 1251 @ 5752.00000 48 @ 5479.00000 356.9 CURRENT 304u BUTANE (C-4) 471 @ 5752.00000 21 @ 5566.00000 139.6 CURRENT BACKGROUND/AVG 30u/50u PENTANE (C-5) 167 @ 5752.00000 11 @ 5566.00000 54.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 20% Sand, 60% Shale and Carbonaceous Shale, 15%Siltstone, 5% Ash Fall Tuff PRESENT LITHOLOGY 50% Sand, 40% Shale and Carbonaceous Shale, 10% Siltstone DAILY ACTIVITY Drill from 5478 to 6313', rotating and some sliding, builiding angle to begin tangent. Begin 15 stand SUMMARY wiper trip. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3020 . REPORT BY Brian O'Fallon file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\C... 9/23/2007 Daily Report r Page 1 of 1 CPAI Kuparuk DAILY WELLSITE REPORT T,~'~~~ 2Z 01A REPORT FOR Dearl Gladden, Pete Wilson DATE Sep 24, 2007 DEPTH 6773.00000 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 6313.00000 24 HOUR FOOTAGE 460 CASING INFORMATION 7" @3710' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6373.37 31.24 164.85 5713.49 SURVEY DATA 6465.42 30.98 168.74 5792.31 6560.50 29.97 .169.74 5874.26 6652.15 30.11 167.87 5953.60 6744.22 29.44 167.75 6033.51 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6" (7' bi-center) HYC CSDX213S-A 3317682 5X10 3763 3010 64.43 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 86.2 @ 6461,00000 3.8 @ 6714.00000 33.9 24.16643 FT/HR SURFACE TORQUE 7 @ 6543,00000 0 @ 6600.00000 4.9 4.85636 AMPS WEIGHT ON BIT 41 @ 6597.00000 -8 @ 6602.00000 14.2 15.52250 KLBS ROTARY RPM 63 @ 6677.00000 19 @ 6595.00000 52.6 58.15182 RPM PUMP PRESSURE 3604 @ 6459.00000 2781 @ 6407.00000 3195.9 3095.68091 PSI DRILLING MUD REPORT DEPTH 6618 MW 11.3 VIS 46 PV 20 YP 15 FL 3.4 Gels 4/5/6 CL- 700 FC 2/ SOL 14.5 SD 0.125 OIL 1/85 MBL 25 pH 9.7 Ca+ 260 CCI MWD SUMMARY INTERVAL 3763 TO Present TOOLS Bit #1 and Mud Motor, MWD (Surveys), and LWD (Gamma, Resistivity, Neutron, Density, ECD, Caliper) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1899 @ 6487.00000 32 @ 6326.00000 142.8 TRIP GAS CUTTING GAS 0 @ 6773.00000 0 @ 6773.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 280616 @ 6487.00000 4656 @ 6326.00000 19834.8 CONNECTION GAS HIGH 1330 ETHANE (C-2) 20043 @ 6487.00000 301 @ 6326.00000 1797.2 AVG 600u PROPANE (C-3) 8613 @ 6487.00000 95 @ 6504.00000 920.7 CURRENT 270u BUTANE (C-4) 3966 @ 6487.00000 43 @ 6326.00000 479.9 CURRENT BACKGROUND/AVG 150u/90u PENTANE (C-5) 1708 @ 6487.00000 19 @ 6326.00000 230.0 HYDROCARBON SHOWS Kuparuk "C": 6540-6600', 444u, oil cut. Kuparuk "A" 6710-6750': 224u, oil cut. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 60% Shale and Carbonaceous Shale, 10%Siltstone, 20% Sandstone PRESENT LITHOLOGY 50% Shale and Carbonaceous Shale, 20% Siltstone, 30% Sandstone DAILY ACTIVITY Complete 15 stand wiper trip, trip gas 740 units. Drill from 6313' to 6773', rotating and minor sliding, SUMMARY maintaining tangent at approximately 30 degrees. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3020 REPORT BY Brian O'Fallon file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLSIC,.. 9/24/2007 • Daily Report Page 1 of I CPAI Kuparuk DAILY WELLSITE REPORT ~+~+~~~ 2Z_01A REPORT FOR Dearl Gladden, Pete Wilson DATE Sep 24, 2007 DEPTH 6950.00000 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 6773.00000 24 HOUR FOOTAGE 177 CASING INFORMATION 7" @3710' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6840.14 26.28 164.84 6118.31 6913.00 27.87 163.53 6183.18 6950.00 27.87 163.53 6215.89 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6" (7" bi-center) HYC CSDX213S-A 3317682 5X10 3763 6950 3187 79.73 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 43.7 @ 6782.00000 5.8 @ 6864.00000 14.0 9.21900 FT/HR SURFACE TORQUE 6 @ 6803.00000 4 @ 6824.00000 5.6 5.91100 AMPS WEIGHT ON BIT 31 @ 6891.00000 -7 @ 6781.00000 12.2 11.69600 KLBS ROTARY RPM 71 @ 6885.00000 39 @ 6860.00000 61.0 56.74100 RPM PUMP PRESSURE 3607 @ 6847.00000 2878 @ 6888.00000 3376.9 3194.69600 PSI DRILLING MUD REPORT DEPTH 6950 MW 11.3 VIS 43 PV 15 YP 15 FL 3.6 Gels 3/4/5 CL- 650 FC 2/ SOL 15 SD 0.125 OIL 1/85 MBL 27.5 pH 9.8 Ca+ 80 CCI MWD SUMMARY INTERVAL 3763 TO 6950 TOOLS Bit #1 and Mud Motor, MWD (Surveys), and LWD (Gamma, Resistivity, Neutron, Density, ECD, Caliper.) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 356 @ 6813.00000 8 @ 6948.00000 82.3 TRIP GAS CUTTING GAS 0 @ 6950.00000 0 @ 6950.00000 0.0 WIPER GAS 1476 CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 49354 @ 6813.00000 1378 @ 6948.00000 .11389.3 CONNECTION GAS HIGH 270 ETHANE (C-2) 4521 @ 6813.00000 86 @ 6948.00000 1049.3 AVG 204 PROPANE (C-3) 2504 @ 6815.00000 37 @ 6948.00000 559.8 CURRENT 138 BUTANE (C-4) 1369 @ 6815.00000 19 @ 6948.00000 291.4 C URRENT BACKGROUND/AVG 12u/50u PENTANE (C-5) 739 @ 6815.00000 12 @ 6948.00000 153.4 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70 % Shale, 10% Sandstone, 20% Siltstone. PRESENT LITHOLOGY 80% Shale, 10% Sandstone, 10% Siltstone. DAILY ACTIVITY Drilled, rotating, from 6773' to 6950' (total depth). Wiper trip 12 stands, pump sweep and circulate trip gas SUMMARY 1476u. POOH. , EPOCH PERSONNEL ON BOARD 4 DAILY COST $3020 REPORT BY Brian O'Fallon file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\C... 9/25/2007 • C] • Daily Report Page 1 of 1 CPAI Kuparuk DAILY WELLSITE REPORT ~+~~~~ 2Z_01A REPORT FOR Dearl Gladden DATE Sep 25, 2007 DEPTH 6950.00000 PRESENT OPERATION Waiting on Packer TIME 23:59 YESTERDAY 6950.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3710' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TY " PE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6 (7" bi-center) HYC CSDX213S-A 3317682 5X10 3763 6950 3187 79.73 8-6-RO-A-X-1/8-BU TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ SURFACETOROUE @ @ FT/HR WEIGHT ON BIT @ @ AMPS ROTARY RPM @ @ KLBS PUMP PRESSURE @ @ RPM PSI DRILLING MUD REPORT DEPTH 6950 MW 11.3 VIS 49 PV 17 YP 18 FL 3.2 Gels 5/8/11 CL- 600 FC 2/ SOL 15.5 SD 0.25 OIL 1/84 MBL 27.5 pH 9.8 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ CUTTING GAS @ @ TRIP GAS 726u WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ PROPANE (C-3) @ @ AVG BUTANE (C-4} @ @ CURRENT CURRENT BACKGROUND/AVG NA/5u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY UD BHA, M/U and RIH with clean out assembly. Pump Hi-Vis sweep, 726 units of trip gas. POOH and L/D clean SUMMARY out assembly. R/U anf RIH with 5.5" liner. Test floats. M/U hanger packer. Packer damaged and UD packer Slip d an cut drilling line. Wait on new Packer. . EPOCH PERSONNEL ON BOARD 4 DAILY COST $3020 REPORT BY Brian O'Fallon file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\C... 9/26/2007