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Home My WebLink About205-034 • • pTP 205 0 3 Lf Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, August 05, 2016 2:42 PM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: Report of sustained casing pressure KRU producer 1C-21 (PTD 205-034) 8-5-16 Attachments: 1C-21 90 day 110 8-5-16.PNG; 1C-21 schematic.pdf Follow Up Flag: Follow up Flag Status: Completed Victoria, KRU producer 1C-21 (PTD 205-034) is experiencing sustained casing pressure of the inner annulus above 2000psi and is being reported per CO 494, Rule 3. It was identified with 2127psi yesterday during the drillsite operator's daily wellwalk. The pressure is beginning to stabilize out but is continuing to slowly rise and is now up to 2138psi. 1C-21 is currently shut in. Well intervention with Slickline will be scheduled as soon as possible to address the TxIA communication. The 7-5/8" 29.7# L-80 production casing has a yield pressure rating of 6890psi (2138psi represents 31%of the burst rating). Attached are the 90 day TIO plot and schematic. • Please let me know if you have any questions. Kelly Lyons/Brent Rogers SCANNED JAN 1 8201z Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907) 943-0170 1 l& 41111111111=11111MMIlll CD © o i=r a III to sr c.1 C',4 •- 43o D a r• r- !r em• A tom' CI% f.3 r-- (..o in LO T 1 I I i in :i co 6 I 'r' itillikt. r. � 0 4c, .--" Lik <1.; IV CO 4 . - IMMO GO -i ) (930 .,�. LG E I. L i- s Ca - C tri Ci. Cr, ,k- ) r r A LIS) I I I I :r, LJ CI LJ < ." .. :i H 300 Cr Cr Cr f) o 'i) L kr) 1.:17.7 l 1.7.4C4 CA iSd KUP w 1C-21 ConocoPhillips a Weil Attributes MaxAngle&MD TD Wellbore APAWI Field Name Wed Stabs Ind(1 MD(MB) Act Btm(MUD ComacgVMps 500292325300 KUPARUK RIVER UNIT PROD 97.69 11,856.33 15,634.0 ... ."„ Comesrd HES(ppm) Date Annotation End Dab KBDate -0rd(11) Rig Release Wet Coni -1C-21 521/20122'53x15 PM SSSV:NIPPLE 45 9/25/2011 Last WO: 46.81 6/22/2005 Sd,n/abc-Actual Annotation Depth(NCB) End Dote Annotation Lae Mod...End Date Last Tag: Rev Reason:WELL REVIEW cotton 5/21/2012 Casing Strings HANGER,37 Casing Description String 0... String ID...Top(1(KB) Set Depth(f...Set Depth(TVD)-..String Wt...String...String Top Thad CONDUCTOR 16 15.062 40.0 115.0 115.0 62.50 H-40 WELDED 'sir Casing Description Stung 0... String ID.-Top(NCB) Set Depth(f...Sat Depth(TVD)-.String Wt..String-.String Tap Thrd SURFACE 103/4 9.794 39.3 5,680.5 4,504.6 45.50 L-80 BTC Casing Description Stung 0... Wag Si-,Top(111(B) Set Depth(L,.Set Depth(TVD)-.String M...Stung-.String Top Thrd la PRODUCTION 75/8 6.875 39.3 9,153.7 6,542.1 29.70 L-80 BTC Casing Description...._-String 0... Stung N...Top(NCB) Set Depth IL Sot Depth(TVD)...String Wt...String...String Top Thad LINER 412 3.958 8,983.0 15,624.0 6,528.4 12.60 L-80 IBT__ , Liner Details e0.115 Top DDpth (1VD) Top iron NIPPLE,492 Ill. Top(NCB) (KKB) (1 Item Description Comment ID(In) 8,983.0 6,513.0 77.18 SLEEVE TIEBACK SLEEVE 3.958 ' 8,994.1 6,515.8 77.60 PACKER BAKER ZXP LINER TOP PACKER w/HRD RUNNING PROFILE 4.970 GAS UFT, 2347 a 9,002.1 6,517.8 77.91 NIPPLE BAKER RS NIPPLE 4.875 1 9,004.9 6,518.5 78.02 HANGER BAKER FLEXLOCK HANGER 4.853 9,014.7 6,520.7 78.39 SBR BAKER 19047 SEAL BORE RECEPTICLE 4.750 or GAS UFT, 11,203.8 6,569.8 86.47 Swell Packer EASY WELLS SOLUTIONS SWELL PACKER 3.960 II 11,7952 6,576.9 99.63 Swell Packer EASY WELLS SOLUTIONS SWELL PACKER 3.960 14,011.4 6,577.9 94.75 Swell Packer EASY WELLS SOLUTIONS SWELL PACKER 3.960 14,545.71 6,559.9 92.81 Swell Packer EASY WELLS SOLUTIONS SWELL PACKER 3.960 Tubing Strings SURFACE, eli dk. ...Tubing Description String 0... String ID Top P(NCB 1 Set Depth(f...SetDepth(TVD)...String Wt...String...String Top Turd TUBING 412 3.958 36.9 9,032.1 6,524.4 12.60 L-80 IBT B' Completion Details GAS LIFT, ,989 IL' Top Depth (Tw) Top int Ranh- - (1 Top(MB) 0) I') Item Description Comment ID(In) 36.9 36.9 0.18 HANGER FMC GEN V TUBING HANGER 4.500 GAS LIFT, 482.1 482.0 1.18 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 7038 8,518.1 6,341.6 61.90 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 8,993.1 6,515.6 77.57 LOCATOR BAKER LOCATOR SUB w/NO GO RING 3.875 9,016.1 6,521.0 78.45 SEAL ASSY BAKER SEAL ASSEMBLY wI 16'EFFECTIVE SEALS 3.875 OAS LIFT,_ - 7830 Perforations&Slots L.- Shot y Top(TVD) Bhn(IVO) Dens Top(NCB)Bbn(NCB) (NCS) (M8) Zone Dab (111-• Type comment ---- GAS4 9,070.0 15,591.0 6,531.1 6,530.0 UNIT D,C-3, 6/19/2005 32.0 IPERF Alternating joints of slotted and solid e.47z - C-4,1C-21 liner MI Notes:General&Safety NIPPLE,8.518 End Date Annotation 6/22/2005 NOTE:NO LATERALS DRILLED;3 PLUGBACKS PERMITTED '.¢¢ 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR, :6 8,993 a Mt I 'I SEAL ASSY, 9,016 / 1 I I PRODUCTION. I I t 39-9,154 IPERF, Mandrel Details 9.070-15.591 Top Depth Top Port (TVD) eel OD Valve Latch Size TRO Runk Sin Top(MS) MSS) r) Make Model (b) Sam TyPe TIM. (in) (Psi) Run Date Com... 1 2,846.8 2,597.0 48.62 CAMCO KBG-2-1R 1 GAS LIFT GLV SBK... 0.156 1,265.0 6/25/2005 2 4,6432 3,810.8 48.13 CAMCO KBG-2-1R 1 GAS UFT GLV SBK... 0.188 1,295.0 6252005 3 5,989.1 4,704.1 50.09 CAMCO KBG2-iR 1 GAS LIFT GLV SBK... 0.188 1,290.0 6/25/2005 4 7,035.8 5,389.8 48.25 CAMCO KBG-2-1R 1 GAS UFT OV SBK... 0250 0.0 6/25/2005 1 GAS LIFT DMY SBK... 0.000 0.0 6/20/2005 5 7,830.4 5,927.8 52.56 CAMCO KBG-2-1R 6 8,472.5 8,319.9 80.88 CAMCO KBG-2-1R 1 GAS LIFT DMY SBK... 0.000 0.0 6/25/2005 1 UNER, 8,983-15,824 11 TO(IC-21),� 15,83{ · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a Q 5. - 03 Y- Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111/1111111111111I RESCAN ~olor Items: ~reYSCale Items: o Poor Quality Originals: DIGITAL DATA ~skettes, No. ~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: Y1'1f Dole 7. 'JZ, D7 ,~IIIIIIIIIIIIIIIII y1f tt X 30 = J ~ Ó + dLJ = TOTAL PAGES / l/-O (Count does not include cover sheet) 'M'f Date: 7, d3, 0 7 151 , r . 1111111111111111111 o Other:: NOTES: BY: ~ Date: 1 ~,07 t t 151 Project Proofing BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: 1 LJ- J (Count does include c~ sheet) Page Count Matches Number in Scanning pr¡:,aration: V YES BY ~ Dole 7/:13/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 mp NO BY: Maria Date: 151 111111/111/11111111 Scanning is complete at this point unless rescanning is required. ReScanned III 11111111111 1111I BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Jan 2, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~' Avenue, Suite 100 Anchorage, AK 99501 RECEIVED JAN 0 7 2009 Alaska Oil & Gas Cons. Commission Anchorage a~~-o~+~ 1 ~`~'~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Similarly, It was noticed In August 2007 that 5 wells on DS 1 C had similar cement and sealant treatments. These wells were inadvertently omitted from the 10-404 submitted at that time for other work being performed. These wells are included here. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Perry K1 ' - ConocoPhillips Well Integrity Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ....._. ..... . Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-09 183-104 11" na 11" na 1.70 12/7/2008 1 F-14 183-146 18" na 18" na 2.00 12/7/2008 1 F-17 196-047 8" na 8" na 1.70 12/7/2008 1 F-19 196-052 8" na 8" na 1.70 12/7/2008 1 F-20 196-053 6" na 6" na 1.00 12/7/2008 1C-111 201-128 5' 9" 0.50 18" 8/27/2007 21.00 8/29/2007 1 C-13 198-011 32' 10" 4.00 18" 8/27/2007 17.00 8/29/2007 1 C-14 206-001 14' 6" 2.00 18" 8/27/2007 9.00 8/29/2007 1 C-21 05-034 38' 10" 4.00 18" 8!27/2007 8.60 8!29/2007 1 C-23 199-034 10' 10" 1.50 18" $/27/2007 23.00 8/29/2007 ) ~ J\J1l DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050340 Well Name/No. KUPARUK RIV UNIT 1C-21 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23253-00-00 MD 15634/ TVD 6528, Completion Date 6/2212005 /' Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional su~ - DATA INFORMATION Types Electric or Other Logs Run: GRlRes, Dens/Neu Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Log Log Run Interval OH/ TYJe Med/Frmt Number Name Scale Media No Start Stop CH Received ¡tt6 - D Asc Directional Survey 12510 15634 Open 7/29/2005 ,¿ D Asc Directional Survey 12510 15634 Open 7/29/2005 ~D Lis 13288 I nd uction/Resistivity 5652 15574 Open 9/26/2005 ~ 13288 LIS Verification 5652 15574 Open 9/26/2005 Log Production 5 Slu 5902 13070 2/22/2006 - ~ C Lis 13694 Induction/Resistivity r C Las 14434 Induction/Resistivity Comments IIFR MWD GR EWR4 ASI CNP SLD ROP PWD GEOPLOT GR EWR4 ASI CNP SLD ROP PWD GEOPLOT PRODUCTION PROFILE SWS TRACTOR W/SPINfTEMP/PRESSIDE FT/GHOST 116 15634 Open 2/22/2006 ROP DGR EWR plus Graphics 5645 15634 Open 1/29/2007 LIS Veri, GR, FET, ROP, NCNT, NPHI, RHOS, J' DRHO w/Graphics . Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM"R'0N Well Cored? Y ~ Daily History Received? WN &N Chips Received? ~ Formation Tops Analysis Received? ~ Permit to Drill 2050340 MD 15634 TVD 6528 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Well Name/No. KUPARUK RIV UNIT 1C-21 Completion Date 6/22/2005 Operator CONOCOPHILLlPS ALASKA INC Completion Status 1-01L Current Status 1-01L do Date: API No. 50-029-23253-00-00 UIC N ) IJ~0 ~/ - e · ., '" WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21_L1_L2_L3, 1D-28_L1, 1F-01A, 3F-19A, 3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1B-15A: doi...l-dS-~ tt: lL-../~/:!D Digital Log Images: 1 CD Rom 50-029-23465-0~D~_034 ;;O'f)-IOO GJoS -JOI I [)O~--/Od 01 II 1C-21_L1_L2_L3: Jl./L/3I..J 14435"" /4'-/310 I,/L/~ Digital Log Images: 1 CD Rom 50-029-23253-00, 60, 61, 62 1D-28 L1: Digital Log Images: 50-029-23237-00, 60 Qó4-Q37 /¿../4;J'd goLf -.93'fr ¡l.../L!33 1 CD Rom 1F-01A: 90S- -Olf7 d ¡¿../Ll(7) Digital Log Images: 50-029-20889-01 3F-19A: {)O'-( -(){ r:o p-/ LIt.¡ 3/ Digital Log Images: 50-029-22680-01 1 CD Rom 1 CD Rom 3H-14B: ÐòG -06)1 :It ¡4¿¡Cf1 Digital Log Images: 50-103-20092-02 1 CD Rom ¡ I . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 ;;05-034- February 16, 2006 J 3bJq 4--- RE: MWD Formation Evaluation Logs 1C-21, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 lC-21: LAS Data & Digital Log Images: 50-029-23253-00 1 CD Rom ~41.0 ýI09")00 02/21/06 Schlumbepger NO. 3691 Schlumberger -DCS ¡, "~';¡ \1 ;¡ i j 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 FEB 22 2006 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 ~'"',. ",,,it.>. vUIìHIH:jS!O\, Anchorage, AK 99501 ?JlcOOtage Field: Kuparuk -- Well Job # Log Description Date BL Color CD -1B-17 ¡q4-045" 11216283 SBHP SURVEY 02/18/06 1 1 E-36 198-~13 11216282 SBHP SURVEY 02/18/06 1 3H-07 1~7-o7f1 11217023 LDL 02/11106 1 3H-07 " 1', 11166757 STATIC SURVEY 01/20/06 1 2A-09 18 fÍ;-rD J 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 IBI-/ÚJO 11213710 INJECTION PROFILE 02/08/06 1 2M-14 19ó{- 010:; 11154127 INJECTION PROFILE 02/10/06 1 1 E-05 ¡ Pfr D5R 11166747 PRODUCTION PROFILE WIDEFT 12/25/05 1 2H-12 IB5-:Jw'). 11154128 PRODUCTION PROFILE W/DEFT 02/11/06 1 1C-21 $5- oM- 11154131 PRODUCTION PROFILE WIDEFT/GHOST 02/14/06 1 3G-18 IQ()-¡';;5' 11154129 PRODUCTION PROFILE WIDEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 I B4 -;J'f{p 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 183- [h;1. 11213128 INJECTION PROFILE 02/06106 1 . 1E-105 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 IB3 -oqç 11141255 INJECTION PROFILE 01/28/06 1 2C-02 183-{)93 11213129 INJECTION PROFILE 02/07/06 1 1 C-25 I qq -031 11144074 GLS 02/02/06 1 2C-14 /84 - dID 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 /B-f-b)/t 11144067 PRODUCTION PROFILE 01/26/06 1 1A-18 fCJo- /53 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 leo!;- DB? 11213709 INJECTION PROFILE 02/07/06 1 10-32 t2OD-17-~ 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 /51-,X(o 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 184 - /)63 11141254 PRODUCTION PROFILE 01/27/06 1 1J-154 N/A PRODUCTION LOG WITRACTOR 02/05/06 1 1 E-1 04 11217024 INJECTION PROFILE 02/12/06 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 Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West ih Avenue, Suite 100 Anchorage, Alaska September 23,2005 RE: MWD Fonnation Evaluation Logs lC-21, AK-MW-3706651 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23253-00 ~ \> 1~'ß PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date) l ~~~, Signed: 1LJf)JlJ ~ () ~- -. D J v 1 . . KRU 1 C-21 - 205-034 Note to File This well and its lateral well branches have a complicated history. Drilling operations began May 14, 2005. A 13-112" hole was drilled to a depth of 5,690' measured depth ("MD") and 10- 3/4" casing was run to 5,680' MD. A 9-7/8" hole was drilled to a depth of 9,160' MD, and 7- 5/8" casing was run to 9,154' MD. A 6-3/4" hole was drilled, and a total depth of 10,336' MD was reached on May 31,2005. The operator pulled back up-hole, and made a course correction beginning at 10,060' MD that same day. Drilling continued to a total depth of 10,408' MD and on June 2nd, the operator made the decision to pull back up-hole again for a second openho1e sidetrack. On June 2nd, drilling began again at 9,600' MD, and continued to a total depth of 12,933' MD on June 6th. The operator again elected to pull back up-hole and begin a third openhole sidetrack. On June 6, drilling began again at 12,560' MD, and continued until the total depth of the well (15,634' MD) was reached on June 15,2005. Slotted liner measuring 4-112" in diameter was then run from 8,993' MD to 15,624' MD. KRU 1C-21 and the associated laterals were equipped and conditioned to produce on June 22, 2005, which is the assigned completion date. Because none of the openhole sidetracks were plugged back, and they all traverse oil-bearing reservoir rock, they are expected to contribute to production from the well. For proper record- keeping purposes, each lateral well branch required a separate pennit to drill. The spud date for this wellbore is May 14, 2005, and the total depth of 15,634' MD, 6,528' TVD was reached on June 15, 2005. KRU 1C-21 and the associated laterals were equipped and conditioned to produce on June 22, 2005, which is the assigned completion date. The schematic diagrams (attached) illustrates tenninology and dates applied to the KRU 1C-21 well and its multilateral well branches. Steve Davies August 10, 2005 KRU 1 1 & Laterals Hi Diagram KRU IC-21 Date: May 2005 Reached ~- __~m__~__-CJ to KRU 1 C-2 I - 205-034 KRU IC-21Ll - 205-100 KRU IC-21L2 - 205-lOJ KRU ! C-2 J L3 - 205-102 10,2005 KRUl 1 Nomenclature KRU I C-21 205-034 KRU IC-21Ll - 205-100 KRU IC-21L2 - 205-101 KRU lC-21U - 205-102 KRU lC-21 Date: May 14, 2005 150' TVD 1 2. 3. 4. KRU lC-2JLl - 205-100 KRU lC-2JL2 205-101 KRU JC-21U - 205-102 KRU I C-21 205-034 Sidetrack No. KRU JC-21 Date TD Reached: June 5 Starts at: Surface I KRU IC-21 Date: May 14,2005 150' TVD WeIll S. Davies AOGCC KRU IC "Spud 1 & Laterals , Dates - -- -----:::::::::J to KRU 1 C-2! - 205-034 KRU IC-21L1 - 205-100 KRU IC-2IL2 - 205-101 KRU IC-2IL3 - 205-102 I. IC-2ILI - 205-100 2. KRU IC-21L2 205-101 3. KRU IC-2IU - 205-102 4. KRU I C-21 - 205-034 KRU IC-2! Date TD Reached: June 15 Starts at: Surface TD: I TVD 10,2005 . . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 14,' 2005 RECEIVED AUG 0 2 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Well Completion Reports for 1 C-21, 1 C-21 L 1, 1 C-21 L2, 1 C-21 L3 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk wells 1 C-21, 1 C-21 L 1, 1 C-21 L2 and 1 C- 21L3. Attached are the directional surveys for each lateral. Also attached are drawings describing each lateral. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. $~ r¡RaA/~ 1ÁdfrlQY R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad · RE~EIVED STATE OF ALASKA I AUG 0 2 2005 ALASKA Oil AND GAS CONSERVATION COMM ION . WELL COMPLETION OR RECOMPLETION REPORT ANDJillOGcons. CommissiOl Gas U Plugged D Abandoned D Suspended D WAG D 1b. Well Class: Anchorage 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D No. of Completions _ Other Service D Stratigraphic Test D 12. Permit to Drill Number: 1 a. Well Status: Oil 0 GINJ D WINJ D WDSPL D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1601' FNL, 1191' FWL, Sec. 12, T11N, R10E, UM At Top Productive Horizon: Total Depth: 46' FSL, 988' FWL, Sec. 8, T11 N, R11 E, UM 302' FNL, 2382' FWL, Sec. 17, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562198 <" y- TPI: x- 572234 y- Total Depth: x- 573633 / y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlRes, Dens/Neu 22. CASING SIZE WT. PER FT. 62.58# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 16" 10.75" 7-5/8" 4.5" 5968638 ' 5965094 5964760 ' Zone- 4 Zone- 4 Zone- 4 5. Date Comp., Susp., or Aband.: June 22, 2005 6. Date Spudded:,.vt~ I'/, '2a)$ ¡y, M~~2005 1::"p·oÇ" 7. Date TD Reached: June 15, 2005 8. KB Elevation (ft): 42' RKB 9. Plug Back Depth (MD + TVD): 15622' MD I 6528' TVD 10. Total Depth (MD + TVD): ~ 15634' MD I 6528' TVD 11. Depth where SSSV set: none 205-034 I 13. API Number: 50-029-23253-00 14. Well Name and Number: 1 C-21 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 28242, 25649, 28243 17. Land Use Permit: ALK 2292 19. Water Depth, if Offshore: N/A 20. Thickness of feet MSL Permafrost: KoÞ ¡S"ð' H(þ I />l:;)/ 'TY"è 1928' MD ,Â''I.' (O.of{" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 42' 116' 42' 116' 42' 5680' 42' 4480' 42' 9154' 42' 6542' 8983' 15624' 6513' 6528' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slotted liner from 8993'-15624' MD 24. SIZE 4.5" HOLE SIZE AMOUNT PULLED CEMENTING RECORD 24" 9 cu yds High Early 776 sx AS Lite, 389 sx LiteCrete 255 sx Class G slotted liner 13.5" 9-7/8" 6.75" TUBING RECORD DEPTH SET (MD) 8994' I PACKER SET 8994' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. Date First Production July 2, 2005 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Oil Producer WATER-BBL 7/2/2005 Flow Tubing press. 476 psi 27. 3 hours Casing Pressure 1060 Production for Test Period --> Calculated 24-Hour Rate -> OIL-BBL 589 OIL-BBL GAS-MCF 235 GAS-MCF 113 WATER-BBL 774 3737 2017 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 10-407 Revised 1212003 NONE RBDMS BFL AUG 0 8 2005 CONTINUED ON REVERSE L CHOKE SIZE not available OIL GRAVITY - API (corr) not available IGAS-OIL RATIO 540 - ~'.'.'~'--~ -...,~'\'\ Cy:c-;~ 1 1 ':1 (':':.' \': 1.1L~'i~~ ost I-\~;¡þ} I ,- ..~.-..----.-- 28. . 29. . FORMATION TESTS GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 C-21 Top Kuparuk C C-4 14195' 14195' 6563' 6563' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name. ~Z'dv Th. omas Signature~~q f( 12, I hdYK:<5 Title: Greater Kuparuk Area DrillinQ Team Leader Phone Contact: Tim Billingsley @ 265-6531 D..i1I7///òS Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/11/2005 04:00 - 10:00 6.00 MOVE DMOB MOVE Prepare for rig move. RDMO Rock Washer. Slide rig floor to center of drilling module. Disconnect service lines between drilling and service module. 10:00 -12:00 2.00 MOVE MOVE MOVE Move rig off well 1 F-01A. 12:00 - 00:00 12.00 MOVE MOVE MOVE Move Doyon Rig 15 from 1 F Pad to 1 C Pad. 5/12/2005 00:00 - 00:30 0.50 MOVE MOB . MOVE Move Doyon Rig 15 to 1 C-Pad. 00:30 - 02:30 2.00 MOVE POSN MOVE Move support module onto matting boards 02:30 - 06:00 3.50 MOVE POSN MOVE Move drilling module onto matting boards, turn tires. 06:00 - 08:30 2.50 MOVE POSN MOVE Move in and spot drilling module over well 1 C-21. 08:30 - 12:00 3.50 MOVE POSN MOVE i Skid rig floor over sub, shim up and level. Spot in support module, set in rock washer. 12:00 - 13:00 1.00 MOVE POSN RIGUP Hook up service lines. Complete berming around rig and rock washer. Accepted rig for operations on we1l1C-21 at 13:00 hrs. 13:00 - 15:00 2.00 MOVE RURD RIGUP Take on fuel and water for rig. CPAI E&I hook up hi-line power to rig. General rig up activities in pipe shed, mud pits, pump room, and cellar. 15:00 - 18:00 3.00 MOVE RURD RIGUP N/U 21-1/4" Divertor System and surface equipment. Take on 580 bbls pre-mixed spud mud into pits. 18:00 - 22:30 4.50 DRILL PULD SURFAC Load pipe shed with 5" drill pipe. Remove thread protectors, inspect, number, and strap 5" drill pipe. Drift on skate. 22:30 - 00:00 1.50 DRILL PULD SURFAC Set mouse hole in rotary table. P/U 5" drill pipe and make up in stands. Rack back drill pipe in derrick. 5/13/2005 00:00 - 05:30 5.50 DRILL PULD SURFAC . P/U 5" drill pipe and make up in stands. Rack back drill pipe in derrick. I Drift on skate. 05:30 - 06:00 0.50' DRILL PULD SURFAC Load 5" HWDP into pipe shed. Remove thread protectors, inspect, number, strap, and drift drill pipe. 06:00 - 09:30 3.50 DRILL RIRD SURFAC C/O Top Drive saver sub to 4-112" IF. Lay down all 4" handling tools, Clear rig floor. 09:30 - 11 :30 2.00 DRILL PULD SURFAC P/U 5" HWDP make uplbreak out new pipe. Rack back HWDP in derrick. 11:30 -12:00 ! 0.50 DRILL OTHR SURFAC Attempt to function test Divertor system. Top element in 21-1/4" Hydril I failed resulting in a 10 gal hydraulic spill to secondary contaminment. 12:00 - 18:00 6.00 RIGMNT RGRP SURFAC N/D riser, mouse hole and flow line. Remove beaver slide to access cellar. Remove and replace 21-1/4" Hydril divertor. 18:00 - 20:15 2.25 RIGMNT RGRP SURFAC N/U riser and flow line. Set in mouse hole. RIU flow line. Set in beaver slide. 20:15 - 22:15 2.00 DRILL OTHR , SURFAC . M/U stand of drill pipe and RIH. Function test divertor system, OK. Fluid I test, OK. Jeff Jones, AOGCC PI, waived witnessing Divertor function test. 22:15 - 00:00 1.75 DRILL PULD SURFAC M/U 13-112" bit and BHA. Set AKO on Motor at 1.5 deg. 5/14/2005 00:00 - 00:15 0.25 DRILL PULD SURFAC M/U 13-1/2" Bit & BHA #1. Set MM AKO at 1.5 deg. 00:15 - 01:15 1.00 DRILL ,PULD SURFAC RIU sheave in derrick for S/L run with gyro survey. 01:15-02:00 0.75 DRILL REAM SURFAC PIT surface mud lines to 2,500 psi. OK. Clean out ice from inside 16" ì conductor to 116' with FW. 02:00 - 02:15 0.25 DRILL DRLG SURFAC Drill 13-112" OH to 130'. 02: 15 - 04:45 2.50 DRILL PULD SURFAC POH, rack back HWDP. M/U MWD tools and orient same. 04:45 - 07:00 2.25 DRILL CIRC SURFAC RIH to btm. Break circulation with spud mud. Returns are thick mud will not flow down auger chute. Circulate and condition mud until vis is down to 300. 07:00 - 08:30 1.50 DRILL DRLG SURFAC Drill 13-1/2" OH to 277'. 08:30 - 09:00 0.50 DRILL TRIP SURFAC POH to 1 00' 09:00 - 09:45 0.75 DRILL PULD SURFAC M/U remaining BHA, Drill collars and Jars. 09:45 - 10:00 0.25 DRILL TRIP SURFAC RIH to btm. 10:00 - 17:30 I 7.50 DRILL DRLG SURFAC Rotary drill 13-112" OH to KOP at 1,110'. I Printed: 7/5/2005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6.50 DRILL DRLG SURFAC Directionally drill 13-1/2" OH to 1,886' MD. ART = 9.23 hrs. AST = 4.1 hrs. ADT = 13.33 hrs. 5.00 DRILL DRLG SURFAC Directionally Drill 13-112" OH to planned inclination and azimuth at 2,499' MD. AST=2.15, ART=1.25, ADT=3.4, P/U=152k, S/O=145k, Rot=145k, gpm= 550 @ 2,225 ps on bottom, 1750 psi off bottom, 80 rpm, Torque= 7-8k on bottom, 3-4k off bottom, 19.00 DRILL DRLG SURFAC Rotary Drill 13-112" OH to 4,609' MD. Maintain inclination and azimuth. AST = 3.03 hrs ART = 12.47 hrs ADT = 15.5 hrs Rot=160K, P/U=200K, S/O=150K, rpm=80, Torque=10kon, 1 Otorque off = 7-8k, gpm=560 @ 2,379 psi on bottom, 2100 psi off bottom. 1.50 DRILL ! DRLG SURFAC Drill 13-112" hole per directional plan. AST=O, ART=1.06. ADT=1.06. Rot=160k, P/U=200k, S/O=140k, rpm=80, Torque=10-14k on 7-8k off, gpm=500 psi @ 2050 on bottom, 1550 psi off bottom. ROP decreased and torque was spiking Stand back stand and CBU @ 429 gpm @ 1400 psi. I Monitor well for 10 min.lstatic. POOH 2 stands and pump dry job. Blow down top drive and POOH to BHA wI no problems. CIO Bit and MWD Tool. RIH shallow test MWD. Tool Failure. POH. CIO MWD Tool. RIH. Shallow test MWD Tool, OK. M/U DC's, Jars, & HWDP, RIH Slip & Cut Drilling Line. RIH to 1,300'. Inspect Drawworks. Drum coolant line parted. POH to repair Drawworks. Repair Draworks Drum Coolant Line. i RIH to 1,300' RIH with Bit #2 to 2,839' RIH with Bit #2. MIU top drive, break circulation, wash last 60' to Btm at 4,688'. Hole in good condition. Drill 13-112" OH as per directional plan to 5,690' MD, TVD 4,490'. Up wt = 220K, Dn wt = 150K, ROT wt = 180K, TQ = 1 0-18K, Circ at 650 GPM 2,650 psi. AST = 1.58 hrs, ART = 6.78 hrs, ADT = 8.36 hrs. AVG ROP = 120 fph. Circulate and condition Mud. Lower funnel viscosity to 100 s/qt. Monitor well for 10 min. Well static. POH 5 stds, Pump dry job, POH to BHA. Tight spot observed at 1,550'. Work tight spot clean. SLM, no correction to strap. , Lay down BHA and clear floor. Down load data from MWD tool. Finish laying down BHA, Clear Rig Floor. Remove hazardous ice build up from derrick prior to running casing. RIU equipment to run 10-3/4" casing. Make drift run with FMC mandrel casing hanger thru 20" riser and hydril divertor.. RIU spider and elevators. M/U Franks circulating tool. RIU casing power tongs. Inspect and function test stabbing board. Service Top Drive and Crown. PJSM, RIH with 10-3/4" Casing to 2,600'. Up wt = 140K, Dn wt = 115K. Observed hole drag from 1,400' to 2,600' at 10-35K. ! Circulate and condition mud at 45 spm, 350 psi. ! RIH with 10-3/4" casing to 3,100'. Observed hazardous ice build up in derrick. Remove ice build up from derrick. RIH with 10-3/4" casing to 4,050'. 5/14/2005 17:30 - 00:00 5/15/2005 00:00 - 05:00 05:00 - 00:00 5/16/2005 00:00 - 01 :30 01 :30 - 03:00 1.50 DRILL CIRC SURFAC 03:00 - 08:00 5.00 DRILL TRIP SURFAC 08:00 - 11 :30 i 3.50 DRILL DEOT SURFAC 11:30 -13:30 2.00 DRILL DEOT SURFAC 13:30 - 14:30 1.00 DRILL TRIP SURFAC 14:30 - 16:00 1.50 RIGMNT RSRV SURFAC 16:00 - 16:30 0.50 DRILL TRIP SURFAC 16:30 - 17:00 0.50 RIGMNT RGRP SURFAC 17:00 - 19:00 2.00 DRILL TRIP SURFAC ! 19:00 - 21 :00 2.00 RIGMNT RGRP SURFAC 21 :00 - 21 :45 0.75 DRILL TRIP SURFAC 21 :45 - 00:00 2.25 DRILL TRIP SURFAC 5/17/2005 00:00 - 03:30 3.50 DRILL TRIP í SURFAC 03:30 - 15:30 12.00 DRILL DRLG SURFAC 15:30 - 19:00 3.50 DRILL CIRC SURFAC 19:00-19:15 0.25 DRILL OBSV SURFAC '19:15 - 23:00 3.75 DRILL TRIP SURFAC 23:00 - 00:00 1.00 DRILL PULD SURFAC 5/18/2005 00:00-01:15 1.25 DRILL SURV 'SURFAC 01:15 - 02:15 1.00 DRILL PULD SURFAC 02:15 - 03:15 1.00 CASE SFTY SURFAC 03:15 - 05:30 2.25 CASE ¡RURD SURFAC 105:30 - 06:00 0.50 CASE RURD SURFAC 06:00 - 11 :30 5.50 CASE RUNC SURFAC 11 :30 - 12:30 1.00 CASE CIRC SURFAC 12:30 - 13:00 0.50 CASE RUNC i SURFAC 13:00 - 13:30 0.50 CASE SFTY SURFAC 13:30 - 17:00 3.50 CASE RUNC SURFAC Printed: 7/5/2005 4:13:27 PM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/18/2005 17:00 - 18:00 1.00 CASE CIRC SURFAC Circulate and condition mud at 48 spm, 450 psi. 18:00 - 21:00 3.00 CASE RUNC SURFAC RIH with 10-3/4" casing to 5,650'. Total jts ran = 139. 21:00-21:15 0.25 CASE 'RUNC SURFAC M/U FMC 10-3/4" Mandrel casing hanger with landing jt. Land casing on landing ring. 21:15-22:00 0.75 CASE RURD SURFAC NID Franks fill up tool. M/U Schlumberger Cement head. 22:00 - 00:00 2.00 CASE CIRC SURFAC Circulate and condition mud prior to cement job. Reciprocate casing at 320K up and 180K dn. 5/19/2005 00:00 - 03:30 3.50 CEMENTCIRC SURFAC Circulate and condition mud for cement job. Mud properties are 10.0 ppg, Vis 57, 600 rpm 28,300 rpm 18, 200 rpm 13, 100 rpm 10,6 rpm 5, 3 rpm 4, PV 10, YP 8, Gels 5/6/8. Pump rate 7 bpm at 200 psi. Reciprocate Casing. Up wt 310K, Dn wt 200K. 03:30 - 03:45 0.25 CEMENT SFTY SURFAC PJSM with Rig Crew, Cementers, and Truck Drivers. 03:45 - 06:00 2.25 CEMENT PUMP SURFAC . Pump 7.5 bbls water. Test cement lines to 3,500 psi. Pump 50 bbls CW100 followed by 50 bbls 10.5 ppg Mud Push. Shut down pumping and drop bottom plug. Mix and pump 615 bbls lead slurry at 10.7 ppg followed by 155 bbls tail slurry at 12.0 ppg. Pump rate while mixing 6 bpm at 100 psi. Reciprocate casing at Up wt 320K, Dn wt 190K with full returns. 06:00 - 08:30 2.50 CEMENT DISP SURFAC Stop pumping. Drop top plug. Cementers pump 20 bbls FW behing plug. Shut down cementers. Switch to rig mud pump. Displace cement at 3-5 bpm, ICP 420 psi, FCP 1,235 psi. Bump plug with 1,735 psi on calculated strokes. Hold pressure for 10 min. Bleed off pressure. Floats held. CIP at 08:30 hrs. Land casing after 260 bbl displaced. Observed full returns during displacement. 200 bbls cement returned to surface. 08:30 - 10:30 2.00 CEMENTPULD SURFAC Flush riser with FW, Break out and lay down cement head and landing ,joint. Clear rig floor. 10:30 - 10:45 0.25 WELCTL SFTY SURFAC PJSM on N/D Divertor System. 10:45 -14:00 3.25 WELCTL NUND SURFAC N/D flow line and riser. Remove from cellar area. Flush Knife valve and Hydril Annular with FW. Observed hydrates breaking out from 10-3/4" X 16" annulus. 14:00 - 16:00 2.00 WELCTL OBSV SURFAC P/U 10-3/4" Landing joint and stab into casing hanger. Monitor and observe hydrates breaking out from 1 0-3/4" x 16" annulus. 16:00 -16:15 0.25 WELCTL, SFTY SURFAC PJSM, Review CPAI shallow gas flow procedure with rig crews. 16:15 - 23:00 6.75 WELCTLOBSV SURFAC Monitor and observe hydrates breaking out from 10-3/4" x 16" annulus. Hydrates steadly diminished. Annulus observed to be static. 23:00 - 00:00 1.00 WELCTL NUND SURFAC Lay down 10-3/4" landing joint. Prepare to N/D hydril annular. 5/20/2005 00:00 - 02:00 2.00 CASE NUND SURFAC N/D 21-1/4" Diverter System. i 02:00 - 04:00 , 2.00 CASE NUND SURFAC N/U FMC Gen 5 Wellhead Equipment. Test seals to 1,000 psi for 10 min. OK. 04:00 - 04:15 0.25 WELCTL SFTY , SURFAC . PJSM, Review DDI N/U & Test BOPE Procedure. 04:15 -10:30 6.25 WELCTL NUND SURFAC N/U BOPE. 10:30 - 11 :30 1.00 WELCTL. BOPE SURFAC RIU equipment to test BOPE. 11 :30 - 20:00 8.50 WELCTL BOPE SURFAC Test BOPE per AOGCC Regs, Approved Drilling Permit, & CPAI Drilling Policy. Test pressures were 250 psi and 3,500 psi. All test pressures held for 5 min and charted on test recorder. AOGCC PI Chuck Scheve, CPAI Senior Drilling Supervisor Fred Herbert, and DOl Senior Toolpusher Ron Matteson witnessed BOPE test. 20:00 - 21 :00 1.00 DRILL PULD SURFAC Lay down 8" flex collars from derrick. 21:00 - 21:15 0.25 DRILL SFTY . SURFAC : PJSM on picking up BHA #3. 21:15 - 23:00 1.75 DRILL PULD SURFAC M/U 9-7/8" bit and BHA # 3 23:00 - 23:45 0.75 DRILL DEQT SURFAC Load MWD/LWD. Dir/Gr/Res/PWD. 23:45 - 00:00 0.25 DRILL TRIP SURFAC RI H with BHA #3 to 1,020'. 5/21/2005 00:00 - 00:45 0.75 DRILL TRIP SURFAC I P/U 9 jts 5" drillpipe, RIH to 1,290'. Printed: 7/5/2005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/21/2005 00:45 - 01 :30 0.75 DRILL DEQT SURFAC Circulate and condition mud. Shallow test MWD tool, OK. 01 :30 - 03:45 2.25 DRILL TRIP SURFAC P/U 90 jts 5" drillpipe, RIH to 4,000'. 03:45 - 04:30 0.75 DRILL TRIP SURFAC RIH with 5" drillpipe from the derrick to 5,511'. 04:30 - 05:45 1.25 DRILL OTHR SURFAC M/U Top Drive, Break circulation. Wash down to TOC at 5,570'. I Circulate and condition mud for casing test. I 05:45 - 06:00 0.25 CASE MIT SURFAC RIU to test casing. 06:00 - 07:00 1.00 CASE MIT SURFAC Test 10-3/4" casing to 2,500 psi. Pressure bled back to 2,485 psi. Held for 30 min. OK. RID test equipment. 07:00 - 10:30 3.50 DRILL DRLG SURFAC ! Drill cement, float equipment, and 20' new hole to 5,710'. 10:30 - 13:00 2.50 DRILL CIRC SURFAC Circulate and condition mud. Change mud system over to 9.5 ppg LSND. 13:00 - 14:30 1.50 DRILL LOT SURFAC Perform LOT as per CPAI FITILOT Procedure. EMW = 14.6 ppg at 9.5 ppg 5,680'MD, 4,505'TVD. Surface pressure of 1,200 psi observed at leak off. 14:30 - 00:00 9.50 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 5,710' to 6,640' MD 15,130' TVD. AST = 1.06 hrs, ART = 5.51 hrs, ADT = 6.57 hrs, Avg. ROP = 145 fph. Up wt = 220K, Dn wt = 160K, Rt Wt = 180K. Pump pressure = 3,300 psi at 650 gpm. Top Drive RPM = 100, MM RPM = 215. RT Torq = 11-18K. 5/22/2005 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 6,642' MD (5,130' TVD) to 8,263' MD ( 6,202' TVD). AST = 4.28 hrs, ART = 10.37 hrs, ADT = 14.65 hrs, Avg. ROP = 115 fph. Up wt = 275K, Dn wt = 175K, Rt Wt = 195K. Pump pressure = 3,450 psi at 650 gpm. Top Drive RPM = 100, MM RPM = 215. RTTorq = 11-18K. 5/23/2005 00:00 - 20:30 20.50 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 8,283' MD (6,202' TVD) to 9,112' MD ( 6,535' TVD ) Up wt = 245K, Dn wt = 165K, RT wt = 200K, AST = 4.58 hrs, ART = 2.74 hrs, ADT = 7.32 hrs. Avg. ROP = 113 fph. Top Drive RPM = 100. MMRPM = 215. RT Tq = 12-20K. Pump Pressure = 3,500 psi at 600 gpm. K-1 marker at 8,712' MD (6,429' TVD). 20:30 - 21 :30 1.00 DRILL CIRC INTRM1 Circulate Btms up sample for Geologist. 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 9,112' MD ( 6,535' TVD ) to 9,150' MD ( 6,542' TVD ) Up wt = 240K, Dn wt = 170K, RT wt = 200K, AST = 1.01 hrs, ART = .84 hrs, ADT = 1.85 hrs. Avg. ROP = 21 fph. Top Drive RPM = 100. MMRPM = 215. RT Tq = 12-20K. Pump Pressure = 3,290 psi at 580 gpm. 5/24/2005 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 9,150' MD (6,535' TVD) to 9,160' MD Up wt = 240K, Dn wt = 170K, RT wt = 200K, AST = .3 hrs, ART =0 hrs, ADT = .3 hrs. Avg. ROP = 30fph.Pump Pressure = 3,290 psi at 580 I gpm. I I 00:30 - 02:00 1.50 DRILL ICIRC i INTRM1 Circulate and condition hole F/short Trip. 02:00 - 06:00 4.00 DRILL WIPR ! INTRM1 Trip out hole T/ Shoe @ 5680' 06:00 - 07:30 1.50 RIGMNT RSRV INTRM1 Rig servo Grease crown - Top Drive - Monitoir well I 07:30 - 09:30 i 2.00 DRILL WIPR INTRM1 Trip in Hole (slowly) Taking wieght @ 8850'. 09:30 - 12:00 I 2.50 DRILL REAM INTRM1 Wash & Ream FI 8,830' - T/9, 160' 12:00 - 15:30 3.50 DRILL CIRC INTRM1 Circ, & Condition Pump 44 bbl Wieghted Sweep, Spot 120bbl pill on Btm. 15:30 - 17:00 1.50 DRILL TRIP INTRM1 Trip Out Hole Work through Tight hole @ 8,830' - 8,735' Pull 10 stands. 17:00 - 17:30 0.50 I DRILL CIRC INTRM1 Monitior well, Pump Dry Job, Blow down 17:30 - 22:30 5.00 DRILL TRIP INTRM1 Trip Out Hole Monitior well @ Shoe and BHA 22:30 - 23:30 1.00 DRILL TRIP INTRM1 Stand back Heavy Wieght Drill Pipe, UD jars, Collars, ·23:30 - 00:00 0.50 DRILL DEQT ì INTRM1 Down Load Directional Tools (MWD) 5/25/2005 00:00 - 02:00 2.00 DRILL SURV INTRM1 Clean Tools and UD MWD & MTR. 02:00 - 03:30 1.50 CASE OTHR INTRM1 Close blind rams circ through mud cross monitoir well. Change Top Printed: 7/512005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/25/2005 02:00 - 03:30 1.50 CASE OTHR INTRM1 rams TI 7 5/8. No gainlloss during ram change. 03:30 - 07:00 3.50 CASE OTHR INTRM1 Pull wear ring,Set test plug, Problem setting test plug wash and flush, RIU test top Rams 250psi. low, 3,500high 5 min each chart and witness.UD test joint & test plug, Clean and clear floor area. 07:00 - 07:30 0.50 RIGMNT RSRV INTRM1 Rig Service 07:30 - 09:00 1.50 RIGMNT RGRP INTRM1 Work on Rig, Drawworks Brake Coolant Line 09:00 - 09:30 0.50 CASE SFTY INTRM1 Pre Job Safety Meeting with crews and support on running 7 5/8 csg. 09:30 - 12:00 2.50 CASE RUNC INTRM1 Finish rigging up to run 7 5/8 - 29.7# - L-80 - Mod Csg. P/U Shoe jt. Fill and Check float 1 jt above float jt OK. RIH W/7 5/8 csg. 12:00 - 12:30 0.50 CASE OTHR INTRM1 Laydown franks Circ. Tool, Replace O-Ring. 12:30 - 18:00 5.50 CASE RUNC INTRM1 Run 7 5/8-29.7#- L80-Mod Csg. 133jts Csg. T/10 3/4 shoe 18:00 - 20:00 2.00 CASE CIRC INTRM1 Circulate and condition mud. 20:00 - 00:00 4.00 CASE RUNC INTRM1 Run in Hole 7 5/8-29.7#- L-80- Mod Csg. to 9110' Fill every joint and record P/U and S/O every 10 joints. Break circ, above recorded tight spot @ 8,750' precautionary. No problems. 5/26/2005 00:00 - 01 :00 1.00 CASE RUNC INTRM1 P/U landing Jt. and hanger wash down, Land Out @ 9,153'. Up wt.280 - Dn Wt. 160. UD Franks Circ. Tool. M/U Cmt. Head. 01 :00 - 04:00 3.00 CASE CIRC INTRM1 Circulate and condition mud for cement job. Start @ 3 bbls min and stage up to 6 bbls per min. 685psi. Up Wt, 280 Dn Wt. 160. Recipacating pipe. PJSM onn CMT job. 04:00 - 06:00 2.00 CEMENT PUMP INTRM1 Pump 2bbls water - Press test 3500psi. - 30 bbls CW100 wash - 50 bbls 12.5 ppg. Mud Push XL spacer - 51 bbls G cement (255sx) 15.8 ppg. - 10 bbls Water - Displace with 395 bbls 10.1 ppg @ 6.5 bpm slowed TI 3 bpm 11 bbls total mud pumped 406 bbls. Bumped plug 650 psi. Pressured up to 1,200psi. Check floats CIP @ 0600 hrs 06:00 - 08:30 2.50 CEMENT RURD INTRM1 RID CMT Head, Csg, Elevators, Landing Jt, Clean and break down franks Circ, tool, Change Bails 08:30 - 09:30 1.00 CASE OTHR INTRM1 Drain stack & Flush, Set Pack Off, Test pack off seals TI 5,000psi. FI 10min. 09:30 - 11 :30 2.00 DRILL OTHR INTRM1 Change Rams, Install Variable 31/2" x 6" in Top and 4" Bottom, 11 :30 - 12:00 0.50 RIGMNT RSRV INTRM1 Rig Service 12:00 - 18:00 6.00 DRILL PULD INTRM1 PJSM - UD 5" Drill Pipe from derrick 159 jts. 18:00 - 21 :30 3.50 DRILL PULD INTRM1 PJSM - UD 5" Drill Pipe. 102 jts. 21 :30 - 23:30 2.00 DRILL OTHR INTRM1 Change Out Saver sub & Bell guide on top Drive TI 4" XT 39. . 23:30 - 00:00 0.50 DRILL OTHR INTRM1 PIU all 4" Test Equipment & Handling Equipment to Rig floor. 5/27/2005 00:00 - 01 :30 1.50 DRILL OTHR INTRM1 RIU test BOP,Run test plug,fill stack open annulas, 01 :30 - 07:00 5.50 DRILL OTHR INTRM1 TEST BOP Equipment 250 low - 3,500 high, Koomey test, Test all floor valves. 07:00 - 08:30 1.50 DRILL RIRD INTRM1 Rig down test equipment, Pull test plug, Install wear Ring I.D.(7 1/8"). Blow down Top Drive, Mud Pumps and choke manifold. 08:30 - 15:00 6.50 DRILL SFTY INTRM1 PJSM, PIU 4" Drill Pipe 14.5# S-135 XT-39 15:00 - 16:30 1.50 RIGMNT RSRV INTRM1 PJSM, Cut Drill Line (95'), Inspect and adjust Brakes, 16:30 - 19:30 3.00 DRILL PULD INTRM1 Pull Drill Pipe out of hole to Rack back in derrick for drilling. 56 stands. 19:30 - 00:00 4.50 DRILL SURV INTRM1 P/U tools M/U Geo - Pilot and MWD - Program Tool 5/28/2005 00:00 - 00:15 0.25 DRILL SFTY INTRM1 H2S Drill 00:15 - 02:00 1.75 DRILL SURV INTRM1 Pulse test MWD, Load Nukes (PJSM) 02:00 - 03:00 1.00 DRILL PULD INTRM1 M/U BHA (cont.) 03:00 - 04:45 1.75 DRILL TRIP INTRM1 RIH FIPipe Shed 75 jts. 4" Drill Pipe 14.5# S-135 XT-39 RIH. 04:45 - 06:00 1.25 DRILL SURV INTRM1 Fill pipe, Test MWD, Break in Geo-pilot seals. Rotating 5 RPM. Send Down link 0 deflections and 0 Toolface, Showed 100% deflection, Manually Sent home command still showed 80%.Change jet. P/U WT 110 - DN.wt 100 - ROT 1 05 06:00 - 06:30 0.50 DRILL TRIP INTRM1 PIU 4" Drill Pipe 14.5# S-135 XT-39 Total 91jts. ì I I Printed: 7/512005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/28/2005 06:30 - 07:00 0.50 DRILL SURV INTRM1 Test Geo-Pilot 300 gpm, Blow down Top Drive. 07:00 - 08:30 1.50 DRILL TRIP INTRM1 P/U 4" Drill Pipe 14.5# S-135 XT-39,TotaI151 its. 08:30 - 09:00 0.50 DRILL SURV INTRM1 Test Geo-Pilot 280 gpm, Blow down Top Drive. 09:00 - 12:00 3.00 DRILL TRIP INTRM1 P/U 4" Drill Pipe 14.5# S-135 XT-39,TotaI250 its. 12:00 - 12:15 0.25 DRILL SFTY INTRM1 H2S Drill 12:15 -13:30 1.25 DRILL TRIP INTRM1 PIU 4" Drill Pipe 14.5# S-135 XT-39,TotaI276 its. 13:30 - 14:30 1.00 CEMENTDSHO INTRM1 Wash and Ream cement Stringers F/9,004' - T 19,045' ·14:30 - 15:30 1.00 DRILL CIRC INTRM1 Circulate and Condition Mud for Casing Test. 15:30 - 16:30 1.00 CASE MIT INTRM1 RIU test Csg. T/3,500psi. F/ 30 min. Chart and plot. RID test equipment, Test Geo-Pilot skid manifold 16:30 - 22:30 6.00 CEMENTDSHO INTRM1 Drill CMT F/9,045' T/9,060', Drill on float, Drill T/9, 153' Drill Shoe @ 9,153. T/9,160' 22:30 - 23:00 0.50 DRILL DRLG INTRM1 Drill 20' of new hole F/9, 160' - T/9, 180' 50 RPM 275gpm 2500psi. WOB 6-8 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Circulate and Condition mud for FIT- LOT, 5/29/2005 00:00 - 01 :00 1.00 DRILL FIT INTRM1 Perform FIT as per CPAI FITILOT Procedure. EMW = 12.6ppg at 10 ppg 9180'MD, 6,543' TVD. Surface pressure of 900 psi. 01 :00 - 03:00 2.00 DRILL CIRC PROD Change Mud out F/10 ppg LSND @ 250 GPM Up WT. 215, DN WT. 135, ROT WT. 156. TI Flow Pro 9.2 ppg. Flush all lines, Displace well 35 bbllow vis-35 bbl high vis-Flow pro, New SPR. #2 MP 20spm-780psi., 30spm - 980 psi. New Wt With 9.2 flow pro. @ 250 GPM UP WT. 155, DN WT. 150, ROT. 150. 03:00 - 03:30 0.50 DRILL OTHR PROD Shut down Monitior and clean Shakers install screens and clean surface equipment. 03:30 - 13:30 10.00 DRILL DRLG PROD Drill 6 3/4" OH from 9,180' MD ( 6,543' TVD ) to 9,700' MD, Up wt = 180, Dn wt = 140, RT wt =150, Bit Hrs = 6.77 hrs, Avg. ROP = ??fph.Pump Pressure = 2200 psi at 285 gpm. APIG = 52' per hr. 13:30 - 16:00 2.50 DRILL ,CIRC PROD Work on GEO-PILOT and Replace Manifold, Decision made GEO - PILOT failed TOOH. 16:00 - 16:30 0.50 DRILL TRIP PROD Monitior Well, T.O.O.H. T /9,050' 16:30 - 17:30 1.00 DRILL CIRC PROD Monitoir Well, Pump Dry Job, Blow down Top Drive. 17:30 - 22:00 4.50 DRILL TRIP PROD T.O.O.H. - Recording up and down wts Every 5 stands. 22:00 - 22:15 0.25 DRILL OBSV PROD Monitior Well @ Heavy Wieght, 22: 15 - 00:00 1.75 DRILL ·TRIP PROD PJSM - Work BHA,Remove Radioactive source, Download MWD. 5/30/2005 00:00 - 01 :00 1.00 DRILL SURV PROD Down Load MWD- UD GEO Pilot 01 :00 - 03:30 2.50' DRILL SURV PROD PJSM; P/U 5" Motor WI 1.22 deg. Bend Flow Rates 250-300 gpm, .77 brev. M/U Bit. Orientate and upload MWD and Load Sources.P/U BHA .T/406', Shallow test 03:30 - 08:00 4.50 DRILL TRIP PROD 'T.I.H. Fill Pipe every 25 stands. 08:00 - 00:00 16.00 DRILL DRLG PROD Drill 6 3/4" OH F/9,700' MD T I 10,220' MD, Up wt =190, On wt = 145, RT wt =155, Bit Hrs = 13.69 hrs, ADT 9.75 hrs. AST = 5.00, ART = 4.75 hrs. Jar hrs.13.57 Pump Pressure = 2700 psi at 290 gpm. APIG =38' per hr. ROP = 62' per. 5/31/2005 00:00 - 03:30 3.50 DRILL DRLH PROD Drill 6 3/4" OH F/10,310' MD T I 10,336' MD, Up wt =180, Dn wt = 140, RT wt =155, Bit Hrs = 13.69 hrs, ADT 21.96 hrs. AST = 7.95, ART = 5.01 hrs. Jar hrs.19.74 Pump Pressure = 2700 psi at 290 gpm. APIG = , 32.6 per Hr. Sliding straight down to get back in C sands. 03:30 - 04:30 1.00 DRILL TRIP PROD Pump out hole to 10,060' 04:30 - 14:30 10.00 DRILL OTHR PROD Open Hole Side track @ 10,060' Orient toolface down and start sidetrack. 68 spm = 289 gpm, 2,350 psi. UP WT. 170, ON WT. 135. 14:30 - 23:00 8.50 DRILL TRIP PROD Monitor Well, TOOH T/Shoe. Monitor @ shoe 9,153'. Pump Pill, TOOH T/ 5,050' crew change monitor well, TOOH to BHA. Monitior Well, Work BHA PJSM remove Radioactive source, Down load MWD, and Upload Printed: 7/5/2005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: I 5/31/2005 14:30 - 23:00 8.50 DRILL TRIP PROD 23:00 - 00:00 1.00 DRILL PULD PROD 6/1/2005 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 01 :00 0.50 DRILL TRIP PROD 01 :00 - 05:30 4.50 DRILL TRIP PROD 05:30 - 07:00 1.50 RIGMNT RSRV PROD 07:00 - 08:00 1.00 RIGMNT RSRV PROD 08:00 - 13:30 5.50 RIGMNT RGRP I PROD 13:30 -14:45 1.25 DRILL TRIP 'PROD 14:45 - 23:30 8.75 DRILL OTHR PROD 23:30 - 00:00 I 0.50 DRILL DRLG PROD I I I I 6/2/2005 00:00 - 02:15 2.25 DRILL DRLH PROD 02:15 - 02:45 0.50 DRILL WIPR PROD 02:45 - 03:15 0.50 DRILL WIPR PROD 03: 15 - 06:00 2.75 DRILL DRLH PROD 06:00 -12:00 6.00 DRILL DRLG PROD 12:00 - 13:30 1.50 DRILL DRLH PROD 13:30 - 14:30 1.00 DRILL TRIP PROD 14:30 - 22:30 8.00 DRILL OTHR PROD I 22:30 - 23:15 0.75 DRILL !OTHR PROD 23: 15 - 00:00 0.75 DRILL OTHR PROD 6/3/2005 00:00 - 05:45 5.75 DRILL OTHR PROD 05:45 - 06:30 0.75 DRILL TRIP PROD 06:30 - 07: 15 0.75 DRILL CIRC PROD 07:15-11:30 4.25 DRILL TRIP PROD 11 :30 - 14:00 2.50 DRILL TRIP PROD 14:00 - 16:45 2.75 DRILL SURV PROD 16:45 - 20:30 3.75 DRILL TRIP PROD 20:30 - 21 :00 0.50 RIGMNT RSRV PROD 21:00 - 21:15 0.25 DRILL TRIP PROD 21:15-21:45 0.50 DRILL OTHR PROD 21 :45 - 00:00 2.25 DRILL OTHR PROD for TIH. UD 1.22 Motor, PIU New Motor Change T/1.5 deg. R.R. Bit HYC DS 111 Shallow test MWD and Load Nuclear source TIH W / BHA. I TIH fill every 25 stands TI 9,104' I PJSM - Cut and slip 85' Drlg line. I Service Rig, Top Drive, Grease Crown Repair Brake cooling lines and brake pad Trip In Hole to 10,040' Orient tool to 160 R begin sliding and troughing 10,040' - 10,090'. Start time drilling @ 147R T 110,107' Drlg Ahead F /10,107' - T 110,120' Pump press=2,366 psi. off btm. 2,500 psi. on btm. Up Wt. 180, DN Wt. 135. Slide hrs .5 ADT. New survey @ 10,131' 88.21. Old Survey @ 10,173' 92.55 Drill horizontal section from 10120' to 10223'. AST=.81 hr. ART=.85 hr. TST=1.31, TRT=.85, P/U=180k, S/0=140k, 69 spm 298 gpm @ 2400 psi on bottom/2300 psi off bottom. Pump out of hole from 10223 to 9944'. Rot 60 rpm. Pump 68 spm Orient toolface to highside and wash from 9944' to 10133'. Took weight @ 10107'. Back ream up past 10107'. Reorient to highside and wash wlo rotating past 10107' without taking weight. Wash to 10223' and tag up. Pumping @ 69 spm @ 2440 psi. Max gas=3923 units. Drill from 10223'to 10302'. ART=.33, AST=2.47, TRT=1.18, Pumping 70 spm (300 gpm), 2600 psi on bottom, 2400 psi off bottom, P/U =180k, S/O=140K, Rot=150k. Drill from 10302' to 10,393' ,6,535 tvd AST= 4, Pumping 70 spm (300 gpm), 2600 psi on bottom, 2400 psi off. bottom, P/U =180k, S/0=140K, Rot=150k. Drill from 10,393' to 10,410', 6,535 tvd AST= .94, Pumping 70 spm (298 gpm), 2300 psi on bottom, 2100 psi off. bottom, P/U =180k, S/0=135K, Could not drop angle. POOH to new side track depth, 9,630' UP WT. 180k - DN WT. 135k Orientate 180 deg. Trough F/9,600' - T/9,630', Start time Drilling for kick off. 9,630'. - 9,642' Slide 160deg. slide 9,661 in old no side track. Re-Check surveys look at first hole log. Suggest alternate K.O.P. up hole @ 9,600'. Start troughing @ 9,568' to 9,600' 180 deg. Start Kick Off. @ 9,600' Side track - Time Drilling to sidetrack well F /9,600-9,630' @ 161 r Orientation. No side track obtained Pump Out of hole, Monitoir well, drop ball to open CCV. opened circ. sub 2,800 psi. Pump Dry Job. Trip out of Hole. tI HWDP, Monitior well Trip out HWDP. PJSM on handling Nuclear source, Work BHA Change Motor bend T/1.83 deg. M/U new Bit FM 2643. Orient, Upload MWD, Shallow test, load Nuclear sources. PIU BHA. T.I.H. Fill every 25 stands Rig service-Grease Crown, Lubricate and check. Cont. Trip in hole Orientate tool face to 150r Trough 70 spm = 2300psi. Start kick off - Time slide 70 spm = 2300psi off btm - 2350 psi. on btm. High gas units 4179 from btms up. Printed: 7/512005 4:13:27 PM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/4/2005 00:00 - 03:30 3.50 DRILL DRLH PROD '03:30 - 03:45 0.25 DRILL SURV PROD 03:45 - 05:45 2.00 DRILL DRLH PROD 05:45 - 06:15 0.50 DRILL REAM PROD 06:15 - 06:30 0.25 DRILL OTHR PROD 06:30 - 18:00 11.50 DRILL DRLH PROD 18:00 - 00:00 6.00 DRILL DRLH PROD DRILL PROD 6/5/2005 00:00 - 05:30 5.50 DRILL DRLH PROD '05:30 - 07:15 07: 15 - 07:30 07:30 - 08:30 08:30 - 18:00 1.75 DRILL ,WIPR PROD 0.25 RIGMNT RSRV PROD 1.00 DRILL WIPR PROD 9.50 DRILL DRLH PROD 18:00 - 00:00 6.00 DRILL DRLH PROD 6/6/2005 00:00 - 18:00 18.00 DRILL DRLH PROD 18:00 - 20:00 2.00 DRILL CIRC PROD 20:00 - 00:00 4.00 DRILL OTHR PROD 6/7/2005 00:00 - 18:00 18.00 DRILL DRLG PROD Time slide Kick Off F/9,605' - T/9,630', TVD 6,547 70 spm = 2300psi off btm - 2350 psi. on btm. Survey - Confirm new hole @ 9,630' Old hole 90.85 incl. 106.55 azm. interpolated. Side Track hole 87.16 incl. 108.32 azm. Drill 6 3/4" OH F/9,630" MD T 19,755' MD, Up wt =180, Dn wt = 135, RT wt =150, Pump Pressure = 2300 psi. off Btm, 2,350 psi. on Btm @ 3009pm. Jar hrs 49.59, ADT=6.66(lncluding time drill). ART= .94 AST= 5.72. Max Gas 2,903' Back Ream out of hole F/9,755 - T /9,572'. Orient high side, Challenge side trac, No Problems, Drill 6 3/4" OH F/9,755 MD T 110,693' MD, Up wt =180, Dn wt = 135, RT wt =150, Pump Pressure = 2,750 psi. off Btm, 3,100 psi. on Btm @ 335 gpm. Jar hrs 56.74, ADT=7.05 ART= 6.05 AST= 1. Drill 6 3/4" OH F/10,693 MD T 111063' MD, Up wt =180, Dn wt = 135, RT wt =150, Pump Pressure = 2,750 psi. off Btm, 3,100 psi. on Btm @ 335 gpm. Jar hrs 60.55, ADT= 3.81 ART= 3.12 AST= .69 . Total Hours on Bit #7 TST=7.51 TRT=10.11TBT=17.62. SPR @ 10,880' MD - 6,535' TVD.-MW - 9.2 ppg. #1pump 20 spm-550psi.30spm-740 psi.#2 pump 20 spm-550psi.30 spm-720psi. GEO-Very fine Sand and traces of Siderite. Drill 6 3/4" OH F/11063 MD T 111439' MD, TVD 6,586' Up wt =180, Dn wt = 135, RT wt =160, Tq on btm 7k, Torq off btm 5k, WOB 5-15k, Rpm 55, Pump Pressure = 2,750 psi. off Btm, 3,100 psi. on Btm @ 335 9pm. Jar hrs 60.76, ADT= 3.81 ART=2.61 AST= .60 APIG= 72.36' per hr. - 1,809' - 25 hrs. . Pump Out Of Hole F/11 ,439' - T 19,575', Monitior well, Service Blocks, Wash Pipe Trip in hole T/11 ,441 and record SPR. Wash to btm. Drill 6 3/4" OH F/11 ,439' MD T 112,125' MD, TVD 6,550' Up wt =190, Dn wt = 130, RT wt =155, Tq on btm 9k, Torq off btm 5-6k, 'WOB 5-15k, Rpm 55, Pump Pressure = 2,980 psi. off Btm, 3,240 psi. on Btm @ 335 gpm. JAR HRS 69.58, ADT= 3.81 ART= 3.12 AST= 1.35 APIG= 72.32' per hr. - New hole 2495' -34.5 hrs. Drill 6 3/4" OH F/11,439' MD T 112,336' MD, TVD 6,550'Up wt =190, Dn wt = 125, RT wt =155, Tq on btm 9k, Torq off btm 5-6k, WOB 5-15k, Rpm 55, Pump Pressure = 3000 psi. off Btm, 3,200 psi. on Btm @ 338 gpm.JAR HRS. 72.58, ADT= 3.01 ART= 1.58 AST= 1.43 APIG= 66.81' per hr. - New hole 2,706' -40.5 hrs. Drill 6 3/4" OH F/11 ,439' MD T 112,933' MD, TVD 6,542'Up wt =205, Dn wt =120, RT wt =155, Tq on btm 9k, Torq off btm 7-6k, WOB 5-15k, Rpm 60, Pump Pressure = 3160 psi. off Btm, 3,450 psi. on Btm @ 338 gpm.JAR HRS. 80.05 ADT= ---- ART= --AST= --- APIG= 56.46' per hr. - New hole 3,303' -58.5 hrs. Work Pipe and Circ,F 112,933' - T/12,469', Out of C sands seeing low resistivity and shale in samples Look at the Geology and discuss Team Leaders, Decision made to side track. Side Track - Start troughing F/12,560' - T/12,595' Start Time Drillin9 at 112,595' - T/12,604' 156r Drill and survey 6-3/4" OH from 12,605' MD ( 6,558' TVD ) to 13,508' MD ( 6,499' TVD ). AST = 3.94 hrs, ART = 5.62 hrs, ADT = 9.56 hrs. Printed: 7/512005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1 C-21 ROT - DRILLING D15CM@conocóphillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/712005 00:00 - 18:00 18.00 DRILL DRLG PROD Avg. ROP = 95 fph. Up wt. 205K, SOW 125K, ROT Wt 160K. Tq on Btm 10K, Tq off Btm 8K, at 60 rpm. Pump at 80 spm, 335 gpm 3,200 psi. SPR = Pump #1 20 spm 710 psi, 30 spm 950 psi, Pump #2 20 spm 730 psi, 30 spm 1,030 psi. 18:00 - 19:00 1.00 DRILL CIRC PROD HP hose on mud pump failed. Jumper hose on Mud Pump #1 leaked spilling approximately 1 bbl of mud in pump room. Hose was replaced and spill cleaned up. KRU security was notified. No fluid escaped out of containment. PIR completed. 19:00 - 19:15 0.25 DRILL OBSV PROD Monitor well, slight flow observed. 19:15 - 21:45 2.50 DRILL CIRC PROD Circulate and condition mud. Weight up mud to 9.4 ppg for trip. 21 :45 - 22:00 0.25 DRILL OBSV PROD Monitor well, static. 22:00 - 00:00 2.00 DRILL WIPR PROD Pump out of hole from 13,508' MD to 11,722' MD. Good hole conditions. 6/8/2005 00:00 - 03:15 3.25 DRILL WIPR PROD Pump out of hole from 11,722' MD to 9,104' MD. 7-5/8" casing shoe. 03:15 - 03:30 0.25 DRILL OBSV PROD Monitor well, static 03:30 - 05:00 1.50 DRILL CIRC PROD Drop opening ball, pump down at 2 bpm 500 psi. Open CCV with 2,600 psi. Circulate and condition mud until clean returns observed at shakers. 05:00 - 07:00 2.00 RIGMNT RSRV PROD Cut and slip drlg line. Service rig. Monitor well, static. 07:00 - 08:00 1.00 DRILL CIRC PROD Drop closing ball. Pump at 3 bpm 710 psi. Close CCV at 2,800 psi. Pulse test MWD, OK. 08:00 - 09:30 1.50 DRILL TRIP PROD RIH with drill pipe from derrick to 12,096'. 09:30 - 09:45 0.25 DRILL CIRC PROD Fill pipe 80 spm 2,700 psi. Blow down top drive. 09:45 - 11 :30 1.75 DRILL PULD PROD P/U 6 jts drill pipe and 39 jts HWDP from pipe shed. RIH to 13,463. 11 :30 - 12:00 0.50 DRILL CIRC PROD M/U top drive, fill pipe. Record SPR's. Orient Bit. 12:00 - 14:00 2.00 DRILL DRLG PROD Drill and Survey 6-3/4" OH from 13,508' MD ( 6,499' TVD ) to 13,650' MD ( 6,601' TVD ). AST = .57 hrs, ART = 1.1 hrs, ADT = 1.67 hrs. Pump at 340 gpm, 3,010 psi on btm, 2,800 psi off btm. Up wt 210K, SOW 130K, Rt wt 160K. 14:00 - 15:00 1.00 DRILL TRIP PROD Lost 250 psi pump pressure. Trouble shoot pressure loss. Suspect CCV not fully closed. POH, pump out to 13,545' MD. 15:00 - 15:45 0.75 DRILL CIRC PROD Drop opening ball. Pump at 2 bpm. Open CCV at 2,730 psi. 15:45 - 16:45 1.00 DRILL CIRC PROD Drop closing ball. Pump at 2 bpm. Close CCV at 2,650 psi. 16:45 - 17:00 0.25 DRILL TRIP PROD RIH to 13,650'. M/U top drive. Break circulation. Pulse test MWD. OK. 17:00 - 00:00 7.00 DRILL DRLG PROD Drill and Survey 6-3/4" OH from 13,650' MD ( 6,601' TVD ) to 14,149' MD ( 6,567' TVD ). AST = .25 hrs, ART = 3.62 hrs, ADT = 3.87 hrs. Pump at 340 gpm, 3,240 psi on btm, 2,900 psi off btm. Up wt 21 OK, SOW 130K, Rt wt 160K. 60 rpm. Tq on btm = 10K, Tq off btm = 8K. 6/9/2005 00:00 - 00:30 0.50 DRILL DRLH PROD Drill horizontal section. Make connection and pump lube pill 00:30 - 01 :00 0.50 DRILL OTHR PROD Investigate pressure loss. Pressure test surface lines to 4000 psi-Ok I Monitor well-static 01 :00 - 06:00 5.00 DRILL ¡TRIP PROD Pump out of hole from 14149' to 9572' 06:00 - 07:15 1.25 DRILL ¡TRIP PROD Pump out of hole from 9572' to 9100' 07:15 - 08:15 1.00 DRILL CIRC PROD Circulate bottoms up 08:15 - 10:15 2.00 DRILL CIRC PROD Monitor well-slight flow. Circulate and raise mud weight to 9.5 ppg. 10:15 - 12:00 1.75 DRILL TRIP PROD Monitor well-flow reduce but still flowing. RIH to 11515' 12:00 - 13:00 1.00 DRILL TRIP PROD Continue tripping in hole. Tag up @ 12848'. Took check shot survey and confirmed in old hole. 13:00 - 13:30 0.50 DRILL TRIP PROD Pump out of hole to 12545' 13:30 - 15:15 1.75 DRILL CIRC PROD Circulate and condition mud. Insure entire system is weighted up to 9.5 ppg 15:15 -16:30 1.25 DRILL TRIP PROD Monitor well-static. Pump out of hole to 11722'. P/U=190k, S/O=125k Printed: 7/5/2005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/9/2005 16:30 - 20:00 3.50 DRILL TRIP PROD Monitor well-static. Pump out of hole to shoe @ 9153' 20:00 - 20:30 0.50 DRILL CIRC PROD Monitor well, static. Pump dry job. Blow down top drive. 20:30 - 00:00 3.50 DRILL TRIP PROD POH on elevators to HWDP. Proper hole fill observed. Break out and lay down CCV. Inspect circ sub. Internal valve washed out. 6/10/2005 00:00 - 00: 15 0.25 DRILL OBSV PROD Monitor well, Static 00:15 - 01:30 1.25 DRILL TRIP PROD POH, stand back HWDP, Jars, and flex drill collars. 01 :30 - 01 :45 0.25 DRILL SFTY PROD PJSM on removing source from LWD tool. 01 :45 - 02:00 0.25 DRILL PULD PROD HES crew removed source from LWD tool. 02:00 - 03:00 1.00 DRILL SURV PROD Download MWD tool. 03:00 - 03:45 0.75 DRILL PULD PROD I Stand back MWD tool, break out and lay down bit and motor. 03:45 - 04:45 1.00 DRILL PULD PROD Latch up MWD tool. Make service breaks and lay down tool in pipe shed for battery change out. 04:45 - 05:30 0.75 DRILL PULD PROD Drain BOP stack, P/U test jt. M/U wear ring retrieving tool. Pull wear ring. M/U test plug and set in wellhead. 05:30 - 06:30 1.00 DRILL RIRD PROD RIU BOPE test equipment. Fill stack and choke manifold with water. 06:30 - 10:00 3.50 WELCTL BOPE PROD Test BOPE per CPAI & AOGCC procedures. Test pressures 250 low and 3,500 hi as per Drilling Permit. Test charted and witnessed by CPAI Drilling Rep and DDI Tool Pusher. Chuck Scheve, AOGCC PI, waived witnessing test. 10:00 - 11 :00 1.00 DRILL RIRD PROD Pull test plug, set wear ring. Monitor well, static. 11 :00 - 13:00 2.00 WELCTL BOPE PROD Pressure test all valves on choke manifold to 250/3,500 psi. Blow down choke maniflod. Line up valves for drilling. 13:00 - 14:00 1.00 RIGMNT RSRV PROD Service rig. Change oil in top drive unit. 14:00 - 15:00 1.00 RIGMNT RSRV PROD Change out top drive saver sub. 15:00 - 15:15 0.25 DRILL SFTY PROD PJSM on picking up BHA # 8. 15:15 - 20:00 4.75 DRILL PULD PROD M/U BHA # 8. 20:00 - 22:00 2.00 DRILL PULD PROD M/U MWD tool. Failed surface test. Change out MWD tool. Retest at surface .OK. 22:00 - 22:30 0.50 DRILL PULD PROD Load sources in LWD Tool, RIH flex collars, HWDP, and jars. 22:30 - 00:00 1.50 DRILL TRIP PROD RIH with dp to 3,203' MD. M/U top drive. Fill drill pipe. Shallow test MWD tool, OK. 6/1112005 00:00 - 01 :00 1.00 DRILL TRIP PROD RIH with BHA # 8 to 6,008'. Stop to take check shot with MWD tool. 01 :00 - 01: 15 0.25 DRILL SURV PROD Unable to take check shot with MWD. Cycle pumps. Surface computer problem. MWD operator reestablished communication with MWD tool. Check shot OK. 01 :15 - 02:45 1.50 DRILL TRIP PROD RIH with BHA # 8 to 9,279' 02:45 - 04:00 1.25 DRILL CIRC PROD Circulate and condition mud at 7-5/8" casing shoe. Observed 35% increase in cuttings at btms up. Continue to circulate until clean returns observed at surface. 04:00 - 04:15 0.25 DRILL OBSV PROD Flow check, well static. Take SPR's for both pumps. 04:15 - 05:15 1.00 DRILL TRIP PROD RIH to 9,780'. Stop and take check shot with MWD. Inadvertently entered old wellbore. POH. Reorient BHA. Enter correct wellbore. Continue to RIH 05: 15 - 07:00 1.75 DRILL TRIP PROD RIH with BHA # 8 to 12,545'. Hole in good condition. 07:00 - 07:45 0.75 DRILL CIRC PROD Circulate and condition mud at 12,545'. Rotate and reciprocate pipe. Observed clean returns at btms up. 07:45 - 08:00 0.25 DRILL OBSV PROD Flow check well, static. 08:00 - 08:30 0.50 DRILL TRIP PROD RIH with BHA # 8 to 13,732'. Hole in good condition. 08:30 - 09:15 0.75 DRILL REAM PROD Precautionary wash and ream to btm at 14,149'. Hole in good condition. 09:15 - 10:15 1.00 DRILL CIRC PROD Circulate and condition mud at 14,149'. Rotate and reciprocate pipe. Observed clean returns at btms up. 10:15-18:00 7.75 DRILL DRLG PROD Drill and survey 6-3/4" OH from 14,149' MD (6,567' TVD ) to 14,288' MD ( 6,558' TVD ). Raise lubrication concentration in mud to 4% to help Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/11/2005 10:15 - 18:00 7.75 DRILL DRLG PROD with sliding difficulties. Unable to get proper weight transfer through drill string to bit due to hole geometry. AST = 2.29 hrs, ART = .53 hrs, ADT = 2.82 hrs. Up wt. 210K, SOW 120K, Rot wt. 162K. Pump 80 spm, 340 gpm, 3,240 psi on btm, 3,010 psi off btm. ROT 60 rpm, 10K tq on btm, 8K tq on btm. Discuss options with Drilling Team Lead, Drilling Engineer, and Geologists. Decision made to trip for Lo-tads. 18:00 - 19:00 1.00 DRILL CIRC PROD Circulate and conditon mud. 19:00 -19:15 0.25 DRILL OBSV PROD Flow check well, slight flow observed. 19:15 - 20:30 1.25 DRILL CIRC PROD Circulate and condition mud. Raise mud weight to 9.5 ppg for trip. 20:30 - 20:45 0.25 DRILL OBSV PROD Flow check well, static. Take SPR's for both pumps. 20:45 - 00:00 3.25 DRILL TRIP PROD POH on elevators from 14,288' to 10,705'. 6/12/2005 00:00 - 01 :45 1.75 DRILL TRIP PROD Pump out of hole to 9,285'. 01 :45 - 02:45 ì 1.00 DRILL CIRC PROD Circulate and condition mud at 7-5/8" casing shoe. 02:45 - 03:00 I 0.25 DRILL OBSV PROD Flow check well. Static. Pump dry job. 03:00 - 04:45 1.75 DRILL TRIP PROD POH on elevators to 6,101' 04:45 - 08:45 4.00 DRILL TRIP PROD RIH to 9,099', installlo-tads on each stand. 08:45 - 09:00 0.25 DRILL CIRC PROD Fill pipe, Blow down top drive. ,09:00 - 10:30 1.50 RIGMNT RSRV ì PROD Cut and slip 86' drilling line. Inspect break bands on drawwork drum. 10:30 - 11 :30 1.00 RIGMNT RSRV PROD Service rig and top drive. 11 :30 - 16:00 4.50 DRILL TRIP PROD RIH to 14,288'. Install total of 60 lo-tads. Hole in good condition. 16:00 - 18:00 2.00 DRILL CIRC PROD Circulate and condition mud. Observed 5,000 units gas at btms up. I Circulate until clean returns observed at surface. 18:00 - 00:00 6.00 I DRILL DRLH PROD Drill and survey 6-3/4" OH from 14,288' MD (6,558' TVD) to 14,392' MD ( 6,561' TVD). AST = .81 hrs, ART = 1.44 hrs, ADT = 2.25 hrs. Up wt. 210K, SOW 120K, Rot wt. 162K. Pump 80 spm, 340 gpm, 3,240 psi on btm, 3,010 psi off btm. ROT 60 rpm, 1 OK tq on btm, 8K tq on btm. 6/13/2005 00:00 - 00:00 24.00 DRILL DRLH PROD Drill and survey 6-3/4" Horizontal OH section from 14,392' MD (6,561' TVD) to 14,857' MD (6,546' TVD). AST = 6.71 hrs, ART = 3.21 hrs, ADT = 9.92 hrs. Up wt. 215K, SOW 115K, Rot wt. 168K. Pump 80 spm, 340 gpm, 3,560 psi on btm, 3,250 psi off btm. ROT 60 rpm, 12K tq on btm, 10K tq on btm. 6/14/2005 00:00 - 01 :00 1.00 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 14,857' MD to I 14,950'MD (6,545' TVD). ART = .87 hrs 01 :00 - 01 :30 0.50 DRILL CIRC I PROD Gas units at 5,000. Circulate and work pipe until gas units below 500. Make connection. Take survey. 01 :30 - 02:00 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 14,950' MD to 14,971' 1.50 I DRILL I MD ( 6,546' TVD ). ART = .18 hrs 02:00 - 03:30 DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in ì attempt to slide. 03:30 - 03:45 0.25 DRILL DRLH PROD Slide at 150 R from 14,971' MD to 14,979' MD. AST = .10 hrs Rotary Drill 6-3/4" hole f/14,979' to 15,011' MD (6546' TVD) ART=.17 hrs. 03:45 - 05: 15 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tool face and slide to bottom. 05: 15 - 05:30 0.25 DRILL !OBSV PROD Flow check well. Static. Take SPR's. 05:30 - 09:30 4.00 DRILL ¡TRIP PROD POH, circulate and back ream out to 12,855' MD to reposition push pipe in drill string. 09:30 - 11 :00 1.50 DRILL TRIP PROD RIH on elevators to 14,320' MD. 11 :00 - 13:30 2.50 DRILL REAM PROD M/U top drive. Wash and ream from 14,320' MD to 15,011' MD. Pump at 80 spm, 3,560 psi, Up wt. 220K, Dn wt. 11 0-115K, Rt wt. 165K. 13:30 - 15:00 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tool face and slide to bottom. 15:00 - 17:00 2.00 DRILL CIRC PROD Mix up 50 bbl Lube pill. Add in 5 ppb Alpine tine glass beads. Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/14/2005 17:00 - 17:30 0.50 DRILL DRLH PROD Pump lube pill with beads. Work pipe, orient string in attempt to slide. Observed large volume of cuttings at btms up. Shakers blinded off for several minutes. 17:30 - 18:00 0.50 DRILL DRLH PROD Slide at 160 R from 15,011' MD to 15,034' MD. AST = .30 hrs 18:00 - 19:00 1.00 DRILL IDRLH PROD Slide at 180 from 15,034' MD to 15,047' MD. AST = 1.00 hrs 19:00 - 20:00 1.00 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 20:00 - 21 :30 1.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,047' MD to 15,139' : MD ( 6,544' TVD ). ART = 1.43 hrs 21 :30 - 22:00 0.50 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 22:00 - 22:30 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,139' MD to 15,160' MD ( 6,544' TVD ). ART = .40 hrs 22:30 - 23:15 0.75 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tool face and slide to bottom. Pump lube pill with beads. Work pipe, orient string in attempt to slide. 23:15 - 00:00 0.75 DRILL DRLH PROD Slide at 180 from 15,160' MD to 15,183' MD ( 6,545' TVD ). AST = .75 hrs 6/15/2005 00:00 - 00:30 0.50 DRILL DRLH PROD Slide at 180 from 15,183' MD to 15,190' MD ( 6,545' TVD ). AST = .50 hrs 00:30 - 01 :15 0.75 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,190' MD to 15,233' MD ( 6,546' TVD ). ART = .65 hrs 01: 15 - 01 :30 0.25 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 01 :30 - 02:00 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,233' MD to 15,326' , MD ( 6,545' TVD ). ART = .45 hrs 02:00 - 02:20 0.33 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 02:20 - 03:00 0.67 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,326' MD to 15,419' I MD ( 6,545' TVD ). ART = .55 hrs 03:00 - 03:30 I 0.50 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 03:30 - 03:45 0.25 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,419' MD to 15,439' MD ( 6,545' TVD ). ART = .15 hrs 03:45 - 04:00 0.25 DRILL DRLH PROD Slide at 180 from 15,439' MD to 15,450' MD ( 6,537' TVD ). AST = .35 hrs 04:00 - 05:30 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in I attempt to slide. Unable to hold tool face and slide to bottom. 05:30 - 06:00 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,514' MD to 15,450' MD ( 6,537' TVD ). ART = .45 hrs 06:00 - 06:30 0.50 DRILL DRLH 'PROD Wash and ream full stand. Make connection. Take survey. 06:30 - 10:30 I 4.00 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,514' MD to 15,603' ! MD ( 6,535' TVD ). ART = 3.50 hrs I I 10:30-11:301 1.00 RIGMNT RGRP PROD HP hose on mud pump failed. Jumper hose on Mud Pump #2 leaked spilling approximately 25 gals of mud in pump room. Hose was replaced and spill cleaned up. KRU security was notified. No fluid escaped out of containment. PIR completed. 11 :30 - 12:30 1.00 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 12:30 - 15:00 2.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,603' MD to 15,634' MD ( 6,528' TVD ). ART = 2.50 hrs. TD horizontal section as per onsite geologist. Up wt. 215K, Dn wt. 120K. 15:00 - 15:30 0.50 DRILL CIRC PROD Wash and ream full stand. Make connection. Take survey. 15:30 - 00:00 8.50 DRILL REAM PROD BROOH from 15,634' to 12,186'. Hole taking fluid. Lost a total of 110 bbls. Reduced pump rate from 80 spm to 50 spm to reduce loss rate. Hole in good condition. Pulling pipe at 8-10 min per stand. 6/16/2005 00:00 - 02:45 2.75 DRILL REAM PROD BROOH from 12,186' to 11,415'. Observed torque fluctuation from 11,500' to 11,440', 6K to 12K torque while back reaming. Work pipe, torque at 6K. Rack back stand. Up wt. 190K, Dn wt 130K. Lost 45 bbls Printed: 7/5/2005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/16/2005 00:00 - 02:45 I 2.75 DRILL REAM PROD of mud to hole. 02:45 - 06:00 . 3.25 DRILL REAM PROD M/U top drive. Break circulation. Unable to move drill string up or down. Work pipe at 11,415'. No jar action. Mix and pump 65 bbllube/bead pill. Pump at 215 gpm 1,700 psi. 06:00 - 08:00 2.00 DRILL REAM PROD Regain jar action. Work pipe at 11,415'. Mix and pump 35 bbl 15% I concentration lube pill. Spot pill around BHA. i 08:00 - 08:45 0.75 DRILL REAM ! PROD Shut down pumps, allow pill to soak. S/O to 65k wI no torque in string. 08:45 - 09:30 0.75 DRILL REAM PROD P/U on drill string to 250K allow jars to fire upward. Regain pipe movement. Rotate and reciprocate pipe. 09:30 - 17:30 8.00 DRILL REAM PROD BROOH from 11,390' to 9,153'. Mix and pump 45 bbl sweep. Record up and down weights every 5 stands. Up wt 180K Dn wt 140K. Pump 315 gpm 75 spm at 2,525 psi. Lost 43 bbls of mud to hole. 17:30 - 19:45 2.25 DRILL CIRC PROD Circulate and condition mud. Mix and pump 45 bbl sweep. Observed 15% increase in cuttings at btms up. Continue to circulate until clean returns are observed at shakers. 19:45 - 20:00 0.25 DRILL OBSV PROD Flow check well, Static. 20:00 - 20: 15 0.25 DRILL CIRC PROD Pump dry job. Blow down top drive. 20:15 - 00:00 3.75 DRILL TRIP PROD POH drill pipe on elevators to 680'. Hole taking correct displacement. 6/17/2005 00:00 - 01 :00 1.00 DRILL PULD PROD Stand back HWDP. Lay down jars. Stand back flex DC's. 01 :00 - 01 :15 0.25 DRILL SFTY PROD PJSM on removing source from LWD. 01 :15 - 02:00 0.75 DRILL PULD PROD Remove source from LWD. 02:00 - 03:00 1.00 DRILL SURV PROD Down load MWD tool. 03:00 - 04:00 1.00 DRILL PULD PROD Lay down MWD/LWD tools. 04:00 - 05:45 1.751 DRILL PULD PROD Inspect Bit. Rerun. Set motor at 1.22 deg. M/U MWD tool. Orient BHA. 05:45 - 07:00 1.25 DRILL ¡TRIP PROD M/U BHA # 9, RIH to 400'. Shallow test MWD, OK. 07:00 - 07:30 0.50 RIGMNT OTHR PROD Inspect Derrick. OK 07:30 - 11 :00 3.50 DRILL TRIP PROD RIH with BHA # 9 for clean out. Take up and down weight readings ,every 5 stands. 11 :00 - 11 :30 i 0.50 DRILL SURV PROD M/U Top drive. Pulse test MWD at 7,025. Blow down top drive. 11 :30 - 12:30 1.00 DRILL TRIP PROD RIH to 7-5/8" casing shoe at 9,153' with BHA # 9 for clean out. Take up and down weight readings every 5 stands. 12:30 - 13:00 0.50 DRILL CIRC PROD Circulate and condition mud. Pump at 300 gpm, 70 spm 1,950 psi. Up wt 183K, Dn wt 145K. ROTwt 152K. Torque offbtm 4K. 13:00 - 18:45 5.75 DRILL TRIP PROD RIH to 15,579' with BHA # 9 for clean out. Take up and down weight readings every 5 stands. Hole in good condition. 18:45 - 19:00 0.25 DRILL REAM PROD M/U top drive. Wash and ream to btm at 15,634' 19:00 - 20:45 1.75 DRILL CIRC PROD Circulate and condition mud. Observed 2,500 units of gas at btms up. Circulate until gas below 200 units. 20:45 - 23:00 2.25 DRILL CIRC PROD Mix and pump 60 bbl hi-vis sweep at 9.7 ppg, 85 seclot. Observed 10% increase in cuttings at shakers when sweep returns to surface. i Circulate until clean returns are observed at surface. 123:00 - 23:15 0.25 DRILL SFTY PROD PJSM on switching over to solids free mud system. 23: 15 - 00:00 0.75 DRILL CIRC PROD . Displace old mud out of hole. Replace with 9.7 ppg solids free mud system. 6/18/2005 00:00 - 03:30 3.50 DRILL CIRC PROD Displace well to 9.7 ppg solids free flo-pro mud system. 03:30 - 03:45 0.25 DRILL OBSV PROD Flow check well, static. Take SPR's. 03:45 - 11 :30 7.75 DRILL WIPR PROD Pump out of hole from 15,634' to 7-5/8" casing shoe. Hole in good condition. 11:30 -12:45 1.25 DRILL CIRC PROD Circulate and condition mud. Pump at 70 spm 1,650 psi. Up wt 175K, Dn wt 145K. 12:45 - 13:00 0.25 DRILL OBSV PROD Flow check well, static. Mix and pump dry job. 13:00 - 18:00 5.00 DRILL TRIP PROD POH with drill pipe on elevators. Hole took proper displacement. Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/18/2005 18:00 - 19:00 1.00 I DRILL PULD PROD Lay down BHA # 9. 19:00 - 19:45 0.751 DRILL PULD PROD Flush out mud motor. Break out and lay down float sub, mud motor, and 6-3/4" PDC bit. 19:45 - 20:15 0.50 DRILL PULD CMPL TN Clear rig floor. 20:15 - 21:45 1.50 CASE RURD CMPL TN RIU GBR casing tools. Layout running order in pipe shed for 4-112" liner. 21 :45 - 22:00 0.25 CASE SFTY CMPL TN PJSM with rig crew and service personnel on running 4-112" casing liner. 22:00 - 00:00 2.00 CASE PULR CMPL TN RIH with 4-112" 12.6 ppf L-80 IBT slotted and blank casing liner. Space out swell packers. 6/19/2005 00:00 - 04:30 4.50 CASE PULR CMPL TN RIH 4-112" 12.6 ppf L-80 IBT liner. Ran 169 jts slotted. 39 jts. blank and 4 swell packers. RIH from 3,774' to 6,600. 04:30 - 05:45 1.25 CASE PULR CMPL TN M/U Baker SBR, Flex Hanger, and Tie-Back Sleeve. RIH to 6,660' Change out to drill pipe elevators. Lay Down GBR casing handling equipment. 05:45 - 13:00 7.25 CASE RUNL CMPL TN RIH with 4-112" liner on drillpipe. Running speed 90 see per stand. 13:00 - 16:30 3.50 CASE RUNL CMPL TN . Hole condition deteriorating. Hole sticky. Work pipe. Up wt 200K, Dn wt 115K. Work 4-1/2" liner to btm at 15,634' 16:30 - 18:00 1.50 CASE DEQT CMPL TN Drop setting ball down drillpipe. Pressure up to 4,600 psi set hanger and packer. Release running tool from hanger. P/U Wt 180K. 18:00 - 19:00 1.00 CASE DEQT CMPL TN Close annular. Pressure up and test liner top packer to 1,500 psi. Hold test pressure for 15 min. OK. Bleed off pressure. RID test chart recorder. 19:00 - 19:30 0.50 DRILL PULD CMPL TN Pull one stand of drillpipe. Blow down top drive. 19:30 - 20:30 1.00 RIGMNT RSRV CMPL TN Cut and slip 129' drilling line. 20:30 - 21 :30 1.00 RIGMNT RSRV CMPL TN Service top drive and crown. 21 :30 - 21 :45 0.25 DRILL OBSV CMPL TN Flow check well. Static 21 :45 - 22:15 0.50 DRILL TRIP CMPL TN Mix and pump dry job. Blow down top drive. Reset crown-o-matic. 22:15 - 00:00 1.75 DRILL TRIP CMPL TN POH, lay down 4" drillpipe at 6,738'. 6/20/2005 00:00 - 09:00 9.00 DRILL PULD CMPL TN POH, lay down 4" drill pipe and lo-tads from 6,738' to surface. 09:00 - 09:30 0.50 DRILL PULD CMPL TN Break out and lay down Baker liner hanger running tool. 09:30 - 12:00 2.50 DRILL TRIP CMPL TN RIH with 13 stands of HWDP and 57 stands 4" drill pipe to 6,500'. 12:00 - 12:30 0.50 DRILL IPULD CMPL TN POH, lay down 4" drill pipe to 6,400'. 12:30 - 13:30 1.00 DRILL ICIRC CMPL TN M/U top drive. Circulate and condition mud. Mix and pump dry job. Blow down top drive. 13:30 - 18:00 4.50 DRILL IpULD CMPL TN POH, lay down 4" drill pipe from 6,400' to 1,200'. 18:00 - 19:00 1.00 DRILL iPULD CMPL TN POH, lay down 4" HWDP from 1,200' to surface. 19:00 - 19:30 0.50 DRILL IRIRD CMPL TN Clear rig floor of all drill pipe handling equipment. 19:30 - 19:45 0.25 DRILL i RIRD CMPL TN Pull wear ring from wellhead. 19:45 - 20:30 0.75 CMPL TNI RURD CMPL TN RIU GBR tubing handling equipment. Layout running order in pipe I shed for 4-1/2" completion. 20:30 - 20:45 0.25 CMPL TNI SFTY CMPL TN PJSM with rig crew and service company personnel on running 4-112" I ; completion. 20:45 - 00:00 3.25 CMPL TN! PULD CMPL TN P/U Baker seal assembly, RIH with 4-1/2" 12.6 ppf L-80 IBT tubing and completion equipment to 4,290' 6/21/2005 00:00 - 03:30 3.50 CMPL TN RUNT CMPL TN Run 4 1/2 TBG. 03:30 - 04:30 1.00 CMPL TN SOHO CMPL TN Space Out test seals 500psi. confirm seal set. 04:30 - 07:30 3.00 CMPL TN CIRC CMPL TN RIU and Displace well W/9.5 ppg. Brine.@ 45spm 250 psi. 07:30 - 09:30 2.00 CMPL TN SOHO CMPL TN M/U hanger & Land Tbg. Press test annulus T/1500 psi. 15 min. Press up To 2,900psi shear RP valve. 09:30 - 10:00 0.50 CMPL TN OTHR CMPL TN UD landing Jt. Set BPV. 10:00 - 17:00 7.00 CMPL TN NUND CMPL TN Change Rams to 4_112" X 7" & 5". Nipple down BOPE 17:00 - 19:30 2.50 CMPL TN SEQT CMPL TN Nipple up adapter flange and Production Tree. Test pack off to Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/21/2005 17:00 - 19:30 2.50 CMPL TN SEQT CMPL TN 19:30 - 22:00 2.50 CMPL TN SEQT CMPL TN 22:00 - 00:00 2.00 CMPL TN CIRC CMPL TN 6/22/2005 00:00 - 03:00 3.00 CMPL TN FRZP CMPL TN 03:00 - MOVE DMOB CMPL TN 5,000psi. Test Good. Pull BPV and install two way check, Trouble Pulling BPV through Actuator Valve, Function valve and work past. Test Tree to 25010w , 5,000psi. high, Good Test. RIU and pump Brine with Inhibitor, total 260 bbls, @ 3bpm 1,050 psi. _ Freeze Protect, Tbg,x7 5/8" 2,000' Set BPV. 280psi. on tbg. and annulus, Injectivity test and freeze Protect 7 5/8"x10 3/4" 2,000' After injecting 82 bbls 875psi. on Annulus. Secure Well and Release Rig @ 03:30. Printed: 7/512005 4:13:27 PM HALLIBURTON Sperry Drilling ServIces -750- 0- 750- 1500- 2250 - '2 :§ o o .,., ~ 3000- '5. '" Q ~ ~ 3750- > - '" .g 4500- 5250- 6000- 6750- 7500- -750 1 I o I I I 1 1 -750 I I I +NI-S +EI-W 0.00 0.00 I I I 750 I I I I I 3750 I I I 1 I 1500 1.1 I I I 2250 I 1 I 3000 I I I I I ~ 1 I I I o I 1 I I I 750 I 1 I I I 3000 I I I I I 1500 I I I I I 2250 WELL DETAILS: Plan: 1C-21 Northing 5968637.75 Ground Level: 60.30 Easting Latittude 562198.12 70019'29.434N Longitude 149°29'44.342W Vertical Section at 109,74' (1500 Win) 4500 5250 6000 6750 7500 I I I 1 I I I I 1 I I I I 1 I I I I 1 I I I I I I I I 8250 I 1 I I I REFERENCE INFORMATION Co-ordlnate (N/E) Reference: Well Plan: 1 C-21 , True North Vertical (TVD) Reference: 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) Section (VS) Reference: Slot - (O.OON, O.ODE) Measured Depth Reference: 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) Calculation Method: Minimum Curvature LEGEND -A- Plan: 1C-21, 1C-21L1, 1C-21L1 VO ~ Plan: 1C-21 , )C-21L3, 1C-21L3 VO "'* Plan: 1C-21 , 1C-21L2, 1C-21L2VO -A- 1C-21 11C-21L1 (0-10336) I 9000 I I I [1C-21L2 (9986-10408) [ 11C-21L3 (9618-12933) I o 0:> 75/8" -.d.... -" I I I I I 3750 I 1 I I I I 1 I I I I I I I I I 1 I I I I I I 4500 5250 6000 6750 7500 Vertical Section at 109.74° (1500 fllin) I I I 1 I I I 8250 I 1 I 9000 .~ CônOcóPhilllps AIm Slot 1C-21 9750 I I I 1 I 10500 11250 12000 12750 I I I I I I I I I I I I I 1 I I I I 1 I --750 -0 . -750 -1500 - 2250 ::;I c: CD ~ ;:¡. ::- 3000 hi a CD ~ -3750 ~ 0 0 ~ 2- -4500 . 11=(12511~ -5250 -6000 -6750 -7500 I I I I I 9750 I I I 1 I I I I I I I I I 1 I I I I 1 ,- 10500 11250 12000 12750 +N/·S +EI·W 0.00 0.00 WELL DETAILS: Plan: 1C-21 (wp11) Extension Ground Level: 60.30 Northing Eastlng Latlttude Longitude 5968637.75 562198.12 70019'29.434N 149"29'44.342W ConocÒPhilliþs AJæka HALLIBURTON Ipeny Drlln... "rvle.. Slot 1C.21 ReFeReNce INFORMATION Co-ordinate (NJe¡ Reference: Wèll Plan: 1C-21, True North Vertical (lVO Reference: 10-21 Actual @ 101.8Oft (Doyon 14 (41.6...e0.3» Section (VS) Reference: Slot - (Q.QON, o.ooe) Measured Depth Reference: 1C-21 Actual@101.8011(Doyon 14 (41.6+60.3» calculation Method: Minimum Curvature LEGEND . -+- Plan: 10.21, 1C-21L1, 1o.21L1 VO ""*" Plan: 10.21, 1C-21L3, 1o.21L3 va -h:- Plan: 10.21, 1C-21L2, 1o.21L2VO -a- 10.21 5625- j 1 C·21 L 1 «()'10336) I . \ j1C-21L2 (9986-10408) I 1C.21L3 (9618-12933) I ~ 'ê" ~ - ~ 6000-: t c _ 1'! 6375- ~ \! - co 7 516" :> -'...- ell _~ ~ - 6750- 1C.21 (12511·15634) I . I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ) I I I I I I I I I I I I I I I I 5625 6000 6375 6150 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 11625 12000 12375 Vertical Section 81109.74· (750 ftlin) COnocJ'Phillips AJas'ka Slot 1 C-21 extension Longitude 149°29'44.342W (Wp11 ) Ground Level~ 60.30 El$tlng Latlttude 562198.12 70019'29.434N WELL DETAILS:. Plan: 1C-21 Northing 5968837.75 +N/-S +EI-W 0.00 0.00 HALLIElUATaN ape..., DrllUnv Servlc.. REFERENCE INFORMATION Co-Qrdlnafe (N/E) Reference: Well Plan: 1C-21. True North Vertical (rvD) Reference: 10-21 Actual @ 101.8Oft (Doyon 14 (41.5+80.3)' Section (VS) Reference: Slòl. (O.OON. O.OOE) Measured Depth Reference: 1C-21 Actual@ 101.8Oft (Doyon 14 (41.6+60.3) Calculation Method: Minimum Curvature . - 6650- 1C-21 (12511-15634) - - - - 6700 , I ' , I , I I 1 '/1"'/""/"11/ I I ' I ' , I' I' , , , (' , , , I I " , f ' , I I I I I I I I I 11 I I I I II , I ' 6000 6050 6100 6150 6200 6250 6300 6350 6400 6450 6500 6550 6600 6650 6700 6750 6800 6850 6900 6950 Vertical Section at 109.74° (100 fIIln) . 1C-21L1 (0.10336) 1C-21L2 (9986-10408) LEGEND C-21L1, 1C-21L 1 VO 1C-21L3, 1C·21L3 VO 1 C-21L2, 1C-21L2 VO 1C-21 1C-21 1C-21 Plan: Plan: Plan: 1C-21 -+- "*" -å- ..g.. 6400- 1C·21L3 - 6450- - '2 - ;¡æ 6500- ß : :§. : ~ 6S50- ~ : ~ - ~ 6600"': F _ eonoc:d'Pbillips I Alaska I . I Project Kuparuk River Unit Site: Kuparuk 1CPad Well: Plan: 1C-21 Wellbòre: 1C-21 Design: 1C-21 Sperry Drilling Services 1750- 875- 0- -875- '2 -1750- ~ - o 10 t-. ~ -2625- +' ':E: 1:: o _ ~ -3500- ¿ :5 :J o CI) -4375- -5250- -6125- -7000- -7875- HALLIBURTON ì . 11C-21 (12511-15634) I . LEGEND T ^ M Azimuths to True North ¿Magnetic North: 24.34' Magnetic Field Strength: 57604.3nT Dip Angle: 60.77' Date: en /2005 Model: BGGM2004 -&- Plan: 1C-21 , 1C-21L1,1C-21L1 VO -f- Plan: 1C-21 , 1C-21L3, 1C-21L3VO -e- Plan: 1C-21 , 1C-21L2, 1C-21L2VO -&- 1C-21 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -875 0 875 1750 2625 3500 4375 5250 6125 7000 7875 8750 9625 10500 11375 12250, 13125 14000 14675 West(-)Æast(+) (1750 ftlin) Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 C 1 C-21 . Job No. AK-ZZ-3706651, Surveyed: 15 June, 2005 Survey Report 6 July, 2005 Your Ref: API 500292325300 Surface Coordinates: 5968637.75 N, 562198.12 E (70019' 29.4336" N, 149029' 44.3424" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 968637.75 N, 62198.12 E (Grid) Surface Coordinates relative to Stucture Referance: 116.73 N, 172.97 W (True) Kelly Bushing Elevation: 101.80ft above Mean Sea Level Kelly Bushing Elevation: 101.80ft above Project V Reference Kelly Bushing Elevation: 101.80ft above Structure Referance spe..........y-sul! DAILLING seAVlces A Halliburton ComP1'ny Survey Ref: svy2171 Halliburton Sperry-Sun Survey Report for Kuparuk 1C . 1C-21 Your Ref: API 500292325300 Job No. AK-ZZ-3706651, Surveyed: 15 June, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12510.99 85.480 97.400 6452.98 6554.78 3068.04 S 8424.68 E 5965639.65 N 570647.95 E 8965.85 Tie-On Point 12595.00 89.480 98.960 6456.67 6558.47 3079.98 S 8507.74 E 5965628.39 N 570731.10 E 5.110 9048.05 Window Point 12604.89 88.760 99.220 6456.82 6558.62 3081.54 S 8517.50 E 5965626.91 N 570740.87 E 7.740 9057.77 12693.26 91.040 109.190 6456.98 6558.78 3103.20 S 8603.06 E 5965605.97 N 570826.60 E 11.573 9145.61 12791.42 88.670 114.310 6457.23 6559.03 3139.56 S 8694.19 E 5965570.36 N 570918.04 E 5.747 9243.67 . 12838.81 89.930 113.420 6457.80 6559.60 3158.73 S 8737.53 E 5965551.55 N 570961.53 E 3.255 9290.93 12884.01 89.380 112.850 6458.08 6559.88 3176.49 S 8779.09 E 5965534.14 N 571003.24 E 1.752 9336.05 12933.50 85.670 112.620 6460.21 6562.01 3195.59 S 8824.69 E 5965515.41 N 571048.99 E 7.511 9385.42 12976.81 85.830 113.520 6463.42 6565.22 3212.52 S 8864.42 E 5965498.82 N 571088.86 E 2.105 9428.54 13031.19 86.290 113.790 6467.16 6568.96 3234.28 S 8914.11 E 5965477.46 N 571138.74 E 0.980 9482.66 13070.59 86.600 113.680 6469.60 6571.40 3250.11 S 8950.11 E 5965461.93 N 571174.86 E 0.835 9521.89 13117.24 86.960 113.030 6472.22 6574.02 3268.58 S 8992.87 E 5965443.83 N 571217.78 E 1.591 9568.38 13163.86 83.660 113.390 6476.03 6577.83 3286.88 S 9035.57 E 5965425.87 N 571260.62 E 7.120 9614.75 13217.08 84.530 113.770 6481.51 6583.31 3308.06 S 9084.09 E 5965405.10 N 571309.31 E 1.782 9667.57 13258.17 84.560 113.580 6485.42 6587.22 3324.49 S 9121.55E 5965388.98 N 571346.91 E 0.466 9708.37 13303.82 85.180 113.920 6489.50 6591.30 3342.80 S 9163.16 E 5965371.02 N 571388.68 E 1.548 9753.73 13349.11 85.910 111.230 6493.02 6594.82 3360.13 S 9204.85 E 5965354.03 N 571430.51 E 6.137 9798.82 13398.14 85.420 111.480 6496.72 6598.52 3377.93 S 9250.39 E 5965336.61 N 571476.19 E 1.121 9847.69 13443.16 88.050 109.830 6499.29 6601.09 3393.78 S 9292.44 E 5965321.10 N 571518.37 E 6.893 9892.63 13507.42 88.550 110.780 6501.19 6602.99 3416.07 S 9352.68 E 5965299.32 N 571578.79 E 1.670 9956.86 13555.31 91.060 109.800 6501.36 6603.16 3432.68 S 9397.59 E 5965283.08 N 571623.84 E 5.626 10004.74 . 13600.06 90.870 108.800 6500.60 6602.40 3447.47 S 9439.82 E 5965268.65 N 571666.19 E 2.274 10049.48 13651.92 91.360 109.680 6499.59 6601.39 3464.55 S 9488.78 E 5965251.97 N 571715.29 E 1.942 10101.33 13692.49 93.560 107.910 6497.85 6599.65 3477.61 S 9527.14 E 5965239.23 N 571753.76 E 6.957 10141.85 13735.20 93.440 106.970 6495.24 6597.04 3490.39 S 9567.81 E 5965226.79 N 571794.53 E 2.215 10184.45 13779.09 94.060 107.570 6492.37 6594.17 3503.39 S 9609.63 E 5965214.13 N 571836.46 E 1.964 10228.20 13827.68 93.790 107.380 6489.05 6590.85 3517.94 S 9655.87 E 5965199.96 N 571882.82 E 0.679 10276.64 13880.14 93.730 107.290 6485.61 6587.41 3533.54 S 9705.84 E 5965184.78 N 571932.92 E 0.206 10328.94 13921.76 93.810 107.370 6482.87 6584.67 3545.91 S 9745.49 E 5965172.74 N 571972.66 E 0.272 10370.43 13972.14 94.410 107.760 6479.26 6581.06 3561.08 S 9793.39 E 5965157.97 N 572020.69 E 1.419 10420.65 14015.40 94.780 107.930 6475.79 6577.59 3574.29 S 9834.44 E 5965145.09 N 572061.85 E 0.941 10463.75 14064.47 94.480 106.800 6471.83 6573.63 3588.89 S 9881.12 E 5965130.88 N 572108.65 E 2.375 10512.61 14123.65 94.700 106.480 6467.10 6568.90 3605.78 S 9937.64 E 5965114.46 N 572165.31 E 0.655 10571.52 14213.11 95.310 105.960 6459.29 6561.09 3630.67 S 10023.21 E 5965090.28 N 572251.08 E 0.895 10660.47 14225.39 94.580 106.300 6458.23 6560.03 3634.07 S 10034.96 E 5965086.98 N 572262.86 E 6.553 10672.68 6 July, 2005 - 17:03 Page 20f4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1C - 1C-21 Your Ref: API 500292325300 Job No. AK-ZZ-3706651, Surveyed: 15 June, 2005 ConocoPhil/ips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 14281.65 92.920 106.570 6454.55 6556.35 3649.96 S 10088.81 E 5965071.54 N 572316.83 E 2.989 10728.72 14317.73 90.390 102.830 6453.51 6555.31 3659.10 S 10123.68 E 5965062.68 N 572351.78 E 12.511 10764.64 14411.38 88.110 103.100 6454.74 6556.54 3680.11 S 10214.93 E 5965042.43 N 572443.20 E 2.452 10857.62 14503.85 88.970 101.930 6457.09 6558.89 3700.14 S 10305.17 E 5965023.15 N 572533.61 E 1.570 10949.32 14597.88 92.960 102.790 6455.51 6557.31 3720.26 S 10396.99 E 5965003.79 N 572625.59 E 4.341 11042.54 . 14690.55 93.220 103.440 6450.52 6552.32 3741.26S 10487.11 E 5964983.54 N 572715.88 E 0.754 11134.46 14783.24 91.870 103.840 6446.40 6548.20 3763.10 S 10577.10 E 5964962.45 N 572806.04 E 1.519 11226.53 14877.02 90.320 104.210 6444.61 6546.41 3785.82 S 10668.06 E 5964940.48 N 572897.19 E 1.699 11319.82 14973.12 91.800 104.310 6442.83 6544.63 3809.49 S 10761.18 E 5964917.59 N 572990.51 E 1.544 11415.46 15066.14 89.960 105.340 6441.40 6543.20 3833.28 S 10851.09 E 5964894.54 N 573080.61 E 2.267 11508.13 15157.29 91.070 105.210 6440.58 6542.38 3857.29 S 10939.01 E 5964871.26 N 573168.73 E 1.226 11598.99 15252.40 90.020 104.240 6439.68 6541.48 3881.47S 11030.99 E 5964847.85 N 573260.91 E 1.503 11693.73 15345.69 91.250 103.840 6438.64 6540.44 3904.10 S 11121.49 E 5964825.97 N 573351.59 E 1.386 11786.55 15439.50 92.670 103.970 6435.43 6537.23 3926.63 S 11212.50E 5964804.19 N 573442.78 E 1.520 11879.82 15531.71 92.790 103.540 6431.04 6532.84 3948.53 S 11301.96 E 5964783.04 N 573532.42 E 0.484 11971.42 15557.63 92.790 103.070 6429.78 6531.58 3954.49 S 11327.15 E 5964777.29 N 573557.66 E 1.811 11997.15 15634.00 92.790 103.070 6426.06 6527.86 - 3971.74 S 11401.46 E 5964760.65 N . 573632.11 E 0.000 12072.91 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). . Vertical Section is from Well and calculated along an Azimuth of 109.740° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15634.00ft., The Bottom Hole Displacement is 12073.44ft., in the Direction of 109.206° (True). 6 July, 2005 - 17:03 Page 3 of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun SUlVey Report for Kuparuk 1C - 1C-21 Your Ref: API 500292325300 Job No. AK-ZZ-3706651, SUlVeyed: 15 June, 2005 ConocoPhillips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12510.99 12595.00 - 15634.00 6554.78 6558.47 6527.86 - 3068.04 S 3079.98 S 3971.74 S 8424.68 E 8507.74 E 11401.46 E Tie-On Point Window Point Projected Survey . Survey tool JroQram for 1 C-21 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 15634.00 6527.86 MWD+IIFR+MS+SAG (1C-21L1) . 6 July, 2005 - 17:03 Page 4 of4 DrillQuest 3.03.06.008 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 1 C-21 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,510.99' MD 12,595.00' MD 15,634.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Jl JO.~ )Jv('\ Signed 1lJ!JiLJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) 14-Jul-05 ) G)- -OY-( ('{:: , l- v I ..... . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-21 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,510.99' MD 12,595.00' MD 15,634.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. AnChorage,;K 99518 /II /1.. BII I Date)1 ~J1"H-' Signed ~_ (//;/;vvf Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 14-Jul-05 ;Z Ò)--ö3'-1 :h' ({. , \ . . .. Note to File KR.U1C-21{2ØS."'(34), KRU IC-2ILI (205-100), KRU IC-2IL2 (205-101), and KRU IC-2IL3 (205-102) ACTION For the sake of clear record keeping, the following names, API numbers and Permit to Drill numbers will be assigned to the vacated portions ofKRU 1C-21: 1. KRU 1 C-21, API Number 50-029-23253-00, Permit to Drill number 205-034: assigned to the well bore segments completed with casing and slotted liner between the surface and the total depth of the well at about 15,573' measured depth ("MD"). 2. KRU 1C-21L1, API number 50-029-23253-60, Permit to Drill number 205-100: assigned to the first vacated well bore segment between 9,605' and 1O,336'MD. 3. KRU 1C-21L2, API number 50-029-23253-61, Permit to Drill number 205-101: assigned to the second vacated well bore segment between 1O,107'and 10,408' MD. 4. KRU 1C-21L3, API number 50-029-23253-62, Permit to Drill number 205-102: assigned to the third vacated well bore segment between 12,511' and 12,933' MD. BACKGROUND The following is a recap of events that occurred during drilling of the KRU 1C-21 well. 1. The Commission issued Permit to Drill 205-034 for the KRU 1C-21 well on March 15,2005. The permitted total depth of the well was 14,147' MD. 2. While drilling, ConocoPhillips Alaska, Inc. ("CP AI") determined that the well bore had exited the top of the reservoir sand into the overlying shale. After reaching a total measured depth of 1 0,336', CP AI pulled back to 10,107' MD (229') and performed an open-hole course correction. This section of vacated well bore opened about 70' of reservoir sand, and it was not plugged back. 3. Due to steering difficulties, the well bore again approached the top ofthe reservoir sand. At 10,408' MD, CP AI pulled back to 9,605'MD (803') and performed a second open-hole course correction without plugging the vacated well bore. This section of vacated well bore lies within the reservoir sand. 4. As drilling continued, CP AI apparently again approached the top ofthe reservoir sand. At 12,933' MD, they pulled back to 12,511' MD (422') and performed a third open-hole course correction without plugging the vacated well bore. This section of vacated well bore apparently lies within the reservoir sand. 5. Based on encouraging drilling results, CPAI sought and obtained verbal approval from the Commission to lengthen the well to a new bottom-hole location that was more than 500' from the permitted bottom-hole location. 6. CP AI submitted a permit to drill application for the revised 1 C-21 bottom-hole location. The requested total depth was changed to 15,573' MD (an additional 1,426'). 7. Commission senior staff instructed CP AI via email to submit permit to a drill application for each vacated well bore segment on June 9, 2005. 8. The Commission issued a revised permit to drill for the KRU 1C-21 well on June 10,2005. }"~ RATIONALE . . The vacated well bore segments open between 70' and 800' of reservoir sand, and they were not plugged. They were not completed, and they are expected to remain open. They will act as open-hole branches of the KRU lC-21 well, and will contribute to production. Commission regulations require that each well branch be given a unique name and an API number. Our databases require that each API number have a corresponding permit to drill number. Commission regulation 25.005(e) requires a separate permit to drill for each well branch, and paragraph (e) specifies that the application for the permit to drill for a well branch need only include information that is unique to that branch. Having unique names, API numbers and permit to drill numbers will ensure proper management ofthe directional data and any MWD data acquired in the vacated well branches. fucluding vacated well branches in our databases is important, especially when conducting Area-of-Review investigations associated with enhanced recovery operations. ~ Steve Davies June 28, 2005 · ~' '~ffit'8' it:"'":::i Œ' rnJ :iþ , Î r-,', " ~.'" ',' ¡ ',' ' ,~ ; !'~ : i 'n\ ! ¡ I [: I ¡.. WU! UW' i.,." - /'r;\\ " 1\\ ,riLl I U-Ü ~u ~ f! \:\,- ,,..,'"J',''¡, , , ' ~ \.:::::../ FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7T" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Drilling T earn Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk lC-21 ConocoPhillips Alaska, Inc. Pennit No: 205-034 (revised) Surface Location: 1600' FNL, 4089' FEL, SEC. 12, TIIN, RI0E, UM Bottomhole Location: 381' FNL, 2293' FWL, SEC. 17, TIIN, RIlE, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit supercedes and replaces the pennit previously issued on March 15, 2005, as pennit to drill number 205-034. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required penn its and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commis_s!~ witness any required test. Contact the Commission's petroleum field inspectorna . rJP; (pager). In y, V DATED this Æ day of June, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . . Note to KRU 1 C-21 Well File (Permit to Drill No. 205-034) To briefly recap events that occurred during drilling of the KRU 1 C-21 well: 1. While ConocoPhillips Alaska, Inc. ("CPAI") was drilling the proposed KRU 1 C-21 well, the wellbore exited the top of the reservoir sand into the overlying shale; 2. CPAI pulled back about 230' and performed an open-hole course correction; 3. due to steering difficulties, the wellbore again approached the top of the reservoir sand; 4. CPAI pulled back 800' and performed a second open-hole course correction; 5. based on encouraging drilling results, CPAI then obtained verbal approval from the Commission to lengthen the well to a new bottom-hole location that is more than 500' from the permitted bottom-hole location; and 6. CPAI submitted this permit to drill application for the new bottom-hole location. The 230' and 800' orphaned wellbore segments will be permitted separately and assigned unique API numbers because they opened 70' and 800' of reservoir, respectively, to the well. Both segments are expected to remain open and contribute to production from KRU 1 C-21. ~~ Steve Davies June 9, 2005 ! Conoc~hillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone(907)265-6830 Email: Randy.L.Thomas@conocophillips.com n ~N- !{'iJ. ¡ ',- ,.' - _~ & 1> .~\",:--- 1\.}' June 8, 2005 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 1C-21 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well, a horizontal well in the Kuparuk "C4/C3" sands. The well will be designated as 1C-21. This well was originally proposed and approved to depth of 14147' MD/6554' 1VD, this application proposes to drill further horizontally to a depth of 15,573' MD/6522' 1VD. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for this well. The spud date of 1C-21 was May 14, 2005. If you have any questions or require any further information, please contact Tim Billingsley at 265-6531. Sincerely, ~ --.....,.,---- Randy Thorn s Greater Kuparuk Area Drilling Team Leader _ STATE OF ALASKA _ Al~ Oil AND GAS CONSERVATION CO~SION PERMIT TO DRILL 20 MC 25.005;:11::" 11 b. Current Well Class: Exploratory D Development Oil i. @. Stratigraphic Test D Service D Development Gas DSirìgre Zone [] 5. Bond: Blanket [] Single Well D 11. Well Name and Number: Bond No. 59-52-180 f 1 C-21 6. Proposed Depth: 12. Field/Pool(s): MD: 15573" TVD: 6522' r' Kuparuk River Field 7. PropertY!Jesignation: . )þ/ ADL-28242 & ADL 25649 .4'Þt... Zezt.f"ð ".::{i ¡I:; Kuparuk Oil Pool I 13. Approximate Spud Date: 5/14/2005 14. Distance to Nearest 2469 Property: 2324' f/KRU Bndry 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 42' RKB feet Within Pool: 1C-26: -2300' / 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3189 psi Surface: 2473 psi r' Setting Depth Quantity of Cement c.f.orsacks 1 a. Type of Work: Drill [] Redrill D Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1600' FNL, 4089' FEL, Sec. 12, T11N, R10E, UM Top of Productive Horizon: 1751' FSL, 987' FWL, Sec. 7, T11 N, R11 E, UM Total Depth: 381' FNL, 2293' FWL, Sec. 17, T11N, R11E, UM / 4b. Location of Well (State Base Plane Coordinates): Surface:x- 562198 / y- 5968638 r' Zone- 16. Deviated wells: Kickoff depth: Maximum Hole Angle: 8. Land Use Permit: ALK 2292 9. Acres in Property: 4 300 feet 92 degrees 18. Casing Program: Size Casing Specifications Top Bottom MD TVD 118' 118' 5980' 4705' 9153' 6542' 15573' 6522' Weight 62.5# 45.5# 29.7# 12.6# Grade H-40 L-80 L-80 L-80 Coupling Welded BTC BTCM IBT Length 76' 5938' 9111 ' 6570' MD TVD 42' 42' 42' 42' 42' 42' 9003' 6519' Hole 24" 16"** 13.5" 9-7/8" 6.75" 10.75"** 7-5/8"** 4.5" ** = actual casing run as of 6/8/05 ~"'C¡i I. ìJ~ ~{; {) (including stage data) 9 cu yds High Early 776 sx AS Lite, 385 sx LiteCrete 255 sx Class G slotted liner 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Size Cement Volume Length Perforation Depth MD (ft): Perforation Depth TVD (ft): MD TVD 20. Attachments: Filing Fee l!J BOP Sketch U Drilling Program l!J Property Plat D Diverter Sketch D Seabed Report D 21. Verbal Approval: Commission Representative: Tom Maunder ~ "'1v1 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Time v. Depth Plot U Shallow Hazard Analysis l.:d Drilling Fluid Program [] 20 AAC 25.050 requirements [] Date 6/7/2005 Contact Tim Billings/ey 265-6531 Printed Name Title Greater Kuparuk Drilling Team Leader Randy Thomas Signature ~ \~ . Phone 265-6830 Commission Use Only Permit to Drill .~ ;.- ¿-_ 3; I API Number: '. ..., _ '"' I Permit Approval Number: :2D~ 0 "1, 50- Ò Co- 9- Z'3 2.S:3 - C:b Date: ú j¡ I) /t7S- Conditions of approval: Yes D No i:}{l sulfide measures Yes ~ No D ......~~ ~~ ~~~ . Mud log required Directional survey required APPROVED BY THE COMMISSION Date: Date 1:./ "8 (05 I See cover letter for other requirements. Yes D Yes ŒI No 8l. No D ¥fs Submit inDuplicate · .Plication for Permit to Drill, We1l1C-21 Revision No.O Saved: 8-Jun-05 Permit It - Kuparuk Well #1 C-21 Application for Permit to Drill Document MQximizE: W.II Vglue Table of Contents 1. Well Name........... ............... ............ ............... ......... ............ ............ ......... .................. 2 Requirements of 20 AAC 25.005 (f) ..... ....... ...................... .............. ......................... ...... ........................ 2 2. Location Summary.............. .............. ............. ............. ........ ........... ................ .......... 2 Requirements of 20 AAC 25.005(c)(2) ...................................................................................................2 Requirements of 20 AAC 25.050(b) .. ................................................ .............. ......... ......... ..................... 3 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)(5) .................................................................. ............. ................... 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25. 005(c)(7) ...... ......... ..................... .............................................. ................. 4 8. Drill i ng FI uid Program.. .............. .......... .............. ....... ..... ........ ............ ............. ........ 5 Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite).................................................................................. 5 Intermediate Hole Mud Program (LSND) ............... ........................... .......................... ............. ......... ..... 5 Lateral Mud Program (MI FloPro)........................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 6 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................ .......... 6 10. Seismic Analysis . ............... ............. ............ ............ ........... .......... ............. .............. 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................ ................................ 6 1C-21 PERMIT IT 6-8-05. doc Page 10f8 Printed: 8-Jun-05 · .Plication for Permit to Drill, Well 1 C-21 Revision No.O Saved: 8-Jun-05 12. Evidence of Bonding.... ............. ........... ............. ............ ........ ............ ............. ......... 6 Requirements of 20 AAC 25.005 (c)(12).................................................................. ........ ................. ..... 6 13. Proposed Drilling Program ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(13)............ .............................................................. ............... ....... 7 14. Discussion of Mud and Cuttings Disposal and Annular DisposaL..................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ........... ............. ............. ............. .............. ........ ........... .............. ............ 8 Attachment 1 Directional Plan................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Summary ........................................................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (f) 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(b). For a well with multiple well branche~ 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 lC-21. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applicaffon for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (2) a plat identifying 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 locaffon 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 ASP Zone 4 NAD 27 Coordinates Nothings: 5,968,638 Eastings: 562,198 1600' FNL, 4089' FEL, Section 12, TUN, R10E, UM I RKB Elevation I 101.8' AMSL Pad Elevation 60.3' AMSL Location at Top of Productive Interval (Kuparuk "C4" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,966,753 Eastings: 567,291 1751' FSL, 987' FWL, Section 7, TUN, RUE, UM Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,964,680 Eastings: Measured Depth, RKB: 8,961 Total Vertical Depth, RKB: 6,509 Total Vertical Depth, 55: 6,407 ("...[ ¿. )1) ¿ ~"óç 381' FNL, 2293~Section 17, TUN, RUE, UM Measured Depth, RKB: 15,573 573,544 Total Vertical Depth, RKB: 6,522 Total Vertical Depth, 55: 6,420 /' and (D) other information required by 20 AAC 2S.0S0(b); 1C-21 PERMIT IT 6-8-05.doc Page 2 of 8 Printed: 8-Jun-05 · .Plication for Permit to Drill, Well 1 C-21 Revision No.O Saved: 8-Jun-05 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 (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed well bore (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 fumished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) 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: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete weIl1C-21. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 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 the 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 it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Kuparuk sands in the 1C-21 area vary from 0.38 to 0.49 psi/ft, or ,/ 7.3 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby Kuparuk wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Kuparuk sand formation is 2,493 psi, calculated thusly: MPSP =(6,509 ft)(0.49 - 0.11 psi/ft) = 2,473 psi (8) 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 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: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(f); 1C-21 PERMIT IT 6-8-05. doc Page 3 of 8 Printed: 8-Jun-05 · .Plication for Permit to Drill, Well 1 C-21 Revision No.O Saved: 8-Jun-05 A procedure is on file with the commission for performing LOT's. For 1C-21 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) 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 item~ 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- petforated liner, or screen to be installed,· 4-1/2 6-3/4" slotted Lateral 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, except for an item already on file with the commission and identified 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); Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 24 Top MD/TVD (ft) 42 / 42 Btm MD/TVD (ft) 118 / 118 Csg/Tbg OD (in) 16 Weight (Ib/ft) 62.58 Length (ft) 76 Grade H40 Connection Welded 10-3/4 5980 /4705 13-1/2 5938 42 / 42 45.5 L-80 STC 7-5/8 9153/ 6542 9-7/8 9111 42 / 42 29.7 L-80 STCM 12.6 9003/6519 15573 / 6522 L-80 IBT 6570 Cement Program Cemented to surface with 9 cu yd High Early Cemented to Surface with 776 sx ASLite Lead, 385 sx LiteCRETE Tail Cement Top planned @ 8156' MD / 6271' 1VD. Cemented w/ 240 sx Class G + additives Slotted- no cement A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1C-21. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 1C-21 PERMIT IT 6-8-0S.doc Page 4 of 8 Printed: 8-Jun-OS · .Plication for Permit to Drill, We1l1C-21 Revision No.O Saved: 8-Jun-05 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Interval Drilling FIUidSystemSPUd Mud INTERVAL MUD PROPERTIES Density (ppg) / 8.5 - 8.6 9.4 - 9.6 9.4 - 9.6 10.0 Funnel Viscosity (seconds) 250 ~ 300 250 - 300 200 - 250 200 -250 Yield Point (cP) 50-80 50 - 80 30-60 30-60 Plastic Viscosity (lb/100 sf) 8 - 15 11 - 22 12 - 30 12 - 30 10 sec Gels (lb/100 sf) 15 - 30 15 - 30 15 - 30 15 - 30 10 min Gels (lb/100 sf) 25 - 55 25 - 55 25 - 65 25 - 65 pH 8.5 - 9.5 8.5 - 9.5 8.5 -9.5 8.5 - 9.5 API Filtrate(cc) 8-15 <8 <8 <6 Solids (%) 5-8 5-8 5-8 6 - 10 Intermediate Interval prilling Fluid system LSND INTERVAL MUD PROPERTIES 9.4 - 9.5 35 - 41 24 - 30 10 - 15 <600 9-9.5 <6 <10 <20 <11 Final Value through .~ 9.6 - 10.0 38 - 45 24 - 30 15 - 20 <600 9 -10 4-5 <10 <20 <12 ,/ Properties Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscosity (lb/100 sf) Chlorides pH API filtrate HTHP filtrate MBT Solids ppb Initial Value 1C-21 PERMIT IT 6-B-05.doc Page 5 of B Printed: B-Jun-05 · .Plication for Permit to Drill, We1l1C-21 Revision No.O Saved: 8-Jun-05 Production Drilling Interval Drilling Fluid System FIO Pro Drill-in Fluid PRODUCTION INTERVAL MUD PROPERTIES Properties Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscosity (lb/100 sf) Chlorides pH API filtrate HTHP filtrate MBT Solids ppb Kuparuk Sand Initial Value 9.2 35 - 45 20 - 30 10 - 15 <600 9-9.5 <6 <10 <5 <3 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) 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: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: 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 the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphie test well, a seismic refraction or refiection analysis as required by 20 MC 25.061(a); Not applicable: 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 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: (11) for a well drilled from an offshore platform, mobJle bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b)~· Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) 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: (12) evidence showing that the requirements of 20 MC 25.025 {8onding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1C-21 PERMIT IT 6-B-OS.doc Page 6 of B Printed: B-Jun-OS · .Plication for Permit to Drill, Well 1 C-21 Revision No.O Saved: 8-Jun-05 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 item~ except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Doyon Rig 15. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Run MWD tools as required for directional monitoring. 3. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. 5. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD (GR/RES) & PWD. RIH, clean out cement to top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results. 6. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. Do not exceed 18.0 ppg EMW. 7. Directionally drill to 7-5/8" casing point as per directional plan. 8. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud. 9. Install wellhead 7-5/8" packoff and test to 5000 psi. 10. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. 11. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD (GR/RES/DENS-NEU) logging tools. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 12. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. Do not exceed 16.0 ppg EMW. 13. Directionally drill 6-3/4" hole to TD as per directional plan. 14. POOH, back reaming out of lateral. POOH. 15. PU and run 4-1/2" slotted liner with swell packers as needed. 16. Set liner hanger and ZXP liner top isolation packer. Release hanger running tool. POOH. 17. POOH, laying down drill pipe as required. 18. P/U and run 4-1/2" completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 19. Nipple down BOPE, nipple up tree and test. 20. Move rig off. 21. Pump corrosion inhibited brine into the 4-1/2" x 7-5/8" annulus, and freeze protect the tubing and IA. 22. Pull BPV. Shift sliding sleeve closed. MITIA. 23. Set gas lift valves in mandrels. 24. Flow back well to portable test separator to clean up well. 25. Secure well for facility hook-up. 1C-21 PERMIT IT 6-B-05.doc Page 7 of B Printed: B-Jun-05 · .Plication for Permit to Drill, We1l1C-21 Revision No.O Saved: 8-Jun-05 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 Item~ except for an item already on file with the commission and identified 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 authorization under 20.MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on IC Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on IC Pad, 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 (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Dríl/íng Hazards Summary Attachment 3 Cement Summary Attachment 4 Well Schematic 1C-21 PERMIT IT 6-8-05. doc Page 8 of 8 Printed: 8-Jun-05 . ....../ ConocoPhillips Alaska . ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-21 Plan: 1 C..21 (wp11) .. Extension Proposal Report 08 June, 2005 HALLIBURTON Sperry Drilling Services II 1,·1 i f i j I 11 I i I I weiL 10 i ! ¡ 'if i I 11 i ¡ 1') ¡' i I ¡ ___I 11600 tú ! I i i I I i I j ¡ I f I I r '<f i &eme.. HALLIBURTON Sperry DriIIInt ServI_ -750~ o~ 750- 15OO~ 2250~ :Ë 4:: o o It) :!:. 3000- "'" Õ. ( o ~ ~ 3750- > .. ( " ¡:: 4500- 5250- 6Ooo~ 6750- 7500- +N/-8 +EI·W 0.00 0.00 Northing 5968631.75 Ground Level: 60.30 Easting Latlttude 562198.12 10019'29.434N :,...;. ConocoPhlllips AJMÍ\å WELL DeTAILS: Pian: 1C.21 Longitude 149"29'44.342W Slot 1 C·21 ----;~-- ·750 I, 750 1 , 1500 I I) 1 ¡ I 3000 1.1 I I I i I 3750 I I I Vertical Section at 109.89" (1500 ftlin) 4500 5250 6000 6750 7500 8250 ¡ i I I ¡ I I I I I I I I I I I I 1 I I I I I I I I I I I , I 10500 1·1 í J ¡ 2250 I I ¡ o ì I I ¡ j ~ 9000 I 1 I 11250 12000 I I I I I I I ¡ ¡ I 9750 I I I I j I I REFERENCE INFORMATION Co-ordinate (NJE) Reference: Well Plan: 1C-21, True North Vertical (TVD) Referance: 1 C·21 Actual @ 101.8011 (Doyon 14 (41.5+60.3)) Section (VS) Reference: Slot· (O.OON. O.OOE) Measured Depth Reference: 1 C·21 Actual @ 101.8011 (Doyon 14 (41.5+60.3)) Calculation Metl'lod: Minimum Curvature ~O ~iI @ 90.00'Inc & 108.55"Azi: 1527311 MD, 6522f1 'NO I - . I Drop @4.5"!100f1 t090"lnc: 1509111 MD, 6535ft TVIJ ~il @ ~8.17"lnc & 108.90'Azi: 1467611 MD, 6594ft TVD I 12750 I I I ~-750 ~// -:¡ ...., -750 ~15OO -2250 :;1 ãš < - ( :-3000 I 0 J 51/2" :-3750 ~ ~ .a. -4500 e -5250 -6000 -6750 ¡Build @ 4.5~()Qft to 98.17" line - 14506ft MD, 660711 TVD ITO of 1C·21 (wp10) 14301'MD. 660TTVD 1 7518" ~I I , , , I ' I , I' Î ' -750 0 750 I Tie-In to Existing Wðll, Begin GeaS1eering to Feult 1293311 MD, 6563ft TVD I '" , 1 ' I , I I I , , 1 ! , , I I , , I I' I I I " 'I I 1500 2250 3000 3750 4500 5250 6000 , ~-~ IrD@ 1557311 MD, 6522f1 TVD : 381'FNl & 2293'F'Wl··Sec 17·T11N-R11E I - ¡ , I 11" , , l' , , , I I , , I" I , I I I ' \ , , I I , I ( I' I , I I I ,', I ' 6750 7500 8250 9000 9750 10500 11250 12000 12750 HALLIBURTON Sperry DtttIIne -.m_ 9000 I I. I 9200 , I I 9400 9600 I , ,I I , I , I , +N/-S +E/-W 0.00 0.00 Northing 5968631.75 ----.----- WEll DETAILS: Plan: 1C-21 (wp11) E.nslon Ground Level: 60.30 Eastlng Latlttude 562198.12 10019'29.434N Longitude 149°29'44.342W .---......--... -..-,- REFERENCE INFORMATION Co-ordináte (N/E) Reference: Well Plan: 1C·21, True North Vertical (TVD) Reference: 1C·21 Actual@ 101.80ft (Doyon 14 (41.5+00.3)) Sadion (VS) Reférence: Slot·· (O.OON, O.DOE) Measured Depth Rafòrence: 1C-21 Actual@ 101.80ft (DoyOn 14 (41.5+00.3)) Calculation Method: Minimum Curvature 9800 10000 10200 10400 I , I I , , I , I 'i' I I, i , I I , í 5600- l!ie-In 10 Exisling well, Begin GeoSteering to Faull 12933f1 MD, 6563f1 TVD I 5800- 6000- 6200- ê "ª o o :::!. 6400- ,s 0- ( C (ij o 'ë 6600- ~ ( " t: 6800- 7000- 7200- 7400- 9000 I I 'J 'Î I 9200 , , I I I ì I I I I', I 9400 9600 Vertical Section at 109.89' (400 fIIin) 10600 10800 11000 11200 11400 I I I , ¡ ì ' I I , , I I , ¡I' I ; i I I I I I I Sail @ 98.17'100 & 108.90'Azi : 1467611 MO, 659411 NO .-...."."""'_.".._",. 11600 I I ¡¡I Slot 1 C·21 11800 , I í ",,' ConocoPhillips tljasJ¡:a 12000 12200 12400 , , I I ,i , , I , , , , I , I I 12600 I t,l, I I . -5600 ¡BUild @ 4.5'/100fl to 98.17' line - 1450611 MO, 660711 TVO i Orop @4,5'/10011 to 9O'lnc; 1509111 MO, 653511 NDI -5800 ¡TO of 1 C.21 (wp10) 14301'MD, 6607'TVD '\,...,~ ""''-'' ""'\',-,-, '<,. -"'''"'\..,. " "'''-,\-." '>">"''- " . '" co / Ii I I 9800 I , I I ' , 10000 , I ' I I I I I 11 I I II J' , 'i I I I ' , 10200 10400 10600 10800 11000 Iro@15573f1MD,6522f!TVD : 381'FNL&2293'FWL--Sec1H11N-R11Ë 1::-7400 " ", ~ \" / I / / , ,/ 11C.21 (14~10) - Fault I -6000 [Sail @ 90.00olne & 108.55"Azi; 15273f1 MO, 6522flT\íDl = / ~/// / / / / / -6200 /",/ :;t c: II> - < -6400 ~ ~ o II> 11 --.. //" ~ - 6800 -7000 -7200 I II' I , f ' I I I I ' I I "II I , , I ' I , , I' I , 'I I I , ii' , , 11200 11400 11600 11800 12000 12200 12400 12600 "....' ConocoPhiUips Alaska . Halliburton Company Planning Report - Geographic . HAL.LIBURTON ........, DrIIIInø ~._1fk:.. EDM 2003.11 Silllle User Db ConocoPhi"ips Alaska (Kupan.d<) Kuparuk River Unrt Kuparuk 1C Pad Plan: 1 C-21 1C-21 Mainbore 1C-21 (wp11) - Extension Local co.ordII1aIe TVD RiIIferenCe: MD Reference: North Reference: Swvey C"aII:uIIdton IiIIIIIIod: Well Plan: 1C-21 1C-21 Actual @ 10t,8OIt (Doyon 14 (41,5+60.3» 1C-21 Actual @ 101.8Oft (Doyon 14 {41.5+60.3)) True Minimum Curvature " North Slope Alaska, United States Geo Datum: I Map Zone: US State Plane 1927 (Exact soMon) NAD 1927 (NAOCON CONUS) Alaska Zone 04 " System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Position Uncertainty 0.00f! 0.00 f! 0.00f! Northing: Easting: Wellhead Elevation: S,968,637.75f! /' 5&2,198.1211: r It latitUde: Longitude: Ground Level: 70019' 29.434" N 149029' 44.342" W 60.30ft Well Position +NI-S +E1-W 6f7 f2OO5 (j 24.34 BGGM2oo4 80.77 57,604 (wp11) - Extension Audit Notes: Version: Phase: PLAN Tie On Depth: 12,933.50 +Nf.S 1ft) 0.00 41.50 000 109.89 1ft:) 12,93350 86.17 112.50 6,562.68 -3,195.07 8,824.68 0.00 0.00 0.00 0.00 13,366.12 88.52 108.86 6,582.72 -3,347.65 9,228. 89 1.00 0.54 -0.84 -57.19 14,298.56 88.52 108.86 6,606.80 -3,64902 10,110.95 000 0.00 0.00 0.00 14,428.73 90.68 10740 6,607.71 -3,689.53 10,234.64 200 1.66 -1.12 -34.11 14,506.08 90.68 10740 6,60680 -3,71267 10,308.45 0.00 0.00 000 000 14,675.90 98.17 108.90 6,593.71 -3,765.37 10,46922 4.50 4.41 0.88 11.24 15,090.87 98.17 108.90 6,534.74 -3,898.46 10,857.82 0.00 0.00 0.00 000 15,272.61 90.00 108.55 6,521.80 -3,956.60 11,029.35 4.50 -4. 50 -0.20 -177.51 15,57261 90.00 108.55 6,521.80 -4,052.04 11,313.77 0.00 0.00 0.00 0.00 6/8/200510A2:02/J.A4 P;.;ig-s 2 (;f 8 CO~v1FA:SS 2003. 11 BuFd48 ""'" ConocoPhillips Alaska . Halliburton Company Planning Report - Geographic . HAL.LIBURTCiN Speny DrIIIIRø ~..... EDM 2003.11 Single User Db CooocoPhillíps Alaska (KupaI'1.Š<) Kuparuk River Unit Lacat C1I TVD Refenmœ: MD Reference: 1C-21 Actual @ 101.8011 (Doyon 14 (41.5+60.3)) 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) True Minimum CuJvature SUrvey IIMIIod: 41.50 0.00 0.00 41.50 -60.30 0.00 0.00 5,968,637.75 562,198.12 0.00 0.00 150.45 0.48 12203 150,45 48.65 -0.24 0.39 5,968,63751 562,198.51 0.44 0.45 238.15 0.71 12310 238.14 138.34 -0.73 1.15 5,968,637.03 562,199.28 0.26 1.33 329.53 067 105.38 329.52 227.72 -1.18 2.14 5,968,636.58 562,200.27 0.24 2.42 423.34 0.88 117.37 423.32 321.52 -1.66 3.31 5,968,636.12 562,201.44 0.28 3.68 515.72 0.98 115.05 515.69 413.89 -2.32 4.66 5,968,635,47 562,202.80 0.12 5.17 607.93 0.44 6953 607.89 506 09 -2.53 5.70 5,968,63527 562,20384 0.80 6.22 700.98 014 2.56 700.94 599.14 -2.29 6.04 5,968,635.51 562,20418 044 6.46 791.69 0.09 44.52 791.65 689.85 -213 6.10 5,968,63567 562,204.23 0.10 6.46 88415 026 3073 884.11 78231 -190 6.26 5,968,635.90 562,204.39 0.19 6.53 97665 0.00 195.75 976.61 87481 -172 6.36 5,968,636.08 562,20450 0.28 6.57 1,072.50 2.80 117.77 1 ,072.42 970.62 -2.81 8.44 5,968,635.01 562,206.58 2.92 8.89 1,167.70 4.08 117.75 1,167.45 1,06565 -5.47 13.49 5,968,632.39 562,211.65 1.34 14.55 1,260.00 5.74 118.20 1,259.40 1,157.60 -9.18 20.46 5,968,628.74 562,218.66 1.60 22.37 1,356.76 9.07 117.17 1,355.34 1,253.54 -1495 31.52 5,968,623.06 562,22976 3.44 3472 1,452.21 12.47 123.17 1,449.10 1,347.30 -24.03 46.84 5,968,614.11 562,245.15 3.75 52.22 1,547.33 13.41 117.90 1,541.81 1,440.01 -34.81 65.19 5,968,603.49 562,263.59 1.59 73.14 1,642.93 14.32 115.22 1,634.62 1,532.82 -45.03 85.68 5,968,593.43 562,284.16 1.16 95.89 1,738.04 15.47 112.66 1,726.54 1,624.74 -5493 108.03 5,968,583.72 562,306.59 1.39 120.27 1,833.26 17.54 109.74 1,817.83 1,716.03 -64.67 133.25 5,968,574.19 562,33189 2.34 147.31 1,837.43 1773 10966 1,821.80 1,720.00 -65.10 134.44 5,968,573.77 562,333.08 4.62 148.57 Base Permafrost 1,928.28 21.90 108.23 1,907.26 1,805.46 -75.06 163.58 5,968,564.06 562,362.30 4.62 179.35 2,024.64 26.47 10940 1,995.14 1,893.34 -87.82 200.92 5,968,551.61 562,39974 4.77 218.81 2,119.04 30.78 113.98 2,077.99 1,97619 -104.63 242.86 5,968,535.14 562,441.82 5.12 263.97 2,214.89 36.44 11491 2,157.78 2,055.98 -126.61 291.13 5,968,513.57 562,490.26 5.93 316.83 2,310.10 42.32 113.36 2,231.34 2,129.54 -15125 346.25 5,968,48939 562,545.57 626 377.05 2,404.35 46.91 110.17 2,298.43 2,196.63 -175.71 407.72 5,968,465.44 562,607.24 542 443.18 2,499.20 48.04 109.15 2,362.54 2,260.74 -19923 473.54 5,968,442.48 562,67325 1.43 513.07 2,595.36 47.42 109.34 2,427. 22 2,325,42 -222.68 540.72 5,968,419.58 562,740.62 0.66 584.23 2,690.64 46.96 10940 2,491.96 2,390.16 -245.86 606.67 5,968,396.95 562,806 75 0.48 654.12 2,785.90 47.77 109.30 2,558.49 2,454 69 -269.08 672.79 5,968,374.28 562,873.05 0.85 724.20 2,880.70 49.09 110.36 2,619.39 2,517.59 -293.15 739.50 5,968,350.77 562,939.96 1.62 795.12 2,975,47 49.10 110.79 2,681.45 2,579.65 -318.32 806.56 5,968,326.16 563,007.21 0.34 866.74 3.070.81 48.70 110.76 2,744.12 2,642.32 -343.80 873.73 5,968,301.23 563,074.59 0.42 938.58 3,186.02 48.35 110.21 2,807.18 2,705.38 -368.77 940.56 5,968,276.83 563,14161 0.57 1,009.91 3,260.89 48.02 110.75 2,870.43 2,768.63 -393.50 1,006.79 5,968,252.64 563,208.04 0.55 1,080.61 3,35668 4778 110.31 2,934.65 2,832.85 -418.43 1,073.35 5,968,228.27 563,27480 0.42 1,15168 3,452.18 47.65 110.25 2,998.90 2,897. 1 0 -442.92 1,139.63 5,968,204.33 563,341.27 0.14 1,222.33 3,547.06 4739 110.45 3,062.98 2,961.18 -46725 1,205.23 5,968,180.55 563,407.07 0.32 1,292.30 3,642.08 47.02 110.38 3,127.53 3,025.73 -491.57 1,27058 5,968,156.77 563,472.61 0.39 1,362.02 3,736.31 46.47 109.98 3,192.10 3,090.30 -51525 1, 334.99 5,968,133.63 563,53721 0.66 1,430.65 3,782.34 46.48 110.16 3,223.80 3,122.00 -526.70 1,36634 5,968,122.44 563,568.65 0.28 1,464.03 Top Ugnu 3,831.64 46.50 11035 3,257.88 3,15606 -539.13 1,400.02 5,968,110.29 563,602.43 0.28 1,499.93 3,926.93 46.24 10979 3,323.49 3,221.69 -562.75 1,464.67 5,968,087.21 563,667.26 0.51 1,568.75 4,022.16 45.98 109.33 3,389.51 3,287.71 -58573 1,52934 5,968,06477 563,132.11 0.44 1,£37.38 4,117.07 47.47 109.64 3,454.57 3,352.77 -608.78 1,59446 5,968,04226 563,797.44 159 1,706.48 4,211.90 4732 109.68 3,518.77 3,416.97 -632.26 1,66021 5,968,019.33 563,863.35 0.16 1,776.26 6Æ!!2005 10 42:02AM Pfj(&3ä8 COf,.,1PA8S 2003, 11 BtiJ:d 48 ~/ ConocoPhillips Alaska . Halliburton Company Planning Report - Geographic . HALLIBURTON Speny DrØIInIJ ~.- ... EDM 2003.11 Single User Db ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-21 1C-21 Mainbore 1C-21 (wp11) - Extension Local eo.ontimde RefImøIte: TVD Aefi!nmœ: MD Reference: North Refen!nce: SUrvey Calt:l1IøIIon MeIIIod: Well Plan: 1C-21 1C-21 Actual @101.8011(Doyon14(41.5+6113» 1C-21 Actual @ 101.8011 (Doyon 14(41.5+60.3)) True Minimum OJIvature - Extension (ft) 4,306.29 46.85 109.86 3,583.04 3,481.24 -655.64 1,725.26 5,967,996,49 563,928.59 0.52 1,845,41 4,40130 47.90 109.80 3,647.38 3,545.58 -679.36 1,791.03 5,967,973.32 563,994.54 1.11 1,915.31 4,494.75 47.52 109.87 3,710.26 3,608.46 -702.81 1,856.05 5,967,950.41 564,059.76 0.41 1,984.44 4,591.17 47.50 109.71 3,775.39 3,673.59 -726.89 1,922.95 5,967,926.89 564,126.85 0.12 2,055.64 4,683.91 47.57 109.44 3,836.00 3,736.20 -749.81 1,987.41 5,967,904.51 564,191.49 0.23 2,123.95 4,707.26 47. 25 10930 3,853.80 3,752.00 -755.51 2,00363 5,967,898.94 564,20775 1,45 2,141.14 Top West Sak 4,779.32 46.25 108.87 3,90318 3,80138 -772.67 2,053.23 5,967,882.19 564,257.49 1.45 2,193.62 4,874.02 4575 109.20 3,966.96 3,867. 16 -794.89 2,117.63 5,967,880.51 564,322.06 0.58 2,261.74 4,969.39 4742 109.77 4,03450 3,932.70 -818.00 2,182.93 5,967,637.95 564,387.55 1.80 2,331.01 5,064.30 49.07 110.20 4,09771 3,995.91 -84220 2,249.46 5,967,81430 564,45427 1.77 2,401.81 5,15880 49.05 1 09. 94 4,159.63 4,057.83 -866.70 2,316.51 5,967,790.36 564,521.52 0.21 2,473.19 5,253.60 49.07 111.79 4,221.75 4,119.95 -892.20 2,383.42 5,967,765.42 564,588.63 1.47 2,54479 5,342.25 4913 11184 4,279.80 4,178.00 -917.10 2,445.63 5,967,741.04 564,651.04 0.07 2,611.76 Base West Sak 5,349.50 49.13 '1184 4,284.54 4,18274 -919.14 2,450.72 5,967,739.04 564,656.14 0.07 2,617.23 5,444.32 49.65 111.84 4,346.26 4,244.46 -945.92 2,517.64 5,967,712.82 564,723.17 0.55 2,689.17 5,539.80 47,58 112,85 4,409.38 4,307,58 -973.14 2,583,79 5,967,686.15 564,789.64 2.31 2,760.74 5,633.56 47.10 11305 4,472.92 4,371.12 -1,000.03 2,647.29 5,967,659,79 564,853.35 0.64 2,829.59 5,723.14 48.12 113.72 4,533.31 4,431.51 -1,026.29 2,708.01 5,967,63404 564,91428 1.27 2,895.63 5,818.01 50.22 112.27 4,595.34 4,493.64 -1,05432 2,774.09 5,967,606.56 564,980.59 2.50 2,967.30 5,906.92 50.93 111.94 4,651.80 4,550.00 -1,080.16 2,837. 72 5,967,581.25 565,044.42 0.85 3,035.92 C-80 5,912.16 50.97 111.92 4,655.10 4,553.30 -1,081.68 2,841.49 5,967,579.76 565,048.21 0.85 3,039.99 6,006.81 4986 110.18 4,715.42 4,613.62 -1,10788 2,909.56 5,967,554.12 565,116.49 1.84 3,112.92 6,102.57 48.63 109.91 4,777.93 4,676.13 -1,132.75 2,977.70 5,967,529.83 565,184.83 1.30 3,185.45 6,197.23 4822 109.52 4,84075 4,738.95 -1,156.64 3,044.37 5,967,506.49 565,251.68 0.53 3,256.27 6,292,41 4898 109,91 4,903.69 4,801.89 -1,180.72 3,111.58 5,967,482.97 565,319.08 0.86 3,327.66 6,388.33 49.93 10964 4,96604 4,864.24 -1,205.38 3,180.17 5,967,458.88 565,387,86 1.01 3,400.55 6,483.93 4916 111.27 5,028.07 4,926.27 -1,230.80 3,248.32 5,967,434,03 565,456.22 1.53 3,473.28 6,579.84 48.62 111.02 5,09114 4,989.34 -1,256.86 3,315.72 5,967,406.53 565,523.82 0.60 3,545.53 6,674.85 48.87 111.06 5,153,79 5,051.99 -1,282.51 3,38238 5,967,383.44 565,590.69 0.27 3,616.94 6,769.27 48.74 110.32 5,215.97 5,114.17 -1,307.61 3,448.85 5,967,358.89 565,657.36 0,61 3,687.98 6,864.01 49.88 110.06 5,277.74 5,175.94 -1,332.40 3,516.27 5,967,33488 565,72497 1.22 3,759.82 6,960.16 49,46 111.88 5,339.97 5,238.17 -1,35863 3,584.71 5,967,309.01 565,79362 1.51 3,83310 7,055.34 47.94 11129 5,402,79 5,300.99 -1,384,94 3,651,19 5,967,283.25 565,860.32 166 3,904.57 7,150.92 46.74 110.73 5,46756 5,365.76 -1,410.14 3,716.81 5,967,258.60 565,926,13 133 3,974.84 7,245.64 46.90 110.31 5,532.37 5,430.57 -1,43435 3,781.50 5,967,234.93 565,991.01 036 4,043,91 7,340.59 46.20 110.15 5,597.67 5,495.87 -1,458.19 3,846.17 5,967,211.63 588,055.88 0.75 4,112.84 7,434,25 4624 109.97 5,662,47 5,560.67 -1,481.38 3,909.69 5,967,188.96 588,119.58 0.15 4,180.46 7,530,42 47.62 110.17 5,728.15 5,626.35 -1,505.49 3,97568 5,967,16540 566,185.76 1.44 4.250.71 7,625.72 48.58 111.52 5,791.79 5,68999 -1,530.74 4,041.96 5,967,140,71 566,25225 1.46 4,321.63 7,698.22 48.48 111.69 5,839.80 5,738.00 -1,550.74 4,092,47 5,967,12113 566,302.91 0.22 4,375,93 C40 7,721.85 48.45 111.74 5,855.47 5,753.67 -1,55728 4,108.91 5,967,11472 566,319.40 0,22 4,393.61 7,814.93 50.01 113.07 5,916.25 5,814.45 -1,584.16 4,174.07 5,967,088.39 568,38478 1.99 4,464.03 7,908.83 51.84 11263 5,975.44 5,873.64 -1,61258 4,241.19 5,967,060.53 565,452.13 1.96 4,538.112 8,004.57 50.96 114.88 6,035.17 5,933.37 -1,64283 4,309.62 5,967,030.85 566,520.80 1.91 4,611.45 6/8/200510A2û2A,'''¡ Pag", 4 of 8 COMPASS 2003.11 Build 48 .,.../ ConocoPhiJIips Alaska . Halliburton Company Planning Report - Geographìc . HAl.L.IBURTON Sperry DIll.... ~._ "'e.. EDM 2003.11 Single User Db ConœoPhitlips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan: 1G-21 1G-21 Mainbore 1 C- 21 (wp11) - Extension Local co-ontinIIte Refentnœ: TVt) Refenmœ: MDRefa_: North Reference: SIney càlalldon lIetIIod: Well Plan:1C-21 1C-21 Actual @ 101.8Oft (Doyon 14 (41.5+60.3)) 1C-21 Actual @101.8Oft (Doyon 14 (41.5+60.3» True Mirtimum CtJlValUl"e 8,099.93 49.86 113.75 6,095.95 5,994.15 -1,673.09 4,376.58 5,967,001.15 566,588.00 1.47 4,684.72 8,150.73 4955 112.73 6,128.80 6,027.00 -1,688.38 4,412.19 5,966,986.16 566,623.73 1.65 4,723.40 Top HRZ 8,194.85 49.29 111.83 6,157.50 6,055.70 -1,701.08 4,443.19 5,966,973.71 566,65483 1.65 4,756.88 8,289.80 51.12 110.06 6,218.27 6,116.47 -1,727.14 4,511.32 5,966,94822 566,723.17 2.40 4,829.81 8,384.96 56.62 109.41 6,274.36 6,172.56 -1,753.07 4,58365 5,966,922.89 566,79570 5.81 4,906.64 8,480.28 61.01 108.44 6,323.70 6,221.90 -1,779.50 4,660.77 5,966,89711 566,873.03 4.69 4,988.15 8,575.26 62.64 108.37 6,368.55 6,266.75 -1,80593 4,74021 5,966,871.34 566,952.68 1.72 5,071.85 8,637.56 63.45 109.03 6,396.80 6,295.00 -1,823.74 4,792.82 5,966,853,97 567,005.43 1.60 5,127.38 Base HRZ 8,669.60 63.86 109.36 6,411.01 6,309.21 -1,833.17 4,819.92 5,966,844.76 567,032.61 1.60 5,156.07 8,754.44 67,72 109.71 6,445.80 6,344.00 -1,859.05 4,892.83 5,966,819.49 567,105.73 4.56 5,233.44 K·1 8,763.73 68.14 109.75 6,449.29 6,347.49 -1,861.95 4,900,93 5,966,816.66 567,113.85 4.56 5,242.04 8,857.57 7304 11080 6,480.47 6,378.67 -1,892.63 4,983.93 5,966,786.68 567,197.08 5.33 5,330.52 8,953,63 75.09 109.60 6,506.84 6,405.04 -1,92451 5,070.61 5,966,755,51 567,2M02 2.45 5,422.88 8,961.35 75.46 109.34 6,508.80 6,407.00 -1,927.00 5,077.65 5,966,753,08 567,291.08 5.82 5,430.34 Top Kuparul< 9,018.43 78.21 107.42 6,521.80 6,420.00 -1,944.52 5,130.39 5,966,736.00 567,34396 5.82 5,485.90 9,050.65 79.77 106.36 6,527.95 6,426.15 -1,953.71 5,160.65 5,966,727.07 567,37429 5.82 5,517.46 9,055.46 79.95 106.20 6,528.80 6,427.00 -1,955.04 5,165.20 5,966,725.78 567,378.85 5.02 5,522.21 C4 9,088.29 81.21 105.12 6,534.17 6,432.37 -1,963.78 5,196.38 5,966,717.29 567,410.10 5.02 5,554.50 9,153.00 84.79 108,82 6,542.06 6,440.26 -1,982.53 5,257.79 5,966,699.06 567,471.65 7.93 5,618.63 75/8" 9,15439 84.87 108.90 6,542.18 6,4«1.38 -1,98297 5,259.10 5,966,698.62 567,472.97 7.93 5,620.01 9,246.59 92.72 108,11 6,544.12 6,442.32 -2,012.21 5,346.44 5,966,670.12 567,560.54 8.56 5,712.09 9,33928 90,26 107,52 6,54171 6,439.91 -2,040.55 5,434.65 5,966,54251 567,64897 2.73 5,804.88 9,432.80 89.88 101.71 6,541.60 6,439.80 -2,064.14 5,525.10 5,966,619.67 567,739.61 6.23 5,897,77 9,52604 85.99 100.31 6,544.96 6,443.16 -2,081.93 5,616.55 5,966,60264 567,83119 4.43 5,989.81 9,618.98 90.46 106.08 6,547.84 6,446.04 -2,103.13 5,706.93 5,966,582.19 567,921.74 7.85 6,082.01 9,706.85 8408 107.63 6,552.02 6,450.22 -2,128.56 5,790.88 5,966,557.46 588,005.89 7.47 6,169.61 9,800.50 85.52 110.72 6,560.51 6,458.71 -2,159.19 5,878. 98 5,966,527.56 588,094.21 3.63 6,262.85 9,893.72 87.29 113.24 6,566.35 6,464.55 -2,194.01 5,96522 5,966,493.46 568,180.75 3.30 6,355.82 9,987.30 88.88 113.04 6,569.48 6,467.68 -2,230.76 6,051.22 5,966,457.43 568,267.04 1.71 6,449.19 10,081.95 8780 110.99 6,572.22 6,470.42 -2,266.23 6,138,93 5,966,42270 568,355.03 2.45 6,543.73 10,174.17 90.01 112.93 6,573,99 6,472.19 -2,300.70 6.22443 5,966,388.93 568,440.81 3.19 6,635.86 10,267.36 92.61 111.95 6,571.86 6,470.06 -2,336.26 6,310.53 5,966,354.09 568,527.20 2.98 6,728.93 10,361.78 94.33 111.83 6,566.14 6,464.34 -2,371.40 6,397.98 5,966,319.68 568,614.93 1,.83 6,823.11 10,454.92 91.72 112.09 6,561.23 6,459.43 -2,406.18 6,484.24 5,966,285.62 568,701.46 2.82 6,916,05 10,548.24 9263 111.91 6,557.68 6,455.88 -2,441.11 6,570.70 5,966,251.41 568,788.20 0.99 7,009.24 10,641.91 95.44 113.29 6,551.09 6,44929 -2,477.01 6,656.95 5,966,216.23 568,874.74 334 7,102.56 10,734.41 91.13 108.89 6,545.79 6,443.99 -2,510.22 6,743.07 5,966,183.74 568,961.12 6.65 7,194.85 10,828.14 84.95 10647 6,549,00 6,447.20 -2,538.66 6,832.27 5,966,156.05 569,050.55 708 7,288.40 10,921.82 85.96 108.97 6,556.42 6,454.62 -2,567.08 6,921.22 5,966,128. 37 569,139.72 2.87 7,381.71 11,014.22 86.98 109.13 6,562.13 6,46033 -2,59718 7,00839 5,966,09899 569,227.13 1.10 7,473.92 6/8/2oo510A2:02AM P&.J&. 50[8 COMPASS 2003. -11 BuHd 48 ,../ ConocoPhiUips Alaska . Halliburton Company Planning Report - Geographic . HALLIBURTON Sperry DrIB'" ~._<fIC8' EDM 2003.11 Single User Db CooocoPhillips Alaska (KuparlJ<) Kuparuk River Unrt Kuparuk 1C Pad n:1C-21 C-21 Mainbore 1 C-21 (wp11) - Extension Locat co.ordinatIt Raferenctt: TVD AilfeI'8llCe: MD RefeÆnce: North Refeœnce: Survey CaII:uIIdIan.eIItod: \/\leU Plan: 1C-21 1C-21 Actual @ 101.BOIt (Doyon 1C-21 Actua1 @ 101800 (Doyon True MInimum CUlVature - Extension SSTVD +NS.s (ft) (ft) 11,108.34 88.09 108.84 6,566.19 6,464.39 -2,627.77 7,097.31 5,966,069.14 569,316.28 1.24 7,567.94 11,204.45 86.47 109.67 6,570.75 6,46895 -2,659.43 7,187.94 5,966,038.24 569,407.16 1.89 7,663.93 11,295,31 87.00 108,88 6,575,93 6,474,13 -2,689,37 7,273,56 5,966,009,01 569,493,03 1,05 7,754.64 11,387,96 84.24 109.53 6,583,00 6,481 ,20 -2,71!F5 7,360.79 5,965,979,35 569,580.50 3,06 7,847.00 11,48334 8624 109,00 6,590.92 6,489.12 -2,751.11 7,450.52 5,965,948,74 569,670.47 2,17 7,942,04 11,576,17 90.46 108,75 6,593.59 6,491 .79 -2,781,12 7,538.30 5,965,919.46 569,758.49 4,55 8,034,80 11,669,15 94,96 108,86 6,589,19 6,487,39 -2,811,06 7,62619 5,965,890,27 569,846,62 4,84 8,127,63 11,76270 96,94 109,02 6,579,50 6,477.70 -2,841,25 7,714.20 5,965,860.80 569,93486 212 8,220,66 11,85634 97. 69 1OB,89 6,567. 57 6,465,77 -2,871.42 7,802.04 5,965,831,36 570,022,94 0.81 8,313,53 11,949,60 9473 109,,06 6,557.48 6,455.66 -2,901.63 7,889,89 5,966,801,89 570,111,03 3.17 8,406.42 12,043,67 9104 109,97 6,552,74 6,450,94 -2,932.94 7,978,24 5,965,771,31 570,199,63 4,05 8,500.15 12,136,82 91,93 110,77 6,550,33 6,44.8,53 -2,965,36 8,065,53 5,965,739.63 570,287.18 1,28 8,593,26 12,23087 87.22 107,40 6,551,02 6,449,22 -2,996,09 8,154,37 5,965,709.63 570,376,27 6.16 8,687.26 12,324.09 92,07 107,52 6,551,60 6,449,80 -3,024,06 8,243,27 5,966,682.41 570,485,38 5,20 8,780,37 12,417,57 88,74 104,58 6,550,94 6,449,14 -3,049,89 8,333,08 5,965,657,32 570,555.40 4,75 8,873,61 12,510,99 85,48 97.40 6,555,66 6,453.86 -3,067.67 8,424.60 5,965,640,30 570,647.05 8,43 8,965,72 12,595,00 89,48 98,96 6,559,35 6,457.55 -3,079,61 8,507.66 5,965,629.05 570,730.19 5,11 9,047.88 12,604,89 88,76 99,22 6,559,50 6,457.70 -3,081,18 8,517.42 5,965,627.57 570,739,97 7.74 9,057,60 12,693,26 91.04 109,19 6,559,66 6,457,86 -3,102,83 8,602,97 5,965,606,62 570,825,69 11,57 9,145.42 12,791.42 88.67 114,31 6,559,91 6,458,11 -3,139,19 8,694,11 5,965,571,02 570,917,11 575 9,243,48 12,838,81 89,93 113.42 6,560.48 6,458. 68 -3,158,36 8,737,44 5,965,55221 570,960,60 3,26 9,290.76 12,884,01 89,38 112,70 6,560,76 6,458.96 -3,176,07 8,779,03 5,965,53485 571,002,33 2,00 9,33588 12,933,50 86,17 112,50 6,562,68 6,460,66 -3,19507 8,824,66 5,965,516,23 571,048.13 6.50 9,385.28 Tic-In to Existing well, Begin GeoSteering to Fault 12933ft MD, 6563ft TVD 12,99995 86,53 111,94 6,566,91 6,465,11 -3,220,15 8,886.ü7 5,965,491.67 571,109,72 100 9,451,53 13,09995 87. 07 111,10 6,572.49 6,470,69 -3,256.77 8,978,95 5,965,455,82 571,202,89 1.00 9,551,34 13,199,95 87,62 110,26 6,577.12 6,475,32 -3,292,05 9,072.40 5,965,42132 571,296,63 1,00 9,651.22 13,299.95 88,16 1 09.42 6,58080 6,479,00 -3,325,96 9,16640 5,965,388,19 571,390,90 1,00 9,751,15 13,36612 88.52 108,86 6,582,72 6,480,92 -3,347.65 9,228,89 5,965,367.02 571,453,55 1,00 9,817.28 13,399,95 88,52 1OB,86 6,583,60 6,481,80 -3,358.58 9,260,89 5,965,356,36 571,485,64 0,00 9,851,10 13,499.95 88.52 1OB,86 6,586,18 6,484,38 -3,39090 9,355.49 5,965,324,82 571,580.49 0.00 9,951,05 13,599,95 8852 1OB,86 6,588. 76 6,48696 -3,423,22 9,450,OB 5,965,293.29 571,675.35 000 10,051.00 13,699.95 88,52 108,86 6,591,34 6,489,54 -3,455,55 9,54468 5,965,261,76 571, 77020 0,00 10,150,95 13,799,94 88,52 108,86 6,593,92 6,492.12 -3,487,87 9,639,28 5,965,230,23 571,865,05 0,00 10,250,90 13,89994 88.52 108,86 6,596,51 6,494.71 -3,520,19 9,73388 5,965,198,69 571,959,91 0,00 10,350,85 13,999,94 88. 52 108.86 6,599,09 6,497,29 -3,552,51 9,828.47 5,965,167.16 572,05476 0,00 10,450,80 14,099,94 88,52 108,86 6,60167 6,499,87 -3,584,83 9,923,07 5,965,135,63 572,149,61 0,00 10,550,75 14,199,94 88,52 108,86 6,604,25 6,502,45 -3,617.15 10,017. 67 5,965,10410 572,244,48 0,00 10,650,70 14,298,56 88.52 108.86 6,606,80 6,505,00 -3,649,02 10,110,95 5,965,073.00 572,338,00 0,00 10,749,26 1C-21 (14301) 14,299.94 88,54 1OB,65 6,606,84 6,505,04 -3,649.47 10,112,26 5,965,072.56 572,339,32 2.00 10,750,65 14,301,00 88. 56 108,84 6,606,86 6,505,06 -3,649,81 10,113,26 5,965,072.23 572,340,32 2,00 10,751,71 TD of 1C-21 (wp10', 14301·MD. 6607'TVD 14,399.94 90.20 107,73 6,607.93 6,506,13 -3,680.85 10,207.20 5,965,041,98 572,434,50 2,00 10,850,60 14,428.73 90.68 107,40 6,607.71 6,505,91 -3,689.53 10,234.64 5,965,033,52 572,46201 2,00 10,879,36 14,506,08 90,68 107.40 6,606,80 6,505.00 -3,712,67 10,308.45 5,965,011,00 572,536.00 0,00 10,956,63 Build @4.5"110IJftto 98,17" line - 14506ft IUD. 6607ft TVD -1C-21 (14510} - Fault 14,599,94 9482 1OB,23 6,602.30 6,500.50 -3,741.35 10,397.69 5,964,983,06 572,625,46 4,50 11,050.30 6/8/2005 10>4202A,\-1 p¿¡g-:: 6 ()f 8 COMPASS 2003 11 Bwtd 48 ../ ConocoPhillips Alaska . Halliburton Company Planning Report - Geographic . H.AL.L.IBURTON Sperry DrIllIng ~'I... EDM 2003.11 Sirgle User Db ConocoPI1íllíps Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan'1c-21 1C-21 Mainbore 1C-21 Extension Local Co-ordimde Refenmce: TVD flillfefl!llCe: MD Reference: HortI1 Reference: SUrvey Qllcullllioo IIetIIod: Well Plan: 1c-21 1c-21 Actual @ 101.8Oft (Doyon 14 (41.5+60.3)} 1C-21 Actual @ 101.800 (Doyon 14 (41.5-+B0.3») True / Minimum Cu/Vature r 1c-21 (Wp11) - 14,675.90 9817 108.90 6,593 71 6,491. 91 -3,765.37 10,469.22 5,964,959.63 572,69719 4.50 11,125.75 Sail @ 98.17'loc & 108.90'Azj: 146761\ MO, 65941\ TVD 14,699.94 98.17 108.90 6,590.29 6,48849 -3,773.08 10,49173 5,964,952.11 572,719.76 0.00 11,149.54 14,799.94 98.17 108.90 6,576.08 6,474.28 -3,805.15 10,585.38 5,964,92082 572,813.66 000 11,248.51 14,899.94 98.17 108.90 6,561.87 6,460.07 -3,837.22 10,679.02 5,964,889.53 572,907.56 0.00 11,347.48 14,999.94 98.17 108.90 6,547.66 6,445.86 -3,869.29 10,772.67 5,964,858.24 573,001.46 0.00 11,446.45 15,090.87 98.17 108.90 6,53474 6,432.94 -3,89846 10,857.82 5,964,829.79 573,086.84 0.00 11,536.44 Drop @ 4.S'/1()Oft to 90'lnc : 15091ft MD, 6535ft TVD 15,099.94 97.76 108.89 6,533.48 6,431.68 -3,901.36 10,866.32 5,964,826.95 573,095.36 4.50 11,545.42 15,199.94 9327 108.69 6,523.87 6,422 07 -3,933.41 10,960.53 5,964,795.69 573,189.82 4.50 11,644.92 15,272.61 90.00 108.55 6,521.80 6,420.00 -3,956.60 11,029.35 5,964,773.07 573,258.83 4.50 11,717.52 Sail@90.00'locl1 108.5S'A2í: 1527311 MO, 652211 TVO 15,299.94 90.00 108.55 6,521.80 6,420.00 -3,965.30 11,055.27 5,964,764.59 573,264.81 000 11,744.85 15,399.94 90.00 108.55 6,521.80 6,420.00 -3,997.11 11,150.07 5,964,733.57 573,379.87 0.00 11,844.82 15,499.94 90.00 108.55 6,52180 6,420.00 -4,028.93 11,244.88 5,964,702.54 573,474.93 0.00 11,944.79 ,. 15,572.61 90.00 108.55 6,521.80 r 6,42000 -4,052.04 11,313.77 5,964,680.00 573,544.00 0.00 12,017.44 TO @15573ftMO, 6522ftTVD : 381"FNL & 2293'~ -See 17-T11N-R11E - 51i2~ -1C-21 (15560¡ ~ 6,606.80 - Circle (radius 200.00) 6,521.80 - Circle (radius 200.00) 6,606,80 - Circle (radius 20000) 6,521.80 - Circle (radius 200.00) 6,606.80 - Circle (radius 200.00) ft , 1,~51f;j For',.IJ! -3,712.67 10,30845 5,965,011.00 572,536.00 1(r) ~. -3,875.67 10,788.16 5,964,852.00 573,017.00 iC', 2:~ '144' -3,688.86 10,211.63 5,965,034.00 572,439.00 -4,052.04 11,313.77 5,964,680.00 573,544.00 {1J;)'?i -3,649.02 10,110.95 5,965,073.00 572,338.00 9,15300 15,57260 6,542.06 6,52180 7-~ 4-1/2 9-718 6-3/4 61í:i12005 1042.021'''\·1 P¿¡g7 7(;( 8 CO~1PASS 2003.11 Bw.ld48 ./ ConocoPhillips Alaska . Halliburton Company Planning Report - Geographic . HALLIBURTON Sperry DrIIIIntIh- vie.. EDM 2003.11 Sifl1Je User Db ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan: 1 C-21 1C-21 Mainbore 1C-21 (wp11ì - Extension t.ocat Co-ordinate RiIfenmI:e: TVD RiIIfe...-: MO Reference: North Refefence: Stney CaII:uIIItion IIeIItod: \NeU Plan: 1C-21 1C-21 Actual @101.8Oft(Doyon 14 (41.5+60.3)ì 1C-21 Actual @ 101.8Oft (Doyon 14 (41 ,5+60,3)ì True Mil1lmum CUlvature 1,837,43 17.73 109,66 1,821,80 -65.10 13444 Base Permarrost 3,782,34 46,48 110,16 3,22380 -526.70 1,366.34 Top Ugnu 4,707,26 47.25 109.30 3,853.80 -755,51 2,003.63 Top West Sak 5,342.25 49,13 111,84 4,279,80 -91710 2,445,63 Base West Sak 5,906.92 50,93 111,94 4,65180 -1,080.16 2,837.72 C-80 7,698.22 48,48 111.69 5,839.80 -1,550.74 4,092,47 C-40 8,15073 49,55 112.73 6,128.80 -1,688,38 4,412,19 Top HRZ 8,637,58 63.45 109,03 6,396,80 -1,823,74 4,792.82 Base HRZ 8,754,44 67. 72 109.71 6,445.80 -1,859,05 4,892.83 K-1 8,961,35 75,46 109,34 6,508,80 -1,927.00 5,077.65 Top Kuparuk 9,055.46 79.95 106,20 6,528,80 -1,955.04 5,165,20 C4 6/8/200510A2.-02AA4 P8ge 6 !)f (3 COMP.4S-S 2003, 1 J Bwld 48 . Conoc;pJ,illips Alaska . ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-21 1C-21 Mainbore Anticollision Summary 08 June, 2005 H;I~L.Lo¡,IBUR·TON Sperry Drilling Service. ""'/ ConocoPhillips Alaska . Halliburton Company Antcoiiisìon Report ConocoPhillips Alaska (Kuparuk) Kuparuk RÍVer Unit Kuparuk 1C Pad 0.001t Plan: 1C-21 o Oot! 1C-21 Mainbore iC-Zi (wp1i) - Extension Loça Co-onIInate Refenmce: 1VD Refenmce: MO ftetenl",;.: North Refenlnce: SUrYev Ca/çullltiOn MdIod: Output elTOl'S ani at Databas.: 0IIHt 1VD ReIiInmœ: 1C-21 (wp11) -Extljnsion FiIte~type: NO GLOBAL FILTER: Using user defined selection & filtering criteria I' Interpolation Method: MD Interval 25. 00f! Eno~ Model: Depth Range: 12,933.50 to 15,572.61ft Scan Method: I Results limited by: Maximum center-centljr distance of 1,337.46ft Error Surface: Warning Levels evaluated at: 0.00 Sigma 150.45 9,706.85 12,595.00 12,933.50 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWO+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-$C 9,618.98 1C-21 PB1 (1C-21PB1) 12,510.99 1 C-21PB3 (1C-21PB3) 12,933.50 1C-21 Mainbor¡¡ (1C-21 Mainbore) 15,57261 1C-21 (wp11) - Extension (1C-21 Mainbore) Kuparuk1 C Pad 1C-i2 -1C-12 - 1C-12 1 C-23 - 1 C-23· 1C-23 1C-26·1C-26 -1C·26 1C-27 - 1C·27 . 1C·27 Plan: 1C-20 (HEW2) - Plan1C- 20 -1C-20 (wp06) Plan: 1C-28 (HEWi) - Plan: iC-28· iC-28 (wp09) 15.343.97 14,375.00 . HAL.L.IBURTCN Speny D....... ~._.rIc.. Well Plan: 1C-21 1C-21 Actual @ 101.8Oft (Doyon 14 (41.5+00.3» 1C-21 Actual@101.8Oft(Doyon14(41.5+ßO.3» True Minìmtm CUrvature 2.00 sigma EOM 2003.11 Single User Db Offset Datum ISCWSA Trav. Cylinder North Elliptical Conic MWD+IFR AK CAZ see MWD+IFR AK CAZ sec MWO+IFR AK CAZ SCC MWD+ìFR AK eAZ see 2.41 0.83 out of range Out of range Out of range Out of range Out of range 1.58 Pass· Minor 11200 6/812005 W:292JAM P;"']I~ ;. 01 2 CC - -Min <:entre to cente: d!stafice Dr GO\(¿;~g~nt pc:ir;( SF - f¡,¡:i sepa:at)~)r; factor, ES - rr.ineHipse separation COMPASS 2003. 11 Bwld 4& 100 b! 00 90 90 BHL lC-21 (wpll) Extension lC-21 Top of Kuparuk · . lC-21 Drillina Hazards Summary 13-1/2" Hole /10-3/4" Casing Interval Event Broach of Conductor Risk Level Low Gas Hydrates Moderate Gravel/Sand Sloughing Moderate Hole Swabbing/Tight Hole on Trips Moderate Lost Circulation Low 9-7/8" Hole / 7-5/8" Casing Interval Event Shale stability in HRZ and K-l High ECD and swabbing with higher MW's required Risk Level Low Moderate Abnormal Reservoir Pressure Moderate Lost Circulation Low 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Trouble Sliding / Steering Moderate Differential Sticking Moderate Difficulties getting liner to bottom with swell packers Moderate Lost Circulation Moderate Mitigation Strategy Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Mitigation Strategy Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. Mitigation Strategy Bit/BHA design will take into account historical problems in offset horizontal wells with steering. Although LOTAD's should not be needed, torque/drag will be monitored to pro-actively identify a need for friction reduction devices to prevent weight transfer problems. Periodic wiper trips. Do not leave pipe static for extended period of time. Torque/drag will be monitored while drilling the interval. Pump out of hole on final trip out prior to running liner to ensure hole is clean. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, pre-treat with LCM prior to drilling fault crossings. Use LC decision tree designed for production laterals. An extensive LC strategy will be documented in the well plan. 1C-21 Drilling Hazards Summary 6-B-OS.doc prepared by Scott Lowry 02/24/05 Page 1 of 1 Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 3/1/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com . . ; ! ;:.,¡ If < Toe at Surface Previous Csg. < 16", 62.6# casing at 118' MD < Base of Permafrost at 1,884' MD (1,801' TVD) < Top of Tail at 4,000' MD < 103/4",45.5# casing in 13 1/2" OH TO at 5,605' MD (4,469' TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only: Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 4,000' MD. Lead Slurry Minimum pump time: 310 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 3 0.6381 ft 1ft x (118') x 1.00 (no excess) = 3 0.3637 ft 1ft x (1884' - 118') x 3.50 (250% excess) = 0.3637 ft3fft x (4000' - 1884'J x 1.35 (35% excess) = 75.3 ft3 + 2248 ft3 + 1038.9 ft = 3362.2 ft31 4.45 ft3fsk = Round up to 760 sks 75.3 ft3 2248 ft3 1038.9 fe 3362.2 ft3 755.6 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 180 min. (pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 3 0.3637 ft 1ft x (5605' - 4000') x 1.35 (35% excess) = 0.5400 ft31ft x 80' (Shoe Joint) = 788 ft3 + 43.2 ft3 = 831.2 fef 2.26 ft3/sk = Round up to 370 sks 788 ft3 43.2 ft3 831.2 fe 367.8 sks BHST = 94°F, Estimated BHCT = 8rF. (BHST calculated using a gradient of 2.6"Ff100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 6.0 614.1 102.4 135.7 DeepCRETE 6.0 148.1 24.7 160.4 Drop top plug 0.0 0.0 5.0 165.4 Water 5.0 20.0 4.0 169.4 Switch to rig pump 0.0 0.0 5.0 174.4 Mud 7.0 496.4 70.9 245.3 Slow & bump plug 3.0 15.0 5.0 250.3 MUD REMOVAL Recommended Mud Properties: 10.1 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. I~IÞ... Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 3/2/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 ernail: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 800' MD above top of Kuparuk - (850' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.02%B155, 0.4% D167 -1.16 ft3/sk 0.2148 ft31ft x 850' x 1.40 (40% excess) = 0.2578 ft31ft x 80' ¡Shoe Joint) = 255.6 ft3 + 20.6 ft = 276.2 ft3/1.16 ft3/sk = Round up to 240 sks 255.6 ft3 20.6 ft3 276.2 ft3 238.1 sks Previous Csg. < 103/4",45.5# casing at 5,605' MD BHST = 155°F, Estimated BHCT = 120°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 6.0 40.0 6.7 29.7 Tail 6.0 49.2 8.2 37.9 < Top of Tail at Drop top plug 0.0 0.0 5.0 42.9 8,156' MD Mud 7.0 397.8 : 56.8 99.7 Slow & bump plug 3.0 12.0 4.0 103.7 MUD REMOVAL < 75/8",29.7# casing in 97/8" OH Recommended Mud Properties: 10.6 ppg, As thin and light as possible to aid in mud removal during cementing. ~ I Spacer Properties: 12.5 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 TO at 9,006' MD (6,524' rvD) Centralizers: Recommend 1 ~ per joint across zones of interest for proper cement placement. 1 C..21 Horizo I Well Base Case Proposed Completion Schematic Conoc;¡;hillips I f ~ ~ i I I i I I I "'" ~ , . I 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT pin down (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Tubing to Surface (Special Drift to 3.91") 4-112" Cameo 'DB' nipple wI 3.875" No-Go Profile set at +1- 500' MD 4-1/2" 12.6# L-80 IBT tubing to landing nipple (Special Drift to 3.843") 4-1/2" x 1" Cameo 'KBG-2' Mandrels wI DV's (Max. OD 5.984", ID 3.833") Spaced out wI 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as follows: Surface csg. 10-314" 45.5# L-80 BTC Special Drift - 9.875" 5980' MD /4705' TVD (200' TVD below Base West Sak) GLM # TVD-RKB MD- RKB 1 2600 2877 2 3800 4671 3 4700 6017 4 5400 7063 5 5925 7848 6 6338 8500 {shear valve pinned for 3000 psi in GLM #6} 4-1/2" Cameo 'DB' nipple wI 3.813" No-Go Profile set @ bottom of tangent section +1- 8530' MD I 6352' TVD 4.75" OD Baker casing seal assembly w/17 Ft. stroke, 4-1/2" 12.6 # L-80 IBT box up (landed 2-4' off fully landed position) Intermediate csg. 75/8" 29.7# L-80 BTCM 9,153' MD 16542' TVD (App. 50' MD below top of C4) - -- --- -- -- -- -- ---, 4 %" x 6.3" Swell Packers for isolation of potentially conductive faults or wet intervals -y- / / Slotted Liner 4-112" 12.6# L-80 IBT ---------- Liner Assembly - Hanger Set +1- 150' above intermediate csg shoe Baker 5 %" x 75/8" 'ZXP' Liner Top Isolation Packer w/ HRD running profile Baker 5 %" x 7 5/8" RS Nipple Baker 5 %" x 7 5/8" 'Flexlock' Liner Hanger Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore) 4 W' 12.6# L-80 IBT alternating slotted and blank pipe w/ swell packers (installation of blank pipe & swell pkrs TBD with well logs) C4/C3 Lateral to 15,573' MD 4 %" ROT 'Silver Bullet' Shoe I Tim Billingsley 5/8/05 RE: lC-21 extented (,.. . - Subject: RE: 1 C-21 extented From: "Lowry, Scott L" <Scott.L.Lowry@conocophillips.com> Date: Mon, 06 Jun 2005 15:47:47 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Thanks Tom! We just got the targets to the directional planner. Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 06, 2005 3:16 PM To: Lowry, Scott L Cc: Thomas, Randy L; Billingsley, Tim A Subject: 1C-21 extented Scott, et al: If you desire to extend 1C-21 beyond 499' in length, then a new permit to drill application is necessary. The well name and API number will not change. You should get us a message describing the plans with rough directional plot. Operations should not be held up with the new paperwork processing, however the paperwork should be in as soon as practical. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 6/9/2005 10: 13 AM Re: lC-21, et al e e .. Subject: Re: lC-21, et al From: Thomas Maunder <torn _ maunder@admin.state.ak.us> Date: Tue, 29 Mar 2005 06:54:52 -0900 To: "Lowry, Scott L" <Scott.L.Lowry@conocophillips.com> d-O 5 -O~~ Scott, There shouldn't be anything further needed with regard to the change in the directional plan. I will place a copy ofthis message in the file. Thanks for checking regarding running the diverter. Torn Maunder, PE AOGCC Lowry, Scott L wrote: Tom, Attached is the revised directional plan. Pushing the kick-off point a little deeper makes the anti-collision situation a lot better. The casing points changed slightly. Please let me know if you need any more info on this change. Our folks went out to lC pad and surveyed the location. We should be able to run our diverter line beneath the flow lines without any modifications. We have a about 4' of clearance beneath the cable tray. We shouldn't be pointed at any charged lines. I will let you know if anything changes. Thanks, Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 -----Original Message----- From: Thomas Maunder [mailto:tom maunde:c@admin.state.ak.us] Sent: Monday, March 14, 2005 10:12 AM To: Lowry, Scott L Subject: Re: lC-21, et al Scott, If the diverter line winds up pointing at "charged" lines and electrical cables, I'd like to know what contingency plan is in place to secure/de-energize if a divert event were encountered. I know the likelihood is low, but it is not zero. Thanks, Tom Thomas Maunder wrote: Scott, I am looking at your lC-21. Will there be a need to modify the diverter line due to flowlines, etc?? If so, you should send in a request for waiver according to 20 AAC 25.035(h) . Thanks, 10f2 3/2912005 6:59 AM ) ~ 6/9/2005 DA" G k ¡:, 5' "-14"" PAYTOTHE ðlaSY",;¡ 0 í / Cjll/t! (JC{(. aN&eVVarf-¡"r;v¡ {ßMM. $·/0 6 ORDER OF 17 f' f-">l:U 0 ,. ð OW i? I L, .^ ¡þO/INJ /' D.^' I\J ... J (J a 4d _ A ~:¡::~''''''.' C t'JV/' '{IV' L{.í\. v¿, Ot /,/ V ~OLL'\f!,.S l.!J ,.."""". ~.... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars . , ~OD White Clay Center Dr., Newllrk, DE 19711 . 1~~:~!~~~~~~(~aqBBb ~qo;';~@~~ DELIA BROWN CONOCOPHILLlPS ATO 1534 700 G ST. ANCHORAGE AK 99501 :«(; 508:;¿ 5 1021 , , . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME be/.{ ¡¿--2( (Ø~/.5S.~(¿ ~ 2D6---û3~ cL~ ) PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well_, Permit No, API No. Production should continue to be reported as a function of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 04/01105 C\j ody\trans m ittal_ checklist The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1C-21 Program DEV Well bore seg 0 Company CONOCOPHILLlPS ALASKA INC nitial ClasslType DEV 11-01L GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 0 Administration 1 P~rmit fee attached_ _ Yes _ _ _ ,ð.ppJiçation tpcbange approved prpgramafterdrilJing QPeratiQn$ _started_: contilJue_drillilJg tpa_deeper TD-" _ _ 2 _Leas~ _nµmber _appropriate_ - - - - - - - _ _ _ _ _ _ _ _No _ _ _ _ _ Corrected omission on 10-407: surfaçe_loçation_ iIJ API,. 02~6<19, JopprodjlJ API,. 0282<12, TP is nowin ADL 02824 3 _U_nlqµewell_n_arn~_a[1d IJumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - _Y~s _ _ _ _ _ I?r~viou_spermitforJÇ,2UI?TD f\lo.J~9Q13Q)_expired PIJ ;2/22/2QOJ._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJI JQcated ina defjnedpool_ - - - - - - - - Y~s _ _ _ _ _ Kup<:lruk River Oil fJo_oL governed by Con_servatiolJ Ord_er No. 432G _ 5 WeJUQcated prpper _distance from driJling unitbounda¡y _ _ _ Yes _ _ _ _ _ ConservatiolJ Order No. 432G çontain$no $pa_cing re_strictions with_ respectto a drilling _unit. _ 6 WellJocat~d prpperdlstance from otber welJs_ Yes _ _ _ Con_servatiplJ Ord_er No. 432G bas_np jnterweILspaçingre::>trictions, 7 Sufficient _acreage_aYail<:lble indrilliIJg unjt_ _ _ Yes _ WelJborewill be_more th<:lIJ 5QO' {rom extemal bou_ndary._ 8 Jfdevi<lted, js_ weJlbQre platincJuded _ - - - - - - _Y~s - - - - - - - - - - - - - - 9 _Operator only affected party _ - Y~s - - - - - - 10 _Operator bas_apprpprlateJlond inJorce _ _ _ _ _ _ _ _ - - ~ - - ~ - - - - - - - - - - - - - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 P~[mit caIJ be issued witbQut co_nserva_tion order_ - - - Y~s - - - - - - Appr Date 12 P~rmit can be issued wjtbQut administratilleapprpvaJ - - - - - - - - - - - - - - Y~s - - - - - - - - - - - - - - - - - SFD 6/8/2005 13 Can permit be approved before 15-day wait Yes .. 14 WelUocated wiJhin <lrea <lnd_strata _authorized by IIJjeçtipIJ Order # (pµUO# incprnrneIJts) (For NA - - - - - - - - - - - - - - - - 15 AJI welJs_wit!1jnJl4J1]ile_area_of reyiew jd~IJtified (Fpr servjc~-,^,ell onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injeçtor; dur<:ltiQnof pre-produGtion I~ss_ than_ 3 months (For service well onJy) _ _ NA - - - - - - - - 17 AÇMP_ finding of Con_siste[1çyhas been issµed_ for_ tbis project NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~----_._---- Engineering 18 CO[1ductor string_provided _ _ _ _ Yes - - - - - - - - - - - - 19 S_urfaœcasingprotects alLkIlown USDWs _ ..... .NA _ All aquifer::> ex_ernpted,AOCfRH7.1Q2(b)(3). . 20 _CMT vol adeQuate_ to çi rc_u tate_ oIl_cond_uçtor_ 8. su_rf_ C$g _ ...... Y~s - - - - - - - - - - - 21 CMT vol adeQuateto tie-in Jong string to_surf csg_ _ _ _ _ _ ...... No . . . . Any hydroçarboIl Zone$ wHlbecO\lere_d, A[1nuJaJ di$PQsaLmaybe propo::>ed. 22 CMT will çoyer_aU known-Pfo_dµçtiye bori~ons No_ . SlottedJilJercompletion ptaIJned. - - - - - - - - 23 C_asi[1g designs adequa_te fp[ CoT, B _&_ permafr_ost ...... Yes - - - - - - - - - - - - - - - - 24 Adequi3te_tc¡n_kage_or reserve pit. - - - Y~s _ . . Rig iseqµippedwith steelpit::>.. NQ reseJ\lepjtplaIllJed, Wasteto <lpprQved al1nµlus or_djsposal wells._ 25 J(aJe-driIL hasa to-403 fQr <:IbandonmeIlt be~IJ apprQved . . - - - - - - - .. NA 26 Adequ<:lte _well bore separatjo_n _proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - Y~s _ _ _ _ _ I?rp~imtty- an<:llysis perf9rme_d, Shallpw jnterferançe_ identifje_d, !3yro$ ptObabJe_. _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdiverterrequired, dQe$ jLmeet reguJations_ _ _ - - - - - - - - ...... Y~s - - - - - - - Appr Date 128 _DrilliIJg fluid program schem<ltic& eCl-uip Jistadequate_ ...... Y~s _ _ _ . . Expeçted Kupform<:ltionpressure::> 7.3 - 9-'1 EMW. _F'lanIled mud weigh_ts as_n_eededin Kup, but 9.2Ji~ely. . TEM 6/9/2005 29 _BOPEs,dp Jhey meet reguJaJion . _ _ ...... Y~s - - - - - - - - - - - - - - - - - . 30 _BOPEpress raJiIJg <lppropriate; test to (put psig Lncomments) - - - - - - -- Yes _ . . MASfJ calçuJatedat 2493 psi, 3500 p$i appropriate, CPN usually te_ststo 5QOO psi._ _ _ - - - - - - 31 _ChokeJDanjfold compJies w/API RfJ-53 (May 84) Y~s . - . - ÑÖ CHÀÑGEŠ iÒENTIFIÈÒ FOR THISRÈVISION. ~ . 4~~ r.(c . . . 32 WQrk will oçcur withoutoperatioIlsbutdown_ - Y~s -~---------------------------------------------,- 33 Js presençe_ oJ H2S g<ls prob_able _ ...... Y~s _ DS :I C !1<1S_ H2S_. _Mu_d_shouJd_ preclude H2S PIJ rig. _ Rig h<lsse[1sors andalarms_. . 34 Mecl)a_nlcal_qmdition pi wells within AOR yerified (For service weU ol1ly). _ _NA - - - - - - - - Geology 35 P~rmitca[1 be issued w!o_ hydrogen_s_ulfide measures. No_ _ _ _ _ _ KRU :lC-Pad welts _ha\le_mea$ured 2Q -_9_0ppmH2S, 36 _D_ata_presented 011 pote_ntial pverpres_sµre _Zone$_ - - - - - - - ..... Y~s . . . . . Expeçted resewojr pressuJe i$7,3_-9Appg EMW; wHl_be_drilled witb 6.5- :10.0 ppg mud. . - - - - - - - - Appr Date 37 _Setsrnic_an<llysjs_ Qf shaJlow gaszPIJes _ NA SFD 6/8/2005 38 _SeabedconditiplJ survey (if off-shpre) . _ _ _ _ NA - - - - - - - - - - - - - - 39 . CQntact namelp!1Ol1eforweekly progress_reports [expIQrato¡y _onlYl NA - - - - - - - - - Geologic Engineering Public "Application is to continue drilling to a deeper TD. Original BHL was targeted to 5256' NFL, 4188' FEL, S. 8, T11 N, R11 E, Commissioner Date: Commissioner: Date Commissioner Date ~ UM. BHL "'eo,oo to 381' FNL, 2293' FWL, S. 17, T11N, R11E, UM. P."",t wm b. "'·',,'ed "'0' ..me API oed P.",,' to DTS [/ ;/0' t.-9-ôS- JKN /~ rill numbers. SFD . . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA. OIL AM» GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lC-21 ConocoPhillips Permit No: 205-034 Surface Location: 1600' FNL, 4089' FEL, SEC. 12, TIIN, RlOE, UM Bottomhole Location: 5256' FNL, 4188' FEL, SEC. 8, TIIN, RllE, UM Dear Mr. Thomas.: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to wi ess any required test. Contact the Commission's petroleum field inspector at (907) 6~607 ger). øe¡y, . i Ju91\.'ie"~an \.....Ø1airìñan DATED this l5'day of March, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com RECEIVED MAR 0 7 Z005 March 3, 2005 AI.aka Oil & Gas Cons. CommilSion Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 1C-21 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well, a horizontal < well in the Kuparuk "C4/C3" sands. The well will be designated as 1C-21. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for this well. The expected spud date of 1C-21 is April 1, 2005. If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, ~\~ Randy Thomas Greater Kuparuk Area Drilling Team Leader 1a. Type of Work: DrillŒ] Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill U MI t.~ RECEIVED MAR 0 7 Z005 ExploratoryU Development ~,~~ Oil & G.fl.GOi.~mn Service 0 Development Gas 0 An~h¡ftíIlUlZone Œ] 5. Bond: LJ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1C-21 6. Proposed Depth: 12. Field/Pool(s): MD: 14147' ~ TVD: 6554' / Kuparuk River Field 7. Property Designation: APL ;¡.n~ ¿..: ADL 28242 11 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1600' FNL, 4089' FEL, Sec. 12, T11N, R10E, UM Top of Productive Horizon: 3567' FNL, 3805' FEL, Sec. 7, T11 N, R11 E, UM Total Depth: 5256' FNL, 4188' FEL, Sec.8, TT1N, R11E, UM Surface: x- 562198 I 4b. Location of Well (State Base Plane Coordinates): y- I 5968638 Zone- Kickoff depth: 300 Maximum Hole Angle: 92° 4 ./ ft. deg 16. Deviated wells: 18. Casing Program Size Hole 24" Casing 16" 13.5" 9-7/8" 6.75" 10.75" 7-5/8" 4.5" 19 Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01 A Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 o Specifications Weight Grade Coupling 62.5# H-40 Welded 45.5# L-80 BTC 29.7" L-80 BTCM 12.6# L-80 IBT ,.{J> ; 'D· cO;- Kuparuk Oil Pool / 8. Land Use Permit: /proximate Spud Date: ALK 2292 " 4/1/2005 9. Acres in Property: //'/ 14. Distance to <I¡8B ' ¡;........... K/W.. 2469 "./ Nearest Property:.~ b""",,"-ll1.'J . 10. KB Elevation. 15. Distance to Nearièt,,-¿(,;,;;;1..3èJ{ ,j.'b (Height above GL): 347kB feet Well within Pool: ~ $¡(:.li; 17. Maximum Antici~ed Pressures in psig (see 20 Me 25.035) ./ Downhole: 3-214 psig Surface: 2493 psig Setting Depth Quantity of Cement c. f. or sacks (including stage data) 9 cu yds High Early 760 sx AS Lite, 370 sx LiteCrete 240 sx Class G slotted liner / Top I Bottom Length MD 1VD MD 1VD 76' 34' " 34' 110' 110' ,. 5571' 34' 34' 5605' 4469' 8972' /34' 34' 9006' 6524' 5291 " 8856' 6513' 14147' 6554' PRESENT WELL CONDITION SUMM RY /Ii (To be completed for Redrill and Re-Entry Operations) Total Depth 1VD (ft): Plugs arnea ¡u;ld) ~ÿctlve Depth MD (ft): Effective Depth 1VD (ft): Junk (measured) Length t~ Volum ( MD TVD ()./ Form 10-401 Revised 06/2004 ~~ Ti v. Depth Plot 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis LJ 20 MC 25.050 requirements 0 Contact Scott Lowry @ 265-6869 Title Greater Kuparuk Area Drilling Team Leader Phone L'J'~!>-o Date ~ ()o( o~ foreDared bv Sharon AI/suo-Drake No ~ No 0 Mud log required Directional survey required APPROVED BY THE COMMISSION ORIGiNAL see cover letter for other requirements Yes 0 Yes~ NoÉ No 0 D,re¥0S Submit in Duplicate · .cation for Permit to Drill, We1l1C-21 Revision No.O Saved: 3-Mar-05 Permit It - Kuparuk Well #1 C-21 Application for Permit to Drill Document Maximize W~II I/gll,/l; Table of Contents 1. Well Name ........ ........... .......... ......... ............ ...... ......... ........... .......... ...... ......... .............. .......... 2 Requirements of 20 AAC 25.005 (f)..... ....... ............................................ .......... .... ....... .... ................ ....... 2 2. Location Summary ................ .................... ........ ..... ....... ............... ................ ......... ............ ... 2 Requirements of 20 AAC 25.005(c)(2) ...... ............ ............. ......... ........... ............ ......... ......... ....... ..... ...... 2 Requirements of 20 AAC 25. 050(b)...... .... .............. ................... ............ ....... ........... ....... ....... ...... ........... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ............ ........ ................................. ............... ....... ....... ....... .......... 3 4. Drill ing 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)(5) .................................................................................................. 3 6. Casi ng and Cementi ng Program ............ ........ ........ ........... ............... ........... ....... ......... 4 Requirements of 20 AAC 25.005(c)(6) ...................... ..... ...... ........... ....... ............ .... ............ ............. ....... 4 7. Diverter System Information .........................................................11.........................4 Requirements of 20 AAC 25.005(c)(7) .............................. .......... ................ ..... ........ .......... .................... 4 8. Dri II i ng FI uid Program .... ........ .............. ......... ..... .............. ................. .............. ........ 5 Requirements of 20 AAC 25.005(c)(B) . ..... ........................... ..... ............. ................ .............. ........ .......... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) .... ......... .................. ................ .......... ..... ................ ................. 5 Lateral Mud Program (MI FloPro)... ......................... ............................. .................. ...................... .......... 5 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) ..............................................................................................".. 6 1 O. Seism ic Analysis............... ........ .............. ......... ............. ............................. ...... ........ 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1C-21 PERMIT IT. doc Page 1 of 8 Printed: 3-Mar-05 OR\GiNAL · .cation for Permit to Drill, Well 1 C-21 Revision No.O Saved: 3-Mar-05 12. Evidence of Bondi ng ........... .............. ............ ......... ....... ......... ..................... .......... ..... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ...... ......... ... ........ ................... ............ ......... ...... .............. ..... .................. ........ 8 Attachment 1 Directional Plan ......... ............... ..... ..... ........... ................................ ............. ...................... 8 Attachment 2 Drilling Hazards Summary. .............. .... ..... ............. ..... .... ...... ..... ....... ............... ....... .......... 8 Attachment 3 Cement Summary. ..... ....... ...... ..... ..... ........... ..... ..... ... ....... ........ ...... ...... ...... ... ...... ..... ..... ... 8 Attachment 4 Well Schematic.... .......... ....... ......................... .......... ............... ............. .... .... ........... ... ...... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branche~ 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 tile number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-21. 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 item~ except for an item already on file wIth the commission and Identified in the application: (2) a plat identifying the plvperty 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. (8) 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 1600' FNL, 4089' FEL, Section 12, TllN, R10E, UM ASP Zone 4 NAD 27 Coordinates I RKB Elevation I 94.8' AMSL Nothings: 5,968,638 /' Eastings: 562,198 ,/ Pad Elevation 60.3' AMSL " Location at Top of Productive Interval (Kuparuk "C4" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,966,716 Eastings: 567,420 3567' FNL, 3805' FEL, Section 7, TllN, RllE, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8,956 6,522 6,427 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,965,073 Eastings: 572,338 5256' FNL, 4188' FEL, Section 8, TllN, RllE, UM Measured Depth, RKB: 14,147 Total Vertical Depth, RKB: 6,554 Total Vertical Depth, 55: 6,459 and (D) other information required by 20 MC 25.050(b),· ORIGINAL 1C-21 PERMIT IT. doc Page 2 of 8 Printed: 3-Mar-05 · ... cation for Permit to Drill, Well 1 C-21 Revision No.O Saved: 3-Mar-05 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 (1) include a plat, drawn to a suitable sca/~ showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: 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 certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) 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: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete weIl1C-21. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pem7it 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: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, mteria used to determine it, and maximum potential sutface pressure based on a methane gradient,' The expected reservoir pressures in the Kuparuk sands in the 1C-21 area vary from 0.38 to 0.49 psi/ft, or /' 7.3 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby Kuparuk wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Kuparuk sand formation is 2,493 psi, calculated thusly: MPSP =(6,560 ft)(0.49 - 0.11 psi/ft) = 2,493 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 Drill must be accompanied by each of the fol/owing items, except for an item already on file wIth the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(!}; 1C-21 PERMIT IT. doc Page 3 of 8 Printed: 3-Mar-05 ORiGiNAL · .cation for Permit to Drill, Well 1 C-21 Revision No.O Saved: 3-Mar-05 A procedure is on file with the commission for performing LOT's. For 1C-21 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Pemlit to Drill must be accompanied by each of the following item~ 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; 4-1/2 6-3/4" slotted Lateral 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 item~ except for an item already on file with the commission and identified 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 MC 25.035(h)(2); Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 24 Length (ft) 76 Top MOfTVO (ft) 34 / 34 8tm MOfTVO (ft) 110 / 110 CsglTbg 00 (in) 16 Weight (Ib/ft) 62.58 Grade H40 Connection Welded 10-3/4 13-1/2 BTC 34 / 34 5605 /4469 5571 45.5 L-80 7-5/8 9-7/8 BTCM 8972 34 / 34 9006 / 6524 29.7 L-80 12.6 8856/6513 14147/6554 L-80 IBT 5291 Cement Program Cemented to surface with 9 cu yd High Early Cemented to Surface with 760 sx ASLite Lead, 370 sx LiteCRETE Tail Cement Top planned @ 8156' MD / 6271'1VD. Cemented w/ 240 sx Class G + additives Slotted- no cement A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1C-21. Please see diagrams of the Doyon 15 diverter system on file with the Commission. U 1\ ï U i l\Jï\Í- 1C-21 PERMIT IT. doc Page 4 of 8 Printed: 3-Mar-05 · .cation for Permit to Drill, Well 1 C-21 Revision No.O Saved: 3-Mar-05 8. Drilling fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pem/it to Drill must be accompanied by each of the following item~ except for 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 drilling fluid system, as required by 20 AAC 25. 03~· Drilling will be done with muds having the following properties over the listed intervals: Surface Interval Spud Mud INTERVAL MUD PROPERTIES Density (ppg) 8.5 - 8.6 9.4 - 9.6 9.4 - 9.6 10.0 Funnel Viscosity (seconds) 250 - 300 250 - 300 200 - 250 200 -250 Yield Point (cP) 50 - 80 50-80 30-60 30 - 60 Plastic Viscosity (lb/100 sf) 8 - 15 11 - 22 12 - 30 12 - 30 10 see Gels (lb/100 sf) 15 - 30 15 - 30 15 - 30 15 - 30 10 min Gels (lb/100 sf) 25 - 55 25 - 55 25 - 65 25 - 65 pH 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 API Filtrate(cc) 8-15 <8 <8 <6 Solids (%) 5-8 5-8 5-8 6 - 10 Intermediate Interval LSND INTERVAL MUD PROPERTIES Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscosity (1b/100 sf) Chlorides pH API filtrate HTHP filtrate MBT Solids ppb 9.4 - 9.5 35 - 41 24 - 30 10 - 15 <600 9-9.5 <6 <10 <20 <11 9.6 - 10.0 38-45 24 - 30 15 - 20 <600 9-10 4-5 <10 <20 <12 ORIGINAL 1C-21 PERMIT IT. doc Page 50f8 Printed: 3-Mar-05 · .ation for Permit to Drill, Well 1 C-21 Revision No.O Saved: 3-Mar-05 Production Drilling Interval Flo Pro Drill-in Fluid PRODUCTION INTERVAL MUD PROPERTIES Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscosity (lb/100 sf) Chlorides pH API filtrate HTH P filtrate MBT Solids ppb 9.2 35-45 20 - 30 10 - 15 <600 9-9.5 <6 <10 <5 <3 /' Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on nJe with the commission and identified in the application: (9) for an exploratory or stratigraphie test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: 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 the following item~ except for an item already on file with the commission and Identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061{a); Not applicable: 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 Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an ¡tern already on file with the commission and identified in the application: (12) evidence showing 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. ORIGINAL 1C-21 PERMIT IT. doc Page 6 of 8 Printed: 3-Mar-05 · .cation for Permit to Drill. We1l1C-21 Revision No.O Saved: 3-Mar-05 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: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Doyon Rig 15. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. RunMWD tools as required for directional monitoring. 3. ~un. and c7ment 10-3/~",~5.5#~ L80, BTC casing to.sUrface. DisPlace~e~n... nt with mud. Perform top Job If reqUired. t\O.\·'~l Co~'':::.S\.c'\'-'", ~ '\ ~ ",(.(:d (:d \ 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. / 5. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD (GR/RES) & PWD. RIH, clean out cement to top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results. 6. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. Do not exceed 18.0 ppg EMW. 7. Directionally drill to 7-5/8" casing point as per directional plan. 8. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud. 9. Install wellhead 7-5/8" packoff and test to 5000 psi. 10. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. / 11. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD (GR/RES/DENS-NEU) logging tools. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 12. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. Do not exceed 16.0 ppg EMW. 13. Directionally drill 6-3/4" hole to TD as per directional plan. 14. POOH, back reaming out of lateral. POOH. 15. PU and run 4-1/2" slotted liner with swell packers as needed. 16. Set liner hanger and ZXP liner top isolation packer. Release hanger running tool. POOH. 17. POOH, laying down drill pipe as required. 18. P/U and run 4-1/2" completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 19. Nipple down BOPE, nipple up tree and test. 20. Move rig off. 21. Pump corrosion inhibited brine into the 4-1/2" x 7-5/8" annulus, and freeze protect the tubing and IA. 22. Pull BPV. Shift sliding sleeve closed. MmA. 23. Set gas lift valves in mandrels. 24. Flow back well to portable test separator to clean up well. 25. Secure well for facility hook-up. 1C-21 PERMIT IT.doc Page 70t8 Printed: 3-Mar-05 ORIGINAL · .cation for Permit to Drill, We1l1C-21 Revision No.O Saved: 3-Mar-05 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 and identified 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 authorization under 20AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on IC Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on IC Pad, 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 (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Summary Attachment 4 Well Schematic ORIGINAL 1C-21 PERMIT IT. doc Page 8 ol8 Printed: 3-Mar-05 . ".. ··~Ph·············II· Conoco ....] ..Ips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 C Pad Plan: 1C·21 Plan: 1C·21 Plan: Plan: 1C·21 (wp08) Standard Planning Report 28 February, 2005 . HALLIBURTON Sperry Drilling Services OR\G\NAL Engineering Kuparuk Calculation Method Minimum Curvature ð¿~ri ~~Wor¿j ~m~~Y¿onic Error Surface Rules Based Warning Method Trav. Cylinder North I I I I I I I 6-3/4'" Hole--9006ft MD, 6524 ft TVD; 35831\ FNL & 37500 FEL; Sec7-T11N-R11E G ¡Iii 2250 1500 , , 750 c ~ o o 1O .- + 'E L o ~ , 'E ::; o (j) I I I 7-5/8'" Csg PT - Continue Dir- I I I I I I . I ¡ I ! I I I 3000 I I I I I I I I 2250 ¡ I i I 1500 I I I I I I 750 3750 4500 West( -)/East( +) (1500 ftlin) SECTION DETAILS I I ! t , ! I I ! 5250 I I I I I I 9000 J I J I ! I ¡ 9750 ! I I I I! I I I I I 7500 8250 6000 6750 Sperry Drilling Services ¡Iii Engineering Kuparuk Calculation Method Error System Scan Method Error Surface: Warning Method: Minimum Curvature ISCWSA Trav. Cylinder North Elliptical Conic Rules Based -4000 7000 ~ -1000-~~ 2000 o o o ~ .c 15- () o (ìj ü t () > () :::J ¡:: 8oo0~~" 9000----- 10000 I ! I J ! I I I I I I i I I ! 1000 tit 2000 I I ¡ I! I I I' -1000 3000 4000 8000 Sperry Drilling Services 1 . . )Þo::/ ConocoPhillips Halliburton Company Planning Report HALLIBURTON Sperry Dñlling Services EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 C Pad Plan: 1 C-21 Plan: 1 C-21 Plan: 1 C-21 (wp08) Well Plan: 1C-21 1 C-21 @ 94.8 @ 94.800f! (94.8 f! above MSL) 1 C-21 @ 94.8 @ 94.800f! (94.8 f! above MSL) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Kuparuk 1 C Pad 0.000f! Northing: Easting: Slot Radius: 5,968,522.4600f! 562,372.0500fl 0" Latitude: Longitude: Grid Convergence: 700 19' 28.285" N 1490 29' 39.293" W 0.4762 0 Site Position: From: Position Uncertainty: Map Well ~- Plan: 1 C-21 Well Position +N/-S +EI-W Position Uncertainty O.OOOf! O.OOOf! 0.000f! Northing: Easting: Wellhead Elevation: 5,968,637.7500 fI 562,198.1200 f! f! Latitude: Longitude: Ground Level: 700 19' 29.434" N 149029' 44.342" W 0.000 f! ~-- Weltbore Plan: 1C-21 bggm2004 11/19/2004 24.5868 80.7693 57,584 Design Audit Notes: Version: Plan: 1C-21 (wp08) 2 Phase: PLAN Tie On Depth: 34.500 34.500 0.000 0.000 109.7401 2/28/200510:51:44AM Page 2 of 9 COMPASS 2003.11 Build 48 ORIGINAL . . ConocJPí,illips Halliburton Company Planning Report HALLIBURTON Sperry Dñlling Services 34.500 0.000 0.0000 34.500 0.000 0.000 0.00 0.00 0.00 0.0000 300.000 0.000 0.0000 300.000 0.000 0.000 0.00 0.00 0.00 0.0000 800.000 15.000 136.0000 794.308 -46.812 45.206 3.00 3.00 0.00 136.0000 1,300.000 15.000 136.0000 1,277.271 -139.902 135.102 0.00 0.00 0.00 0.0000 2,089.625 44.409 109.3248 1,957.999 -309.142 475.460 4.00 3.72 -3.38 -36.8550 7,878.047 44.409 109.3248 6,093.067 -1,649.566 4,297.804 0.00 0.00 0.00 0.0000 8,956.281 87.537 109.0386 6,521.800 -1,965.155 5,206.270 4.00 4.00 -0.03 -0.4183 1 C-21 (Landing pt To 8,971.557 86.927 109.0124 6,522.538 -1,970.128 5,220.694 4.00 -4.00 -0.17 -177.5461 9,364.653 86.927 109.0124 6,543.613 -2,098.004 5,591.811 0.00 0.00 0.00 0.0000 9,491.653 92.002 109.2299 6,544.800 -2,139.590 5,711.760 4.00 4.00 0.17 2.4551 1C-21 (Target 1 Low) 9,495.064 92.003 109.3664 6,544.681 -2,140.716 5,714.977 4.00 0.03 4.00 89.6148 10,207.014 92.003 109.3664 6,519.798 -2,376.660 6,386.233 0.00 0.00 0.00 0.0000 10,307.273 87.994 109.4827 6,519.800 -2,409.996 6,480.765 4.00 -4.00 0.12 178.3375 1C-21 (Target 1 High: 10,318.903 87.536 109.4056 6,520.254 -2,413.865 6,491.724 4.00 -3.94 -0.66 -170.4679 11,104.730 87.536 109.4056 6,554.044 -2,674.716 7,232.223 0.00 0.00 0.00 0.0000 11,207.466 91.621 108.9641 6,554.800 -2,708.469 7,329.230 4.00 3.98 -0.43 -6.1707 1 C-21 (Target 2 Low1 11,220.960 92.125 109.1568 6,554.359 -2,712.873 7,341.977 4.00 3.74 1.43 20.9060 12,262.671 92.125 109.1568 6,515.725 -3,054.480 8,325.326 0.00 0.00 0.00 0.0000 12,445.012 85.312 106.5508 6,519.800 -3,110.337 8,498.723 4.00 -3.74 -1.43 -159.0877 1C-21 (Target 3 High; 12,476.533 84.205 105.9452 6,522.679 -3,119.120 8,528.859 4.00 -3.51 -1.92 -151.4520 12,761.864 84.205 105.9452 6,551.489 -3,197.105 8,801.809 0.00 0.00 0.00 0.0000 12,934.771 90.284 109.2501 6,559.800 -3,249.300 8,966.330 4.00 3.52 1.91 28.6033 1 C-21 (Target 3 Low) 14,147.195 90.284 109.2501 6,553.800 -3,649.023 10,110.951 0.00 0.00 0.00 0.0000 1 C-21 (Target 4) ~~._~.~---~~- 2/28/200510:51:44AM Page 3 of 9 COMPASS 2003.11 Build 48 ORIGINAL . . eol'lOCÓPhillips Halliburton Company Planning Report HALLIBURTON Sperry Drilling Services 34.500 0.000 0.0000 34.500 0.000 0.000 0.000 0.00 0.00 0.00 SHL ~ 1600ft FNL & 4089ftFEL; Sec12-T11N-R10E 100.000 0.000 0.0000 100.000 0.000 0.000 0.000 0.00 0.00 0.00 199.999 0.000 0.0000 199.999 0.000 0.000 0.000 0.00 0.00 0.00 300.000 0.000 0.0000 300.000 0.000 0.000 0.000 0.00 0.00 0.00 300.100 0.000 136.0000 300.100 0.000 0.000 0.000 0.00 0.00 0.00 Begin Dir -- 3.00oDLS, 300.100 ftMD, 300.100 ft TVD 400.000 3.000 136.0000 399.954 -1.883 1.818 2.347 3.00 3.00 0.00 500.000 6.000 136.0000 499.635 -7.526 7.268 9.383 3.00 3.00 0.00 600.000 9.000 136.0000 598.768 -16.914 16.334 21.087 3.00 3.00 0.00 700.000 12.000 136.0000 697.082 -30.022 28.992 37.428 3.00 3.00 0.00 800.000 15.000 136.0000 794.308 -46.812 45.206 58.361 3.00 3.00 0.00 800.100 15.000 136.0000 794.405 -46.831 45.224 58.384 0.00 0.00 0.00 End Dir-5tart $ail--15.000' ,800.100 ft MD, 794.405 ft TVD 900.000 15.000 136.0000 890.901 -65.430 63.185 81.572 0.00 0.00 0.00 1,000.000 15.000 136.0000 987.493 -84.048 81.164 104.782 0.00 0.00 0.00 1,100.000 15.000 136.0000 1,084.086 -102.666 99.143 127.993 0.00 0.00 0.00 1,200.000 15.000 136.0000 1,180.678 -121.284 117.123 151.204 0.00 0.00 0.00 1,300.000 15.000 136.0000 1,277.271 -139.902 135.102 174.415 0.00 0.00 0.00 1,300.100 15.000 136.0000 1.277.367 -139.920 135.120 174.438 0.00 0.00 0.00 Begin Dir- 4.00'DLS, 1300.100ft MD, 1277.367 ft TVD 1,400.000 18.354 128.3650 1,373.062 -158.991 156.445 200.951 4.00 3.36 -7.64 1,500.000 21.920 123.0795 1,466.942 -178.959 184.442 234.047 4.00 3.57 -5.29 1,600.000 25.609 119.2315 1,558.452 -199.709 218.956 273.541 4.00 3.69 -3.85 1,700.000 29.375 116.3039 1,647.148 -221.140 259.819 319.242 4.00 3.77 -2.93 1,800.000 33.192 113.9928 1,732.596 -243.147 306.832 370.925 4.00 3.82 -2.31 1,884.301 36.437 112.3834 1,801.800 -262.069 351.075 418.959 4.00 3.85 -1.91 Base Permafrost 1,900.000 37.043 112.1111 1,814.380 -265.624 359.767 428.340 4.00 3.86 -1.73 2,000.000 40.919 110.5384 1,892.103 -288.460 418.364 491.207 4.00 3.88 -1.57 2,089.625 44.409 109.3248 1,957.999 -309.142 475.460 551.933 4.00 3.89 -1.35 End Dir-5tart Sail--44.409° , 2089.630 ft MD, 1958.003 ft TVD 2,100.000 44.409 109.3248 1,965.411 -311.545 482.311 559.193 0.00 0.00 0.00 2,200.000 44.409 109.3248 2,036.847 -334.701 548.346 629.168 0.00 0.00 0.00 2,300.000 44.409 109.3248 2,108.284 -357.858 614.380 699.144 0.00 0.00 0.00 2,400.000 44.409 109.3248 2,179.721 -381.015 680.414 769.119 0.00 0.00 0.00 2,500.000 44.409 109.3248 2,251.158 -404.172 746.448 839.094 0.00 0.00 0.00 2,600.000 44.409 109.3248 2,322.595 -427.329 812.483 909.069 0.00 0.00 0.00 2,700.000 44.409 109.3248 2,394.032 -450.486 878.517 979.044 0.00 0.00 0.00 2,800.000 44.409 109.3248 2,465.469 -473.643 944.551 1,049.019 0.00 0.00 0.00 2,900.000 44.409 109.3248 2,536.906 -496.800 1,010.586 1,118.994 0.00 0.00 0.00 3,000.000 44.409 109.3248 2,608.342 -519.957 1,076.620 1,188.969 0.00 0.00 0.00 3,100.000 44.409 109.3248 2,679.779 -543.114 1,142.654 1,258.945 0.00 0.00 0.00 3,200.000 44.409 109.3248 2,751.216 -566.271 1,208.688 1,328.920 0.00 0.00 0.00 3,300.000 44.409 109.3248 2,822.653 -589.428 1 ,274.723 1,398.895 0.00 0.00 0.00 3,400.000 44.409 109.3248 2,894.090 -612.585 1 ,340.757 1,468.870 0.00 0.00 0.00 3,500.000 44.409 109.3248 2,965.527 -635.742 1,406.791 1,538.845 0.00 0.00 0.00 3,600.000 44.409 109.3248 3,036.964 -658.899 1 ,4 72. 826 1,608.820 0.00 0.00 0.00 3,700.000 44.409 109.3248 3,108.400 -682.056 1,538.860 1,678.795 0.00 0.00 0.00 3,800.000 44.409 109.3248 3,179.837 -705.213 1,604.894 1,748.770 0.00 0.00 0.00 3,854.541 44.409 109.3248 3,218.800 -717.844 1,640.910 1,786.936 0.00 0.00 0.00 Top Ugnu 3,900.000 44.409 109.3248 3,251p4 -728.370 1,670.928 ~18.745 0·90 0.00 0.00 2/28/200510:51:44AM Page 40f9 COMPASS 2003.11 Buíld 48 ORIGINAL . . eonocJ'Phillips Halliburton Company Planning Report HALLIBURTON Sperry Drilling Serviees 4,000.000 44.409 109.3248 3,322.711 -751.527 1,736.963 1,888.721 0.00 0.00 0.00 4,100.000 44.409 109.3248 3,394.148 -774.684 1,802.997 1,958.696 0.00 0.00 0.00 4,200.000 44.409 109.3248 3,465.585 -797.841 1,869.031 2,028.671 0.00 0.00 0.00 4,300.000 44.409 109.3248 3,537.022 -820.998 1,935.066 2,098.646 0.00 0.00 0.00 4,400.000 44.409 109.3248 3,608.459 -844.155 2,001.100 2,168.621 0.00 0.00 0.00 4,500.000 44.409 109.3248 3,679.895 -867.312 2,067.134 2,238.596 0.00 0.00 0.00 4,600.000 44.409 109.3248 3,751.332 -890.469 2,133.169 2,308.571 0.00 0.00 0.00 4,700.000 44.409 109.3248 3,822.769 -913.626 2,199.203 2,378.546 0.00 0.00 0.00 4,739.239 44.409 109.3248 3,850.800 -922.713 2,225.114 2,406.004 0.00 0.00 0.00 Top West Sak 4,800.000 44.409 109.3248 3,894.206 -936.783 2,265.237 2,448.521 0.00 0.00 0.00 4,900.000 44.409 109.3248 3,965.643 -959.940 2,331.271 2,518.497 0.00 0.00 0.00 5,000.000 44.409 109.3248 4,037.080 -983.097 2,397.306 2,588.472 0.00 0.00 0.00 5,100.000 44.409 109.3248 4,108.517 -1,006.254 2,463.340 2,658.447 0.00 0.00 0.00 5,200.000 44.409 109.3248 4,179.953 -1,029.411 2.529.374 2,728.422 0.00 0.00 0.00 5,300.000 44.409 109.3248 4,251.390 -1,052.568 2,595.409 2,798.397 0.00 0.00 0.00 5,327.170 44.409 109.3248 4,270.800 -1,058.860 2,613.350 2,817.410 0.00 0.00 0.00 BaseWest Sak 5,400.000 44.409 109.3248 4,322.827 -1,075.725 2,661.443 2,868.372 0.00 0.00 0.00 5,500.000 44 .409 109.3248 4,394.264 -1,098.882 2,727.477 2,938.347 0.00 0.00 0.00 5,600.000 44.409 109.3248 4,465.701 -1,122.039 2,793.511 3,008.322 0.00 0.00 0.00 5,604.618 44.409 109.3248 4,469.000 -1,123.109 2,796.561 3,011.554 0.00 0.00 0.00 10-3/4"Csg pt.. Drill out 9'118" Hole: 5604.618ftMD, 4469.000 ft TVD ·103/4" @5604' MD 5,700.000 44.409 109.3248 4,537.138 -1,145.196 2,859.546 3,078.291 0.00 0.00 0.00 5,800.000 44.409 109.3248 4,608.575 -1,168.353 2,925.580 3,148.273 0.00 0.00 0.00 5,853.509 44.409 109.3248 4,646.800 -1,180.744 2,960.914 3,185.716 0.00 0.00 0.00 COSO 5,900.000 44 .409 109.3248 4,680.012 -1,191.510 2,991.614 3,218.248 0.00 0.00 0.00 6,000.000 44.409 109.3248 4,751.448 -1,214.667 3,057.649 3,288.223 0.00 0.00 0.00 6,100.000 44.409 109.3248 4,822.885 -1,231.824 3,123.683 3,358.198 0.00 0.00 0.00 6,200.000 44.409 109.3248 4,894.322 -1,260.981 3,189.717 3,428.173 0.00 0.00 0.00 6,300.000 44.409 109.3248 4,965.759 -1,284.138 3,255.751 3,498.148 0.00 0.00 0.00 6,400.000 44.409 109.3248 5,037.196 -1,307.295 3,321.786 3,568.123 0.00 0.00 0.00 6,500.000 44.409 109.3248 5,108.633 -1,330.452 3,387.820 3,638.098 0.00 0.00 0.00 6,600.000 44.409 109.3248 5,180.070 -1,353.609 3,453.854 3,708.074 0.00 0.00 0.00 6,700.000 44.409 109.3248 5,251.507 -1,376.766 3,519.889 3,778.049 0.00 0.00 0.00 6,800.000 44.409 109.3248 5,322.943 -1,399.923 3,585.923 3,848.024 0.00 0.00 0.00 6,900.000 44.409 109.3248 5,394.380 -1,423.080 3,651.957 3,917.999 0.00 0.00 0.00 7,000.000 44.409 109.3248 5,465.817 -1 ,446.237 3,717.991 3,987.974 0.00 0.00 0.00 7,100.000 44.409 109.3248 5,537.254 -1,469.394 3,784.026 4,057.949 0.00 0.00 0.00 7,200.000 44.409 109.3248 5,608.691 -1,492.551 3,850.060 4,127.924 0.00 0.00 0.00 7,300.000 44.409 109.3248 5,680.128 -1,515.708 3,916.094 4,197.899 0.00 0.00 0.00 7,400.000 44.409 109.3248 5,751.565 -1,538.865 3,982.129 4,267.874 0.00 0.00 0.00 7,500.000 44.409 109.3248 5,823.001 -1,562.022 4,048.163 4,337.850 0.00 0.00 0.00 7,510.917 44.409 109.3248 5,830.800 -1,564.550 4,055.372 4,345.489 0.00 0.00 0.00 C-40 7,600.000 44.409 109.3248 5,894.438 -1,585.179 4,114.197 4,407.825 0.00 0.00 0.00 7,700.000 44.409 109.3248 5,965.875 -1,608.336 4,180.232 4,477.800 0.00 0.00 0.00 7,800.000 44.409 109.3248 6,037.312 -1,631.493 4,246.266 4,547.775 0.00 0.00 0.00 7,878.047 44.409 109.3248 6,093.067 -1,649.566 4,297.804 4,602.389 0.00 0.00 0.00 Begin Dir-· 4.00oDLS, 1818.100 ft MD, 6093.104ft TVD 7,900.000 45.285 109.3158 6,108.631 -1,654.688 4,312.413 4,617.870 3.99 3.99 -0.04 7,918.844 46.040 109.3083 6,121.800 -1,659.146 4,325.133 4,631·-ª~L_.__ 4.01 4.01 -0.04 2/28/200510:51:44AM Page 5 of 9 COMPASS 2003.11 Build 48 ORIGINAL J . . eonoc6'Á,illips Halliburton Company Planning Report HALLIBURTON Sperry Dñlling Services TC)p HRZ 8,000.000 49.285 109.2779 6,176.450 -1,678.964 4,381.747 4,691.328 4.00 4.00 -0.04 8,100.000 53.285 109.2443 6,238.980 -1,704.697 4,455.393 4,769.338 4.00 4.00 -0.03 8,200.000 57.285 109.2140 6,295.916 -1,731.764 4,532.992 4,851.519 4.00 4.00 -0.03 8,300.000 61.285 109.1864 6,346.981 -1,760.032 4,614.167 4,937.470 4.00 4.00 -0.03 8,397.315 65.179 109.1614 6,390.800 -1,788.563 4,696.218 5,024.336 4.00 4.00 -0.03 Base HRZ 8,400.000 65.285 109.1607 6,391.925 -1,789.363 4,698.521 5,026.774 3.95 3.95 -0.02 8,500.000 69.285 109.1367 6,430.530 -1,819.615 4,785.644 5,118.995 4.00 4.00 -0.02 8,545.054 71.088 109.1263 6,445.800 -1,833.506 4,825.688 5,161.377 4.00 4.00 -0.02 K-1 8,600.000 73.285 109.1139 6,462.608 -1,850.639 4,875.111 5,213.684 4.00 4.00 -0.02 8,700.000 77 .285 109.0921 6,488.002 -1,882.286 4,966.487 5,310.379 4.00 4.00 -0.02 8,800.000 81.285 109.0709 6,506.589 -1,914.401 5,059.326 5,408.609 4.00 4.00 -0.02 8,815.117 81.891 109.0677 6,508.800 -1,919.287 5,073.460 5,423.562 4.01 4.01 -0.02 TC)p Kuparuk 8,900.000 85.284 109.0502 6,518.278 -1,946.827 5,153.177 5,507.896 4.00 4.00 -0.02 8,956.281 87.537 109.0386 6,521.800 -1,965.155 5,206.270 5,564.059 4.00 4.00 -0.02 C4 -1C-21 (Landing ÞtTC)! C) 8,971.557 86.927 109.0124 6,522.538 -1,970.128 5,220.694 5,579.315 4.00 -4.00 -0.17 9,000.000 86.927 109.0124 6,524.063 -1,979.381 5,247.547 5,607.715 0.00 0.00 0.00 9,006.000 86.927 109.0124 6,524.384 -1,981.333 5,253.211 5,613.706 0.00 0.00 0.00 7-5/8" Csg PT--Continue Oir- Begin 6-3/4" HC)le-9006ft MO, 6524 ft TVO; 3583ft FNL & 3159ft FEL; Sec7-T11N-R11E -7-5/S"@9006' MO 9,100.000 86.927 109.0124 6,529.424 -2,011.912 5,341.956 5,707.564 0.00 0.00 0.00 9,200.000 86.927 109.0124 6,534.785 -2,044.442 5,436.364 5,807.412 0.00 0.00 0.00 9,300.000 86.927 109.0124 6,540.147 -2,076.972 5,530.773 5,907.260 0.00 0.00 0.00 9,364.653 86.927 109.0124 6,543.613 -2,098.004 5,591.811 5,971.815 0.00 0.00 0.00 9,391.460 87.998 109.0584 6,544.800 -2,106.739 5,617.127 5,998.593 4.00 4.00 0.17 1 C-21 (Target 2 Low) 9,400.000 88.338 109.0729 6,545.073 -2,109.527 5,625.195 6,007.128 3.98 3.98 0.17 9,491.653 92.002 109.2299 6,544.800 -2,139.590 5,711.760 6,098.760 4.00 4.00 0.17 1 C-21 (Target 1 LC)w) 9,495.064 92.003 109.3664 6,544.681 -2,140.716 5,714.977 6,102.168 4.00 0.03 4.00 9,500.000 92.003 109.3664 6,544.508 -2,142.352 5,719.631 6,107.102 0.00 0.00 0.00 9,600.000 92.003 109.3664 6,541.013 -2,175.493 5,813.915 6,207.039 0.00 0.00 0.00 9,700.000 92.003 109.3664 6,537.518 -2,208.633 5,908.199 6,306.975 0.00 0.00 0.00 9,800.000 92.003 109.3664 6,534.023 -2,241.774 6,002.483 6,406.912 0.00 0.00 0.00 9,900.000 92.003 109.3664 6,530.528 -2,274.914 6,096.768 6,506.849 0.00 0.00 0.00 10,000.000 92.003 109.3664 6,527.033 -2,308.055 6,191.052 6,606.786 0.00 0.00 0.00 10,100.000 92.003 109.3664 6,523.538 -2,341.195 6,285.336 6,706.722 0.00 0.00 0.00 10,200.000 92.003 109.3664 6.520.043 -2,374.336 6,379.620 6,806.659 0.00 0.00 0.00 10,207.014 92.003 109.3664 6,519.798 -2,376.660 6,386.233 6,813.669 0.00 0.00 0.00 10,300.000 88.285 109.4743 6,519.564 -2,407.572 6,473.913 6,906.637 4.00 -4.00 0.12 10,307.273 87.994 109.4827 6,519.800 -2,409.996 6,480.765 6,913.905 4.00 -4.00 0.12 1C-21 (Target 1 High) 10,318.903 87.536 109.4056 6,520.254 -2,413.865 6,491.724 6,925.526 4.00 -3.94 -0.66 10,400.000 87.536 1 09.4056 6,523.741 -2,440.784 6,568. 143 7,006.547 0.00 0.00 0.00 10,500.000 87.536 109.4056 6,528.041 -2,473.979 6,662.375 7,106.453 0.00 0.00 0.00 10,600.000 87.536 1 09.4056 6,532.341 -2,507.174 6,756.607 7,206.359 0.00 0.00 0.00 10,700.000 87.536 109.4056 6,536.641 -2,540.368 6,850.839 7,306.265 0.00 0.00 0.00 10,800.000 87.536 1 09.4056 6,540.941 -2,573.563 6,945.070 7,406.171 0.00 0.00 0.00 10,900.000 87·~~___j99.4056 6,545.241 -2,606.757 7,039.302 7,506.076 Oºº-- 0.00 0.00 2/28/200510:51:44AM Page 60'9 COMPASS 2003.11 Build 48 ORI GINAL . . ConocJ)hillips Halliburton Company Planning Report HALLIBURTON Sperry Dñlling Services 11,000.000 87.536 1 09.4056 6,549.541 -2,639.952 7,133.534 7,605.982 0.00 0.00 0.00 11,100.000 87.536 109.4056 6,553.841 -2,673.146 7,227.766 7,705.888 0.00 0.00 0.00 11,104.730 87.536 109.4056 6,554.044 -2,674.716 7,232.223 7,710.613 0.00 0.00 0.00 11,200.000 91.324 108.9961 6,554.992 -2,706.042 7,322.172 7,805.857 4.00 3.98 -0.43 11,207.466 91.621 108.9641 6,554.800 -2,708.469 7,329.230 7,813.320 4.00 3.98 -0.43 1 C-21 (Target 2 Low1) 11,220.960 92.125 109.1568 6,554.359 -2,712.873 7,341.977 7,826.806 4.00 3.74 1.43 11,300.000 92.125 109.1568 6,551.428 -2,738.793 7,416.589 7,905.787 0.00 0.00 0.00 11,400.000 92.125 109.1568 6,547.719 -2,771.586 7,510.986 8,005.713 0.00 0.00 0.00 11,500.000 92.125 109.1568 6,544.010 -2,804.379 7,605.384 8,105.639 0.00 0.00 0.00 11,600.000 92.125 109.1568 6,540.301 -2,837.171 7,699.781 8,205.565 0.00 0.00 0.00 11,700.000 92.125 109.1568 6,536.593 -2,869.964 7,794.179 8,305.491 0.00 0.00 0.00 11,800.000 92.125 109.1568 6,532.884 -2,902.757 7,888.576 8,405.417 0.00 0.00 0.00 11,900.000 92.125 .109.1568 6,529.175 -2,935.550 7,982.974 8,505.343 0.00 0.00 0.00 12,000.000 92.125 109.1568 6,525.467 -2,968.343 8,077.371 8,605.269 0.00 0.00 0.00 12,100.000 92.125 109.1568 6,521.758 -3,001.136 8,171.768 8.705.195 0.00 0.00 0.00 12,200.000 92.125 109.1568 6,518.049 -3,033.928 8,266.166 8,805.121 0.00 0.00 0.00 12,262.671 92.125 109.1568 6,515.725 -3,054 .480 8,325.326 8,867.746 0.00 0.00 0.00 12,300.000 90.732 108.6245 6,514.795 -3,066.561 8,360.632 8,905.058 3.99 -3.73 -1.43 12,400.000 86.996 107.1967 6,516.780 -3,097.302 8,455.748 9,004.967 4.00 -3.74 -1.43 12,445.012 85.312 106.5508 6,519.800 -3,110.337 8,498.723 9,049.820 4.00 -3.74 -1.43 1 C-21 (Target 3 High) 12,476.533 84.205 105.9452 6,522.679 -3,119.120 8,528.859 9,081.151 4.00 -3.51 -1.92 12,500.000 84.205 105.9452 6,525.049 -3,125.534 8,551.307 9,104.446 0.00 0.00 0.00 12,600.000 84.205 105.9452 6,535.146 -3,152.865 8,646.968 9,203.717 0.00 0.00 0.00 12,700.000 84.205 105.9452 6,545.242 -3,180.197 8,742.629 9,302.988 0.00 0.00 0.00 12,761.864 84.205 105.9452 6,551.489 -3,197.105 8,801.809 9,364.401 0.00 0.00 0.00 12,800.000 85.543 106.6767 6,554.895 -3,207.773 8,838.262 9,402.315 3.99 3.51 1.92 12,900.000 89.059 108.5867 6,559.601 -3,238.027 8,933.439 9,502.116 4.00 3.52 1.91 12,934.771 90.284 109.2501 6,559.800 -3,249.300 8,966.330 9,536.883 4.01 3.52 1.91 1C-21 (Target 3 Low) 13,000.000 90.284 109.2501 6,559.477 -3,270.805 9,027.911 9,602.108 0.00 0.00 0.00 13,100.000 90.284 109.2501 6,558.982 -3,303.774 9,122.319 9,702.103 0.00 0.00 0.00 13,200.000 90.284 109.2501 6,558.487 -3,336.743 9,216.726 9,802.098 0.00 0.00 0.00 13,300.000 90.284 109.2501 6,557.993 -3,369.712 9,311.134 9,902.094 0.00 0.00 0.00 13,400.000 90.284 109.2501 6,557.498 -3,402.681 9,405.542 10,002.089 0.00 0.00 0.00 13,500.000 90.284 109.2501 6,557.003 -3,435.650 9,499.949 10,102.084 0.00 0.00 0.00 13,600.000 90.284 109.2501 6,556.508 -3,468.619 9,594.357 10,202.079 0.00 0.00 0.00 13,700.000 90.284 109.2501 6,556.013 -3,501.588 9,688.765 10,302.074 0.00 0.00 0.00 13,800.000 90.284 109.2501 6,555.518 -3,534.556 9,783.172 10,402.069 0.00 0.00 0.00 13,900.000 90.284 109.2501 6,555.023 -3,567.525 9,877.580 10,502.064 0.00 0.00 0.00 14,000.000 90.284 109.2501 6,554.528 -3,600.494 9,971.988 10,602.059 0.00 0.00 0.00 14,100.000 90.284 109.2501 6,554.034 -3,633.463 10,066.395 10,702.054 0.00 0.00 0.00 14,147.195 90.284 109.2501 6,553.800 -3,649.023 10,110.951 10,749.247 0.00 0.00 0.00 TI>(6HLj --14147.190 ft MD, 6553.800 ft TVD, 5256ft FNL & 4188ft FEL, Sec8-T11N-Rl1E - 41/2" @TD-tC-21 (Targøt4) 2/28/200510:51:44AM Page 7 of 9 COMPASS 2003.11 Build 48 R\G\NAL . . ~illips Halliburton Company Planning Report HALLIBURTON Sperry Dñlling Services EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 C Pad Plan: 1C-21 Plan: 1 C-21 Plan: 1C-21 (wp08) Well Plan: 1 C-21 1 C-21 @ 94.8 @ 94.800ft (94.8 ft above MSL) 1 C-21 @ 94.8 @ 94.800ft (94.8 ft above MSL) True Minimum Curvature 1 C-21 (Landing PI Top 0.00 - plan hits target - Circle (radius 1,320.000) 1C-21 (Target 2 Low) 0.00 0.00 6,544.800 -2,500.490 6,766.430 5,966,193.6646 568,984.3945 - plan misses by 282.599ft at 10889.750ft MD (6544.800 TVD, -2603.355 N, 7029.643 E) - Point 1C-21 (Target 3 High) -5.00 - plan hits target - Point 1C-21 (Target 1 High) - plan hits target - Point 0.00 6,519.800 -3,110.337 8,498.723 5,965,598.2535 570,721.5173 70018' 58.796" N 149025' 36.382" W 0.00 6,521.800 -1,965.155 5,206.270 5,966,716.0000 567,420.0000 70019'10.089" N 149027' 12.420" W 700 19' 04.811" N 1490 26' 26.908" W -1.25 0.00 6,519.800 -2,409.996 6,480.765 5,966,281.7793 568,698.0171 700 19' 05.704" N 1490 26' 35.241" W 1 C-21 (Target 4) 0.00 0.00 6,553.800 -3,649.023 10,110.951 5,965,073.0000 572,338.0000 - plan misses by 1360.35Oft at 12786.602ft MD (6553.800 TVD, -3203.969 N, 8825.463 E) - Point 70018' 53.479" N 149024' 49.365" W 1 C-21 (Target 2 Low1) 0.00 0.00 6,554.800 -2,708.469 7,329.230 5,965,990.3768 569,548.8455 70019' 02.761" N 149026' 10.492" W - plan hits target - Point 1C-21 (Target 1 Low) 0.00 0.00 6,544.800 -2,139.590 5,711.760 5,966,545.7767 567,926.8705 700 19' 08.370" N 1490 26' 57.673" W - plan hits target - Point 1 C-21 (Target 3 Low) 0.00 0.00 6,559.800 -3,249.300 8,966.330 5,965,463.1845 571,190.2147 70018' 57.424" N 149025' 22.744" W - plan hits target - Point 5,604.618 9,006.000 14,147.100 4,469.000 103/4" @ 5604' MD 6,524.384 7-5/8"@ 9006' MD 6,553.800 4 1/2" @ TO 1 0-3/4 9-7/8 4-1/2 13-1/2 9-7/8 6-3/4 1,884.301 3,854.541 4,739.239 5,327.170 5,853.509 7,510.917 7,918.844 8,397.315 8,545.054 8,815.117 8,956.281 2/281200510:51:44AM 1,801.800 Base Permafrost 3,218.800 Top Ugnu 3,850.800 Top West Sak 4,270.800 Base West Sak 4,646.800 C-80 5,830.800 C-40 6,121.800 Top HRZ 6,390.800 Base HRZ 6,445.800 K-1 6,508.800 Top Kuparuk 6,521 .800 C4 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Page 8 of 9 COMPASS 2003.11 Build 48 ORIGINAL . . Conoc;pí,illips Halliburton Company Planning Report HALLIBURTON Sperry Drilling Services 34.500 300.100 800.100 1,300.100 2,089.630 5,604.618 7,878.100 9,006.000 14,147.190 34.500 300.100 794.405 1,277.367 1,958.003 4,469.000 6,093.104 6,524.384 6,553.800 0.000 0.000 -46.831 -139.920 -309.143 -1,123.109 -1,649.579 -1,981.333 -3,649.021 0.000 0.000 45.224 135.120 475.463 2,796.561 4,297.839 5,253.211 10,110.946 SHL -- 16000 FNL & 4089ftFEL; Sec12-T11 N-R10E Begin Dir -- 3.00"DLS, 300.100 ft MO, 300.100 ft NO End Oir-Start Sall--15.000" , 800.100 ft MD, 794.405 ft ND Begin Dir--4.00"OLS, 1300.100ftMO, 1277.367ftND End Oir-Start Sail--44.409" ,2089.630 ft MO, 1958.003 ft NO 10-3/4" Csg PI-- Drill out 9-7/8" Hole: 5604.618ft MD, 4469.000 ft ND Begin Dir -- 4.00'OLS, 7878.100 ft MO, 6093.104 ft ND 7-5/8" Csg PT-- Continue Oir- Begin 6-3/4" Hole-9006ft MO, 6524 ft NO; 3583' TO (BHL) -- 14147.190 ft MO, 6553.800 ft ND, 5256f1 FNL & 4188ft FEL, Sect 2/28/200510:51:44AM Page 90'9 COMPASS 2003.11 Build 48 OR\G\NAL +W·S WELL DETAILS: Plan:1C·21 GroundL",vjò¡' 0.000 NorthIng fasting latirtude Long!1ude 5268637.7500 E7(~~~~~~g ANTI-COLLISION SEITINGS Interpolation Method: MD Interval: 25Stations Reference: Plan: 1 C-21 (wp08) Depth Range From: 34.500 To 14147.195 Maximum Range:1611.26952202881 From Colour To MD 34 300 300 400 400 500 500 750 750 1000 1000 1250 0 1250 1450 1450 1750 1750 2000 2000 2500 2500 3000 3000 3500 3500 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 10000 10000 11000 11000 12000 12000 13000 90 13000 14000 14000 15000 15000 16000 16000 17000 17000 18000 18000 19000 190JO 2000C 180 Travelling Cylinder Azimuth (TFO+AZI) ¡oj vs Centre to Centre Separation [50 ft/in] 180 Travelling Cylinder Azimuth (TFO+AZI) [0] vs Centre to Centre Separation [10 ftlin] · . eonocóPhUlips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 C Pad Plan: 1 C-21 Plan: 1 C-21 Plan: 1 C-21 (wp08) Travelling Cylinder Report 25 February, 2005 HALLIBURTON Sperry Drilling Services ORIGIN/t\L . . Co~illips Halliburton Company Anticollision Report HALLIBURTON Sperry Drilling Services ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 C Pad O.OOOft Plan: 1 C-21 O.OOOft Plan: 1 C-21 Plan: 1 C-21 (wp08) Plan: 1C-21 (wp08) Well Plan: 1C-21 1G-21 @ 94.8 @ 94.800ft (94.8 ft above MSL) 1 G-21 @ 94.8 @ 94.800ft (94.8 ft above MS L) True Minimum CUNature .00 sigma EDM 2003.11 Single User Db Offset Datum Filter type: GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD InteNal 50.000ft Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Maximum center-center distance of 1,607.931 ft Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic 34.500 1,640.000 1,400.000 Plan: 1 C-21 (wp08) (Plan: 1 C-21) 14,147.195 Plan: 1C-21 (wp08) (Plan: 1C-21) CB-GYRO-SS MWD+IFR-AK-CAZ-SC Camera based gyro single shot MWD+IFR AK CAZ SCC Kuparuk 1C Pad 1C-01 -1C-01 -1C-01 1,374.384 1,350.000 44.095 26.86 17.231 Pass - Major Risk 1 C-02 - 1 C-02 - 1 C-02 859.760 850.000 19.153 16.56 2.592 Pass - Major Risk 1 C-03 - 1 C-03 - 1 C-03 349.969 350.000 32.521 6.43 26.095 Pass - Major Risk 1 C-04 - 1 C-04 - 1 C-04 346.941 350.000 160.411 5.88 154.532 Pass - Major Risk 1C-12 - 1 C-12 - 1C-12 3,268.644 3,900.000 207.842 1 45.49 62.355 Pass - Major Risk 1C-131 -1C-131 -1C-131 193.347 200.000 229.914 3.24 226.674 Pass - Major Risk 1C-131 - 1C-131 -1C-131 WP01 293.350 300.000 229.525 5.16 224.365 Pass - Major Risk 1C-133 - 1C-133 - 1C-133 389.271 400.000 212.357 6.70 205.658 Pass - Major Risk 1C-135 -1C-135 -1C-135 154.295 150.000 199.898 2.53 197.369 Pass - Major Risk 1C-135 -1C-135PB1 - 1C-135 (wp02) 353.138 350.000 199.811 6.45 193.365 Pass - Major Risk 1C-135 -1C-135PB1 -1C-135PB1 154.295 150.000 199.898 2.53 197.369 Pass - Major Risk 1C-14 - 1 C-14 - 1 C-14 438.449 450.000 57.075 7.86 49.212 Pass - Major Risk 1C-15 -1C-15 -1C-15 548.785 550.000 57.812 9.77 48.038 Pass - Major Risk 1C-15 -1C-15L1 -1C-15L1 548.583 550.000 57.807 9.77 48.037 Pass - Major Risk 1C-170 -1C-170 -1C-170 351.676 350.000 225.839 6.32 219.517 Pass - Major Risk 1C-170 -1C-170PB1 -1C-170PB1 351.676 350.000 225.839 6.06 219.783 Pass - Major Risk 1 C-172 - 1 C-172 - 1 C-172 306.910 300.000 191.292 5.54 185.748 Pass - Major Risk 1C-174 -1C-174-1C-174 257.581 250.000 156.050 4.42 151.630 Pass - Major Risk 1C-178 -1C-178 -1C-178 355.585 350.000 99.031 5.97 93.066 Pass - Major Risk 1C-178 -1C-178L1 -1C-178L1 355.585 350.000 99.031 6.23 92.800 Pass - Major Risk 1C-178 -1C-178L1PB1 -1C-178L1PB1 355.585 350.000 99.031 5.97 93.066 Pass - Major Risk 1 C-178 - 1 C-178L 1 PB2 - 1 C-178L1 PB2 355.585 350.000 99.031 5.97 93.066 Pass - Major Risk 1C-18 -1C-18-1C-18 338.919 350.000 219.751 5.58 214.167 Pass - Major Risk 1C-19 -1C-19-1C-19 878.012 850.000 141.984 14.94 127.044 Pass - Major Risk 1 C-23 - 1 C-23 - 1 C-23 665.116 650.000 95.240 11.55 83.691 Pass - Major Risk 1 C-23PB1 - 1 C-23PB1 - 1 C-23PB1 665.116 650.000 95.240 11.55 83.691 Pass - Major Risk 1 C-24 - 1 C-24 - 1 C-24 1,059.861 1,050.000 38.277 19.05 19.223 Pass - Major Risk 1 C-25 - 1 C-25 - 1 C-25 928.185 900.000 121.510 16.08 105.434 Pass - Major Risk 1 C-26 - 1 C-26 - 1 C-26 1,582.261 1,550.000 34.847 31.12 3.723 Pass - Major Risk 1 C-27 - 1 C-27 - 1 C-27 935.413 900.000 165.919 17.29 148.627 Pass - Major Risk Plan: 1C-129 -1C-129 -1C-129 (wp01) 2,774.780 2,899.988 136.856 61.06 75.793 Pass - Major Risk Plan: 1C-HEW1 - Plan: 1C-HEW1 - Plan: 1C-HEW 1,016.156 1,050.000 80.969 8.21 72.762 Pass - Minor 1/100 Plan: 1 C-HEW2 - Plan:1 C- HEW2 - Plan: 1 C-HEW 292.793 299.999 31 .253 5.36 25.895 Pass - Major Risk 2/25/200511:14:39AM CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 2 0177 COMPASS 2003.11 Build 48 OR\G\NAL - Plan: Plan: lC-l1 (wpm;) (Plan: lC-ll/Plau: lC~21) , I' ' , 58.0- ... , ..-~ .._c . :~ .. . ' i ¡. '... 56.c~ "C_ .. ¡. ..., . . . . 54.0-;- . . .. , . '. .. , . , '..~'.." . ' '" - .. . , . .c. - " ~_... , "'.. '-.' i , ^^ .. ':.. " , - . ¡"~+'¡ = ' . ' , 48.0--, , ," . ...., .. , i ' 46.0- ' " ¡" . "', ..' .': , . , ·----i\.... ' , 44.0---:= . .... I . i " .... i . ' 42.~ ......" ' ..; .. .. i,' . .,' i .. · " ·..·u··· .. !..:.... 40.0-' , . . ì .' , ... . : .''o . . .. i . . . _ · . . , .v _ I . . -.. - . . i 36.0-- "! . . .' I··.. 34.fJ-"~ . , ' . . ' , . - i , . . , : . . I, '. 32.~ ·~=."r~~~"~.I,~!, : . .., ' : '>li ^ - ¡ . !." 1···'" I. ' , __ : ~ - , '. i II ~~I~' . ! /', ,+ 15 . ,: :_-'i.. ' Ü 28.~ ' ..... . i' . '!4=-.=~/'/'/"" '¡ .8 - '" ': ' .ê 26.0- . I ,-" 8 ::. , ,/. I .' 24 0- . " : ---. , =.' . . :., ! I . " ' 22.0- I .. \ ....-.. . , .... I" . . .' . i - ' .,,' !' I 20.0-:: \ /,,-é'" \ ' .. : = \ . .,...,¡..~~/ , . - 'Z~_'o ,',' ' 18.0-· -.. \ , eø//;..r- ¡,." _. .. ' 16.0-.:: ' ~. .. ~ ' ,. "\.. .'" . . - ' , "', , . .. , . ''o' , ' . .... ¡. , - . : '. I . :' 14.0- : . i .. .. , :', . ,'> - . .' , . .. . !. L"':: .' I . 'i ... ".' ":. . . , 100-= . i " ',.1 . ::, .. . '. I·. . . , '! 80"'::' : .. .. , . ' " . ,.' . = '.. ' .' ¡; ^ I. ! ' .' . ' :. . - :. . . . . . ' , ~. .' " , 4.0-' .' ., . =. 'o! . - , ! ' 2.0-= . ''o : . . ." I"". ..',. ' . ¡: ; i ':': . . ' 0.0 I I I I II I I I 1'1'1'1" I' I " I I , I t 1'1 I t I III I I I I t 1'1' I I I I t I I I I I I I I I' I I I II I II I I I I I I I I II I I I I I I I III I II I1II II I -200 ·1)0 0 100 21íO 300 400 5,)0 600 71íO 800 <)')0 1000 BOO 1200 13:10 li)O 1500 1600 1~00 1800 lÇ:OO VI VI . . lC-21 SHL ORIGINAL" . . lC-21PBHL ORtGtN,AL . . (I ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-21 Plan: 1C-21 Plan: Plan: 1C-21 (wp08) Sperry-Sun GEO Report 28 February, 2005 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan: 1C-21 1C-21 @ 94.8 @94.80Oft (94.8 ft above MSL) N True API - US Survey Feet HALLIBURTON ORtG\NAL . . ConocoPhillips Alaska Inc. (Kuparuk) HALLIBURTON Kuparuk River Unit Plan Report for Plan: 1C-21 - Plan: 1C-21 - Plan: 1C-21 (wp08) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N( -S +EI-W Northing Easting Rate Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0(100ft) (ft) 34.500 0.000 0.0000 -60.300 34.500 100.000 0.000 0.0000 5.200 5,968,637.7500 562.198.1200 199.999 0.000 0.0000 105.199 5,968,637.7500 562,198.1200 300.000 0.000 0.0000 205.200 5,968,637.7500 562,198.1200 300.100 0.000 136.0000 205.300 400.000 3.000 136.0000 305.154 399.954 -1.883 1.818 5,968,635.8825 562,199.9536 3.00 2.347 500.000 6.000 136.0000 404.835 499.635 -7.526 7.268 5,968,630.2852 562.205.4492 3.00 9.383 600.000 9.000 136.0000 503.968 598.768 -16.914 16.334 5.968.620.9733 562,214.5919 3.00 21.087 700.000 12.000 136.0000 602.282 697.082 -30.022 28.992 5.968,607.9725 562.227.3566 3.00 37.428 800.000 15.000 136.0000 699.508 794.308 -46.812 45.206 5.968,591.3184 562,243.7083 3.00 58.361 800.1 00 15.000 136.0000 699.605 794.405 -46.831 900.000 15.000 136.0000 796.101 890.901 -65.430 63.185 5.968.572.8519 562,261.8393 0.00 81.572 1,000.000 15.000 136.0000 892.693 987.493 -84.048 81.164 5.968,554.3854 562,279.9704 0.00 104.782 1,100.000 15.000 136.0000 989.286 1,084.086 -102.666 99.143 5,968,535.9190 562,298.1014 0.00 127.993 1,200.000 15.000 136.0000 1,085.878 1.180.678 -121.284 117.123 5,968,517.4525 562,316.2325 0.00 151.204 1,300.000 136.0000 1,182.471 1,277 .271 5,968,498.9861 562,334.3635 1 00 136.0000 1 562,334.3817 1,400.000 18.354 128.3650 1 .373.062 -158.991 156.445 5,968.480.0766 562,355.8623 4.00 200.951 1.500.000 21 .920 123.0795 1 ,466.942 -178.959 184.442 5,968,460.3431 562,384.0210 4.00 234.047 1,600.000 25.609 119.2315 1 .558.452 -199.709 218.956 5,968,439.8817 562,418.7027 4.00 273.541 1.700.000 1.647.148 5,968,418.7922 562,459.7382 1,800.000 1,732.596 5,968.397.1773 562,506.9277 1 .800 562.551.3214 44.409 109.3248 2,100.000 44.409 109.3248 1,870.611 1,965.411 -311.545 482.311 5,968,330.2433 562.682.9506 0.00 559.193 2,200.000 44.409 109.3248 1,942.047 2,036.847 -334.701 548.346 5,968,307.6366 562,749.1682 0.00 629.168 2,300.000 44.409 109.3248 2,013.484 2.108.284 -357.858 614.380 5,968,285.0299 562.815.3859 0.00 699.144 2.400.000 44.409 109.3248 2.084.921 2,179.721 -381.015 680.414 5.968.262.4233 562,881.6035 0.00 769.119 2,500.000 44.409 109.3248 2,156.358 2,251.158 -404.172 746.448 5.968.239.8166 562,947.8211 0.00 839.094 2,600.000 44.409 109.3248 2.227.795 2.322.595 -427.329 812.483 5.968,217.2099 563.014.0388 0.00 909.069 2,700.000 44.409 109.3248 2.299.232 2,394.032 -450.486 878.517 5.968,194.6032 563,080.2564 0.00 979.044 2,800.000 44.409 109.3248 2.370.669 2,465.469 -473.643 944.551 5,968,171.9965 563,146.4740 0.00 1,049.019 2,900.000 44.409 109.3248 2.442.106 2,536.906 -496.800 1 ,01 0.586 5.968,149.3898 563,212.6917 0.00 1,118.994 3,000.000 44.409 109.3248 2,513.542 2,608.342 -519.957 1 ,076.620 5,968,126.7831 563,278.9093 0.00 1,188.969 3,100.000 44.409 109.3248 2,584.979 2,679.779 -543.114 1,142.654 5,968,104.1764 563.345.1269 0.00 1 ,258.945 3,200.000 44.409 109.3248 2,656.416 2.751.216 -566.271 1,208.688 5,968,081.5697 563,411.3446 0.00 1 ,328.920 3,300.000 44.409 109.3248 2,727.853 2,822.653 -589.428 1,274.723 5,968,058.9630 563,477.5622 0.00 1 ,398.895 3,400.000 44.409 109.3248 2,799.290 2,894.090 -612.585 1,340.757 5.968,036.3563 563,543.7798 0.00 1,468.870 3.500.000 44.409 109.3248 2,870.727 2,965.527 1 ,406.791 5,968,013.7496 563,609.9975 1.538.845 3,600.000 44.409 109.3248 2,942.164 3,036.964 1,472.826 5.967.991.1429 563,676.2151 1,608.820 3,700.000 44.409 109.3248 3,013.600 3,108.400 1 .538.860 5,967,968.5362 563,742.4327 1,678.795 3,800.000 44.409 109.3248 3.085.037 3,179.837 1.604.894 5,967.945.9295 563,808.6504 1,748.770 44.409 109.3248 3,124.000 1 3,900.000 44.409 109.3248 3.156.474 3.251.274 -728.370 1,670.928 5.967,923.3228 563,874.8680 0.00 1,818.745 4,000.000 44.409 109.3248 3,227.911 3,322.711 -751.527 1,736.963 5,967,900.7161 563,941.0856 0.00 1.888.721 4.100.000 44.409 109.3248 3,299.348 3.394.148 -774.684 1,802.997 5,967,878.1094 564,007.3033 0.00 1,958.696 4.200.000 44.409 109.3248 3,370.785 3,465.585 -797.841 1,869.031 5,967,855.5027 564,073.5209 0.00 2,028.671 4,300.000 44.409 109.3248 3,442.222 3,537.022 -820.998 1,935.066 5,967,832.8961 564.139.7385 0.00 2,098.646 4,400.000 44.409 109.3248 3,513.659 3,608.459 -844.155 2.001.100 5,967,810.2894 564.205.9562 0.00 2,168.621 28 February, 2005 - 10:54 Page 2 of 6 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. (Kuparuk) HALLIBURTON Kuparuk River Unit Plan Report for Plan: 1C-21 - Plan: 1C-21 - Plan: 1C-21 (wp08) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 4,500.000 44.409 109.3248 3,585.095 3,679.895 -867.312 2,067.134 5,967,787.6827 564,272.1738 0.00 2,238.596 4,600.000 44.409 109.3248 3,656.532 3,751.332 -890.469 2,133.169 5,967,765.0760 564,338.3914 0.00 2,308.571 4,700.000 44.409 109.3248 3,727.969 3,822.769 -913.626 2,199.203 5,967,742.4693 564,404.6091 0.00 2,378.546 4,739.239 44.409 109.3248 3,756.000 3,850.800 -922.713 2,225.114 5,967,733.5987 564,430.5920 0.00 2,406.004 TopwestSak 4,800.000 44.409 109.3248 3,799.406 3,894.206 -936.783 2,265.237 5,967,719.8626 564,470.8267 0.00 2,448.521 4,900.000 44.409 109.3248 3,870.843 3,965.643 -959.940 2,331.271 5,967,697.2559 564,537.0443 0.00 2,518.497 5,000.000 44.409 109.3248 3,942.280 4,037.080 -983.097 2,397.306 5,967,674.6492 564,603.2620 0.00 2,588.472 5,100.000 44.409 109.3248 4,013.717 4,108.517 -1,006.254 2,463.340 5,967,652.0425 564,669.4796 0.00 2,658.447 5,200.000 44.409 109.3248 4,085.153 4,179.953 -1,029.411 2,529.374 5,967,629.4358 564,735.6972 0.00 2,728.422 5,300.000 44.409 109.3248 4,156.590 4,251.390 -1 ,052.568 2,595.409 5,967,606.8291 564,801.9149 0.00 2,798.397 5,327.1 70 44.409 109.3248 4,176.000 4,270.800 -1,058.860 2,613.350 5,967,600.6868 564,819.9064 0.00 2,817.410 Bas~ W~stSak 5,400.000 44.409 109.3248 4,228.027 4,322.827 -1,075.725 2,661.443 5,967,584.2224 564,868.1325 0.00 2,868.372 5,500.000 44.409 109.3248 4,299.464 4,394.264 -1,098.882 2,727.477 5,967,561.6157 564,934.3501 0.00 2,938.347 5,600.000 44.409 109.3248 4,370.901 4,465.701 -1,122.039 2,793.511 5,967,539.0090 565,000.5678 0.00 3,008.322 5,604.618 44.409 109.3248 4,374.200 4,469.000 -1,123.109 2,796.561 5,967,537.9650 565,003.6258 0.00 3,011.554 1Q,3J4" psg Pt-Drill. out~-118"H()le:ß604.618ft MP'4469.000 ft TVD_10 5,700.000 44.409 109.3248 4,442.338 4,537.138 -1,145.196 2,859.546 5,967,516.4023 565,066.7854 0.00 3,078.297 5,800.000 44.409 109.3248 4,513.775 4,608.575 -1,168.353 2,925.580 5,967,493.7956 565,133.0030 0.00 3,148.273 5,853.509 44.409 109.3248 4,552.000 4,646.800 -1,180.744 2,960.914 5,967,481.6990 565,168.4356 0.00 3,185.716 C,sO 5,900.000 44.409 109.3248 4,585.212 4,680.012 -1 ,191 .51 0 2,991.614 5,967,471.1889 565,199.2207 0.00 3,218.248 6,000.000 44.409 109.3248 4,656.648 4,751.448 -1,214.667 3,057.649 5,967,448.5822 565,265.4383 0.00 3,288.223 6,100.000 44.409 109.3248 4,728.085 4,822.885 -1,237.824 3,123.683 5,967,425.9756 565,331.6559 0.00 3,358.198 6,200.000 44.409 109.3248 4,799.522 4,894.322 -1,260.981 3,189.717 5,967,403.3689 565,397.8736 0.00 3,428.173 6,300.000 44.409 109.3248 4,870.959 4,965.759 -1,284.138 3,255.751 5,967,380.7622 565,464.0912 0.00 3,498.148 6,400.000 44.409 109.3248 4,942.396 5,037.196 -1,307.295 3,321.786 5,967,358.1555 565,530.3088 0.00 3,568.123 6,500.000 44.409 109.3248 5,013.833 5,108.633 -1,330.452 3,387.820 5,967,335.5488 565,596.5264 0.00 3,638.098 6,600.000 44.409 109.3248 5,085.270 5,180.070 -1,353.609 3,453.854 5,967,312.9421 565,662.7441 0.00 3,708.074 6,700.000 44.409 109.3248 5,156.707 5,251.507 -1,376.766 3,519.889 5,967,290.3354 565,728.9617 0.00 3,778.049 6,800.000 44.409 109.3248 5,228.143 5,322.943 -1,399.923 3,585.923 5,967,267.7287 565,795.1793 0.00 3,848.024 6,900.000 44.409 109.3248 5,299.580 5,394.380 -1,423.080 3,651.957 5,967,245.1220 565,861.3970 0.00 3,917.999 7,000.000 44.409 109.3248 5,371.017 5,465.817 -1 ,446.237 3,717.991 5,967,222.5153 565,927.6146 0.00 3,987.974 7,100.000 44.409 109.3248 5,442.454 5,537.254 -1,469.394 3,784.026 5,967,199.9086 565,993.8322 0.00 4,057.949 7,200.000 44.409 109.3248 5,513.891 5,608.691 -1,492.551 3,850.060 5,967,177.3019 566,060.0499 0.00 4,127.924 7,300.000 44.409 109.3248 5,585.328 5,680.128 -1,515.708 3,916.094 5,967,154.6952 566,126.2675 0.00 4,197.899 7,400.000 44.409 109.3248 5,656.765 5,751.565 -1,538.865 3,982.129 5,967,132.0885 566,192.4851 0.00 4,267.874 7,500.000 44.409 109.3248 5,728.201 5,823.001 -1,562.022 4,048.163 5,967,109.4818 566,258.7028 0.00 4,337.850 7,510.917 44.409 109.3248 5,736.000 5,830.800 -1,564.550 4,055.372 5,967,107.0139 566,265.9316 0.00 4,345.489 C40 7,600.000 44.409 109.3248 5,799.638 5,894.438 -1,585.179 4,114.197 5,967,086.8751 566,324.9204 0.00 4,407.825 7,700.000 44.409 109.3248 5,871.075 5,965.875 -1,608.336 4,180.232 5,967,064.2684 566,391.1380 0.00 4,477.800 7,800.000 44.409 109.3248 5,942.512 6,037.312 -1,631.493 4,246.266 5,967,041.6617 566,457.3557 0.00 4,547.775 7,878.047 44.409 109.3248 5,998.267 6,093.067 -1,649.566 4,297.804 5,967,024.0178 566,509.0369 0.00 4,602.389 B~inDïr";'4.0Ø°Dl..S,1:$18."\00ft MD.60~3.104 ftTVi:) 7,900.000 45.285 109.3158 6,013.831 6,108.631 -1,654.688 4,312.413 5,967,019.0176 566,523.6869 3.99 4,617.870 7,918.844 46.040 109.3083 6,027.000 6,121 .800 -1,659.146 4,325.133 5,967,014.6663 566,536.4417 4.01 4,631.347 'r-opHRZ 8,000.000 49.285 109.2779 6,081.650 6,176.450 -1,678.964 4,381 .747 5,966,995.3201 566,593.2129 4.00 4,691.328 8,100.000 53.285 109.2443 6,144.180 6,238.980 -1,704.697 4,455.393 5,966,970.2002 566,667.0625 4.00 4,769.338 8,200.000 57.285 109.2140 6,201.116 6,295.916 -1,731.764 4,532.992 5,966,943.7803 566,744.8759 4.00 4,851.519 8,300.000 61.285 109.1864 6,252.181 6,346.981 -1,760.032 4,614.167 5,966,916.1889 566,826.2741 4.00 4,937.470 8,397.315 65.179 109.1614 6,296.000 6,390.800 -1,788.563 4,696.218 5,966,888.3416 566,908.5513 4.00 5,024.336 BaseH~ 8,400.000 65.285 109.1607 6,297.125 6,391 .925 -1,789.363 4,698.521 5,966,887.5606 566,910.8604 3.95 5,026.774 8,500.000 69.285 109.1367 6,335.730 6,430.530 -1,819.615 4,785.644 5,966,858.0349 566,998.2229 4.00 5,118.995 8,545.054 71.088 109.1263 6,351.000 6,445.800 -1,833.506 4,825.688 5,966,844.4775 567,038.3767 4.00 5,161 .377 t(,"\ 28 February, 2005 - 10:54 Page 3 0'6 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. (Kuparuk) HALLIBURTON Kuparuk River Unit Plan Report for Plan: 1C-21 - Plan: 1C-21 - Plan: 1C-21 (wp08) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) (ft) 8,600.000 6,367.808 6,462.608 -1,850.639 4,875.111 5,966,827.7555 567,087.9358 5,213.684 8,700.000 6,393.202 6,488.002 -1,882.286 4,966.487 5,966,796.8701 567,179.5620 5,310.379 8,800.000 6,411.789 6,506.589 -1,914.401 5,059.326 5,966,765.5290 567,272.6553 5,408.609 17 -1 8,900.000 85.284 6,423.478 -1,946.827 5,153.177 5,966,733.8850 5,507.896 87.537 -1 8,971 .557 86.927 109.0124 6,427.738 6,522.538 5,220.694 5,966,711.1463 567,434.4636 5,579.315 9,000.000 86.927 109.0124 6,429.263 6,524.063 5,247.547 5,966,702.1174 567,461.3897 5,607.715 86.927 109.0124 1 9,100.000 86.927 6,529.424 -2,011.912 5,966,670.3736 567,556.0558 9,200.000 86.927 6,534.785 -2,044.442 5,966,638.6299 567,650.7220 9,300.000 86.927 6,540.147 -2,076.972 5,966,606.8861 567,745.3882 9,364.653 86.927 6,543.613 -2,098.004 5,966,586.3628 567,806.5927 9,391.460 87.998 5,966,577.8393 .9776 9,400.000 6,450.273 6,545.073 -2,109.527 5,966,575.1183 567,840.0671 6,007.128 9,495.064 92.003 109.3664 6,449.881 6,544.681 -2,140.716 5,714.977 5,966,544.6771 567,930.0962 4.00 6,102.168 9,500.000 92.003 109.3664 6,449.708 6,544.508 -2,142.352 5,719.631 5,966,543.0799 567,934.7634 0.00 6,107.102 9,600.000 92.003 109.3664 6,446.213 6,541.013 -2,175.493 5,813.915 5,966,510.7251 568,029.3099 0.00 6,207.039 9,700.000 92.003 109.3664 6,442.718 6,537.518 -2,208.633 5,908.199 5,966,478.3704 568,123.8565 0.00 6,306.975 9,800.000 92.003 109.3664 6,439.223 6,534.023 -2,241.774 6,002.483 5,966,446.0156 568,218.4030 0.00 6,406.912 9,900.000 92.003 109.3664 6,435.728 6,530.528 -2,274.914 6,096.768 5,966,413.6608 568,312.9495 0.00 6,506.849 10,000.000 92.003 109.3664 6,432.233 6,527.033 -2,308.055 6,191 .052 5,966,381.3061 568,407.4960 0.00 6,606.786 10,100.000 92.003 109.3664 6,428.738 6,523.538 -2,341.195 6,285.336 5,966,348.9513 568,502.0425 0.00 6,706.722 10,200.000 109.3664 6,425.243 6,520.043 -2,374.336 6,379.620 5,966,316.5965 568,596.5890 6,806.659 10,207.014 109.3664 6,424.998 6,519.798 -2,376.660 6,386.233 5,966,314.3270 568,603.2209 6,813.669 10,300.000 109.4743 6,424.764 6,519.564 -2,407.572 6,473.913 5,966,284.1460 568,691.1452 6,906.637 1 09.4827 -2,409.996 .7793 10,318.903 87.536 109.4056 6,425.454 6,520.254 -2,413.865 6,491.724 5,966,278.0020 568,709.0062 4.00 6,925.526 10,400.000 87.536 109.4056 6,428.941 6,523.741 -2,440.784 6,568.143 5,966,251.7190 568,785.6388 0.00 7,006.547 10,500.000 87.536 109.4056 6,433.241 6,528.041 -2,473.979 6,662.375 5,966,219.3097 568,880.1334 0.00 7,106.453 10,600.000 87.536 109.4056 6,437.541 6,532.341 -2,507.174 6,756.607 5,966,186.9004 568,974.6281 0.00 7,206.359 10,700.000 87.536 109.4056 6,441.841 6,536.641 -2,540.368 6,850.839 5,966,154.4912 569,069.1227 0.00 7,306.265 10,800.000 87.536 109.4056 6,446.141 6,540.941 -2,573.563 6,945.070 5,966,122.0819 569,163.6174 0.00 7,406.171 10,900.000 87.536 109.4056 6,450.441 6,545.241 -2,606.757 7,039.302 5,966,089.6726 569,258.1121 0.00 7,506.076 11,000.000 87.536 109.4056 6,454.741 6,549.541 -2,639.952 7,133.534 5,966,057.2633 569,352.6067 0.00 7,605.982 11,100.000 87.536 1 09.4056 6,459.041 6,553.841 -2,673.146 7,227.766 5,966,024.8540 569,447.1014 0.00 7,705.888 11,104.730 87.536 109.4056 6,459.244 6,554.044 -2,674.716 7,232.223 5,966,023.3212 569,451.5705 0.00 7,710.613 11,200.000 91.324 108.9961 6,460.192 6,554.992 -2,706.042 7,322.172 5,965,992.7456 569,541.7681 4.00 7,805.857 11 6,554.800 7,813.320 11,220.960 92.125 109.1568 6,459.559 6,554.359 -2,712.873 7,341.977 5,965,986.0789 569,561.6272 4.00 7,826.806 11,300.000 92.125 109.1568 6,456.628 6,551 .428 -2,738.793 7,416.589 5,965,960.7812 569,636.4441 0.00 7,905.787 11,400.000 92.125 109.1568 6,452.919 6,547.719 -2,771.586 7,510.986 5,965,928.7749 569,731.1011 0.00 8,005.713 11,500.000 92.125 109.1568 6,449.210 6,544.010 -2,804.379 7,605.384 5,965,896.7687 569,825.7580 0.00 8,105.639 11,600.000 92.125 109.1568 6,445.501 6,540.301 -2,837.171 7,699.781 5,965,864.7625 569,920.4150 0.00 8,205.565 11,700.000 92.125 109.1568 6,441.793 6,536.593 -2,869.964 7,794.179 5,965,832.7563 570,015.0719 0.00 8,305.491 11,800.000 92.125 109.1568 6,438.084 6,532.884 -2,902.757 7,888.576 5,965,800.7500 570,109.7288 0.00 8,405.417 11,900.000 92.125 109.1568 6,434.375 6,529.175 -2,935.550 7,982.974 5,965,768.7438 570,204.3858 0.00 8,505.343 12,000.000 92.125 109.1568 6,430.667 6,525.467 -2,968.343 8,077.371 5,965,736.7376 570,299.0427 0.00 8,605.269 12,100.000 92.125 109.1568 6,426.958 6,521 .758 -3,001.136 8,171.768 5,965,704.7313 570,393.6997 0.00 8,705.195 12,200.000 92.125 109.1568 6,423.249 6,518.049 -3,033.928 8,266.166 5,965,672.7251 570,488.3566 0.00 8,805.121 12,262.671 92.125 109.1568 6,420.925 6,515.725 -3,054.480 8,325.326 5,965,652.6666 570,547.6789 0.00 8,867.746 28 February, 2005 - 10:54 Page 4 0'6 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. (Kuparuk) HALLIBURTON Kuparuk River Unit Plan Report for Plan: 1C-21 - Plan: 1C-21 - Plan: 1C-21 (wp08) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 12,300.000 90.732 108.6245 6,419.995 8,360.632 5,965,640.8793 570,583.0811 3.99 8,905.058 12,400.000 86.996 107.1967 6,421.980 8,455.748 5,965,610.9310 570,678.4393 4.00 9,004.967 12,476.533 84.205 105.9452 6,427.879 6,522.679 -3,119.120 8,528.859 5,965,589.7218 570,751.7212 4.00 9,081.151 12,500.000 84.205 105.9452 6,430.249 6,525.049 -3,125.534 8,551.307 5,965,583.4950 570,774.2198 0.00 9,104.446 12,600.000 84.205 105.9452 6,440.346 6,535.146 -3,152.865 8,646.968 5,965,556.9599 570,870.0950 0.00 9,203.717 12,700.000 84.205 105.9452 6,450.442 6,545.242 -3,180.197 8,742.629 5,965,530.4249 570,965.9702 0.00 9,302.988 12,761 .864 105.9452 6,456.689 6,551.489 8,801.809 5,965,514.0092 571,025.2829 9,364.401 12,800.000 106.6767 6,460.095 6,554.895 8,838.262 5,965,503.6449 571,061.8196 9,402.315 12,900.000 108.5867 6,464.801 6,559.601 8,933.439 5,965,474.1838 571,157.2341 9,502.116 571,190.2147 13,000.000 90.284 109.2501 6,464.677 6,559.477 -3,270.805 9,027.911 5,965,442.1924 571,251.9659 0.00 9,602.108 13,100.000 90.284 109.2501 6,464.182 6,558.982 -3,303.774 9,122.319 5,965,410.0102 571,346.6346 0.00 9,702.103 13,200.000 90.284 109.2501 6,463.687 6,558.487 -3,336.743 9,216.726 5,965,377.8281 571,441.3032 0.00 9,802.098 13,300.000 90.284 109.2501 6,463.193 6,557.993 -3,369.712 9,311.134 5,965,345.6459 571,535.9718 0.00 9,902.094 13,400.000 90.284 109.2501 6,462.698 6,557.498 -3,402.681 9,405.542 5,965,313.4637 571,630.6405 0.00 10,002.089 13,500.000 90.284 109.2501 6,462.203 6,557.003 -3,435.650 9,499.949 5,965,281 .2815 571,725.3091 0.00 10,102.084 13,600.000 90.284 109.2501 6,461.708 6,556.508 -3,468.619 9,594.357 5,965,249.0993 571,819.9778 0.00 10,202.079 13,700.000 90.284 109.2501 6,461.213 6,556.013 -3,501.588 9,688.765 5,965,216.9172 571,914.6464 0.00 10,302.074 13,800.000 90.284 109.2501 6,460.718 6,555.518 -3,534.556 9,783.172 5,965,184.7350 572,009.3150 0.00 10,402.069 13,900.000 90.284 109.2501 6,460.223 6,555.023 -3,567.525 9,877.580 5,965,152.5528 572,103.9837 0.00 10,502.064 14,000.000 90.284 109.2501 6,459.728 6,554.528 -3,600.494 9,971.988 5,965,120.3706 572,198.6523 0.00 10,602.059 14,100.000 90.284 109.2501 6,459.234 6,554.034 -3,633.463 10,066.395 5,965,088.1885 572,293.3209 10,702.054 90.284 109.2501 10,110.951 Based upon Minimum Curvature type calculations, at a Measured Depth of 14, 147.20ft the Bottom Hole Displacement is 1 0,749. 27ft in the Direction of 109.84° (Grid). Plan Annotations Measured Depth (ft) 34.500 300.100 800.100 1,300.100 2,089.630 5,604.618 7,878.100 9,006.000 14,147.190 Vertical Depth (ft) 34.500 300.100 794.405 1,277.367 1,958.003 4,469.000 6,093.104 6,524.384 6,553.800 Vertical Section Information 28 February, 2005 - 10:54 Angle Type User Local Coordinates +N/-S +E/-W (ft) (ft) 0.000 0.000 0.000 0.000 -46.831 45.224 -139.920 135.120 -309.143 475.463 -1,123.109 2,796.561 -1,649.579 4,297.839 -1,981.333 5,253.211 -3,649.021 10,110.946 Comment SHL -- 1600fl FNL & 4089f1FEL; Sec12-T11 N-R10E Begin Dir -- 3.000DLS, 300.100 fI MD, 300.100 fI TVD End Dir-Start Sail--15.oo0° ,800.100 fI MD, 794.405 ft TVD Begin Dir -- 4.000DLS, 1300.100 fI MD, 1277.367 fI TVD End Dir-Start Sail--44.409° ,2089.630 fI MD, 1958.003 ft TVD 10-3/4" Csg Pt-- Drill out 9-7/8" Hole: 5604.618f1 MD, 4469.000 ft TVD Begin Dir -- 4.000DLS, 7878.100 fI MD, 6093.104 fI TVD 7-5/8" Csg PT-- Continue Dir- Begin 6-3/4" Hole-9006ft MD, 6524 fI TVD; TD (BHL) -- 14147.190 ft MD, 6553.800 fI TVD, 5256ft FNL & 4188f1 FEL, Origin Origin Start Target Azimuth Type +N/_S +EI-W TVD (0) (ft) (ft) (ft) No Target (Freehand) 109.7401 Slot 0.000 0.000 34.500 Page 5 of 6 COMPASS ORIGINAL . . HALLIBURTON ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit North Reference Sheet for Kuparuk 1C Pad - Plan: 1C-21 - Plan: 1C-21 Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 using datum NAD 1927 (NADCON CON US), ellipsoid Clarke 1866 Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -150.00·, longitude Origin:O.OO·, latitude Origin:O.OO· False Easting: 500,000.000Oft, False Northing: O.OOOOft, Scale Reduction: 0.99990439 Grid Coordinates of Well: 5,968,637.7500, 562,198.1 200 Geographical Coordinates of Well: 70· 19' 29.43" N, 149· 29' 44.34" W Grid Convergence at Surface is: 0.4749· Magnetic Convergence at surface is: -24.1100· (19 November 2004, , bggm20Q4) 28 February, 2005 - 10:54 Page 6 0'6 COMPASS ORiGINAL . . EBA 1 C-21 1 (NAD 27) GEOLOGIC SUMMARY: Resp: Jeff Harrison - 6315 o Incomplete Formatio n X Upper C sand Landing in 567,420 TGT 1 568,416 FLT1 PT 1 569,564 FLT1 PT 2 570,038 Toe 572,338 y Z (TVD.SS) Porosity Perm 18-23% 10-300mD Preferred Tar. Angle Net Pay 5,966,716 5,966,384 5,966,000 5,965,842 5,965,073 6,421' 6,425' 6,431' 6,404' 6,464' Approx Stepout: Remarks: Target line is defined as 15' below top of C sand. Ultimate target strategy is to undulate through entire -30' of upper C sand stratigraphy at high angle of penetration. FEL 3 targets updated as of 1/24/05. ~t Shape: 2 (NAD 27) Formatio n X ~t Shape: omments: 3 (NAD 27) Formatio n X ~t Shape: omments: Geologic Progno~ ~ormatio I X Base Permafrost Top Ugnu I Top West Sak Base West Sak C-80 C-40 Top HRZ Base HRZ K-1 Top Kuparuk D C4 ~ot Applicable Z Preferred Tar. y (TVD.SS) Porosity Perm Net Pay Angle Approx Stepout: ~ot Applicable Z Preferred Tar. y (TVD.SS) Porosity Perm Net Pay Angle Approx Stepout: Responsible: Jeff Harrison - 6315 Y Z MD Gross (TVD.SS) Thicknes s o Net Pay Incomplete Net to Gross 1,701' 3,124' 3,756' 4,176' 4,552' 5,736' 6,021' 6,296' 6,351' 6,414' 6,414' 6,421' Remarks: Geologic Discussion: Responsible: Jeff Harrison - 6315 n Incomplete The 1 C-21 is designed to be an approximately 4000' long horizontal C sand producer located between the 1 C-26 horizontal injector to the south and the 1 C-27 horizontal producer to the north. As a part of the development, the current plan is to convert the 1 C-27 to injection following the completion ofthe 1C-21. The upper C4/C3 intervals are the primary target and the proposed well trajectory crosses one major (-50') down to the west normal fault. The defined target line is currently 15' below the top of the C sand although the actual well bore will be gently geosteered to penetrate and access reserves from approximately 35' TVD of upper C sand stratigraphy. ORIGINAL un -9000-~ o + :c t o Z > , :c ~ o (f) , ~ I j I 3000 I I 4500 ¡ 6000 I I I 7500 I 9000 10500 West( -)/East( +) \ WELL DETAILS: Plan: 1C-21 Ground Level: 0.000 Northing Easting Latittude Longitude 5968637.7500562198.1200 70° 19'29 .434N 49°29'44.342W Spe.rry Drilling. Services +N/-S +E/-W 0.000 0.000 -' '--/ 1C-25 VO 1 C-27 Vi 1C-25,1C-25, o JO o 00 00 00 ~ 'C::) ~ J longitude 1C~21 0.000 latittude 70° 19'29 .434N WEll DETAilS: Pfan Ground level Northing Easting 5968637.7500562198.1200 49°29'44.342W Services 1C-2?, 1C-2?, 1C-2? V1 / / / 1C-21 PI/!fI: +N/-S +E/-W 0.000 0.000 .... ~ 1C-25, 1<:-25 VO . . 1C-21 Drilling Hazards Summary 13-1/2" Hole /10-3/4" Casino Interval Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing Hole Swabbing/Tight Hole on Trips Lost Circulation Risk Level Low Moderate Moderate Moderate Low 9-7/8" Hole / 7-5/8" Casino Interval Event Shale stability in HRZ and K-l High ECD and swabbing with higher MW's required Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Moderate Low 6-3/4" Hole / 4-1/2" Liner Interval Event Trouble Sliding / Steering Differential Sticking Difficulties getting liner to bottom with swell packers Lost Circulation Risk Level Moderate Moderate Moderate Moderate Mit_ig~tion Strategy Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Mitigation Strategy Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. Mitigation Strategy Bit/BHA design will take into account historical problems in offset horizontal wells with steering. Although LOTAD's should not be needed, torque/drag will be monitored to pro-actively identify a need for friction reduction devices to prevent weight transfer problems. Periodic wiper trips. Do not leave pipe static for extended period of time. Torque/drag will be monitored while drilling the interval. Pump out of hole on final trip out prior to running liner to ensure hole is clean. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, pre-treat with LCM prior to drilling fault crossings. Use LC decision tree designed for production laterals. An extensive LC strategy will be documented in the well plan. 1C-21 Drilling Hazards Summary. doc prepared by Scott Lowry 02/24/05 ,n. n!0NíAl ' "" ".",. ',.... "'" i . ~ , ". ¡ "'. i ~" V ,,\ I, :;"." ,;" 'IN . "~ Page 1 of1 Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 3/1/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6# casing at 118' MD < Base of Permafrost at 1,884' MD (1,801' TVD) < Top ofTail at 4,000' MD < 103/4",45.5# casing in 13 1/2" OH TO at 5,605' MD (4,469' TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 4,000' MD. Lead Slurrv Minimum pump time: 310 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 3 0.6381 ft 1ft x (118') x 1.00 (no excess) = 0.3637ft31ft x (1884' -118') x 3.50 (250% excess) = 0.3637 ft31ft x (4000' - 1884'1 x 1.35 (35% excess) = 75.3 ft3 + 2248 ft3+ 1038.9 ft = 3362.2 ft3 14.45 ft3/sk = Round up to 760 sks 75.3 ft3 2248 ft3 1038.9 ft3 3362.2 ft3 755.6 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 180 min. (pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.3637 ft31ft x (5605' - 4000') x 1.35 (35% excess) = 0.5400 ft3/ft x 80' (Shoe Joint) = 788 ft3 + 43.2 ft3 = 831.2 ft31 2.26 ft3/sk = Round up to 370 sks 788 ft3 43.2 ft3 831.2 ft3 367.8 sks BHST = 94°F, Estimated BHCT = 8rF. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 6.0 614.1 102.4 135.7 DeepCRETE 6.0 148.1 24.7 160.4 Drop top plug 0.0 0.0 5.0 165.4 Water 5.0 20.0 4.0 169.4 Switch to rig pump 0.0 0.0 5.0 174.4 Mud 7.0 496.4 70.9 245.3 Slow & bump plug 3.0 15.0 5.0 250.3 MUD REMOVAL Recommended Mud Properties: 10.1 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR~Git~AL bl P Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 3/2/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 800' MD above top of Kuparuk - (850' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.02%B155, 0.4% D167 -1.16 ft3/sk 3 0.2148 ft 1ft x 850' x 1.40 (40% excess) = 0.2578 ft3/ft x 80' JShoe Joint) = 255.6 ft3 + 20.6 ft = 276.2 ft3/ 1.16 ft3/sk = Round up to 240 sks 255.6 ft3 20.6 ft3 276.2 ft3 238.1 sks Previous Csg. < 103/4",45.5# casing at 5,605' MD BHST = 155°F, Estimated BHCT = 120°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 6.0 40.0 6.7 29.7 Tail 6.0 49.2 8.2 37.9 < Top of Tail at Drop top plug 0.0 0.0 5.0 42.9 8,156' MD Mud 7.0 397.8 56.8 99.7 Slow & bump plug 3.0 12.0 4.0 103.7 MUD REMOVAL < 75/8", 29.7# casing in 9 7/8" OH Recommended Mud Properties: 10.6 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 ~ TO at 9,006' MD (6,524' TVD) Centralizers: Recommend 1 ~ per joint across zones of interest for proper cement placement. ORIGt~J.AL 1 C...21 Horizon Well Base Case Proposed Completion Schematic Con ill ips I ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ iï r I ~ ~ ~ ~ ~ ~ 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT pin down (Special Drift to 3.91 ") 4-1/2" 126# L-80 IBT Spaceout Pups as Required (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Tubing to Surface (Special Drift to 3.91") ~ 4-1/2" Camco 'DB' nipple wi 3.875" No-Go Profile set at +1- 500' MD 4-1/2" 12.6# L-80 IBT tubing to landing nipple (Special Drift to 3.843") 4-1/2" x 1" Cameo 'KBG-2' Mandrels wI DV's (Max. 005.984",103.833") Spaced out wi 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as follows: GLM # TVD-RKB MD-RKB 1 2600 2983 2 3800 4645 3 4700 5891 4 5400 6861 5 5925 7588 6 6325 8199 Surface csg. 10-3/4" 45.5# L-80 BTC Special Drift 9.875" 5605' MD I 4469' TVD (200' TVD below Base West Sak) 4-1/2" Camco 'DB' nipple wi 3.813" No-Go Profile set @ bottom of tangent section +1- 10,000 MD 16330' TVD 4-1/2" 12.6# L-80 IBT tubing from 'DB' nipple to sliding sleeve (Special Drift to 3.843") Baker 4-%" CMU Sliding Sleeve, 3.81" DB Profile (Ran in open position) 1 jt 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") 4.75" 00 Baker casing seal assembly w/17 Ft. stroke, # L-80 IBT box up (landed 3-4' off fully landed position) Intermediate csg. 75/8" 29.7# L-80 BTCM 9,006' MD I 6524' TVD (App. 50' MD below top of C4) 4 %" x 6.3" Swell Packers for isolation of conductive faults wet -----------. / / ----------.-- Slotted Liner 4-1/2" 12.6# L-80 IBT Liner Assemblv Hanqer Set +1- 150' above intermediate csq shoe Baker 5 %" x 7 5/8" 'ZXP' Liner Top Isolation Packer wi HRD running profile Baker 5 %" x 7 5/8" RS Nipple Baker 5 %" x 7 5/8" 'Flexlock' Liner Hanger Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore) 4 %" 12.6# L-80 IBT alternating slotted and blank pipe wi swell packers (installation of blank pipe & swell pkrs TBD with well logs) C4/C3 Lateralto 14,147' MD .,¡ø. 4 %" ROT 'Silver Bullet' Shoe Scott Lowry 3/3/05 SFD 3/10/2005 Feet 2,000 3,000 4,0001 SHARÖN K. ALLSUP-DRAKE 1095 CÖNOCOPHILlIPS ~~~l~~o 1 f(fl;vJ 2aJ~-14/311 ANCHORAGE AK 99501 DATE b~='/ ¿:r;/ff&/j j,'1C(J~¡lð~ $ ¡CO. ~_ (1./4- ~ II DOLLARS L!.J :;;:::::"..~ ...... C HASE Chase Manhattan Bank USA, N.A. . Valid Up To 5000 Dollars . ,.. .. 200 White Clay Ct!nter Or., Newark. DE 19711 . ~;> ~ ~OO ~~~I: 2 ~ß~7 ~"O 7'1 ~~;;:,A~~ . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K¡¿¿( / C! - z( ZÚ~-Ó3f PTD# 1// Development Service CHECK WHAT AP~LIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two, (2) digits are between 60-69) Exploration Stratigraphic to'CLUE n. The permit is for a new weUbore 'segmeDt of existing weD,. . Permit No, .' API No. , Production.sbould continue to be reponed as a function' of the original API number. stated above. . HOLE )n accordance with' 20 AAC 25.005(1), a)) records, data and logs acquired .for the pilot hole must be clearly differentiated ïD both name (name OB permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for we)) (name on permit). Pll.,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 2S.,055~ Approval to perforate and produce is cODtiDgent UPOD issuance of ~ conservatioD order approving a spacing' exceptioD. (Company Name) assumes tbe Jiability of aD)' protest 10 tbe spacing .e:lceptioD tbat ma)' occur. AU dry ditcb sample sets submitted to tbe Commission must be iD DO greater 1haD 30' sample intervals from below tbe permafrost or from wbere samples are fint caught aDd ] 0' sampleinter:vals through target zones. Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1C-21 Program D.EV Well bore seg D PTD#: 2050340 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal D Administration 1 P~rmitJee attached . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ . . . 2 _Leas~_number _ap¡::>ro¡::>ri~te _ _ _ _ _ . _ . _ . Yes _ _ _ _ . Surface Ipcation in ADL0256<19,_top ¡::>rod. ioterval& TD in ADL .02&2<42._ . _ _ _ . . . _ _ 3 _U_nlquewelln_am~_andoumb_er _........................... _......... .Y~s...... .l?r~viou.s.permitfor.H:::c21.(PTDl\Jo..1~9Q13Q).expiredoo2/n1200.1...................... _...... 4 WeJlJocat~d in.a d_efinedpool _ _ _ _ _ _ _ _ _ _ . . . . . . . _ .Y~s _ _ . . . Kuparuk Rjver Oil 1:'001, govern~d by Conseryatioo Order No. .432C . . _ _ _ _ _ . . . . . 5 WellJocat~d proper distance from driJling unitb.ound.al)'_ . . _ _ _ _ .Y~s _ Conseryattoo Ord.er No. .432C co_ntains _no spa_clng restrictions wiíh resRecUo a drilUn9 .unit.. . _ _ _ _ _ . . . . 6 WellJocat~d proper .dtstance. from otber wel!s_ _ _ _ . . . . . _ _ _ . _ _ _ _ . . . . . . . .Y~s _ _ _ _ _ _ Con.seryattoo Ord_er No. .432C bas no jn.terwell.spac;ingrestriction.s, _ . _ . . . _ _ _ _ . _ . . . . . . . 7SutficientacreaQeaYail~ble indrilliog unit. . . . . . . . . . _ _ .Y~s . . _ _ WelJb_ore.will be. more th~o 500~ from exteroal boundary.. .. . _ _ _ _ _ _ _ . . _ . 8 Jfd~viated, js weJlbore platincJu_ded . . . . . . . _ . . . . . . .Y~s _ _ _ _ _ . . _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . . . _ _ _ _ . . 90'perator only affected party. . _ _ _ _ _ _ _ _ _ . . . . . . . . . . . . _ . .Y~s. . . . _ _ _ _ _ . . . _ _ . _ _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 10 .Qperator bas. appropriate. bond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rmit c.ao be issu.ed witbout conservation order _ . _ . . . . . Yes _ . _ _ _ _ . . . . _ . . . . . . . . _ _ _ _ _ _ _ . . . . . _ . _ _ _ _ . _ _ . . . . Appr Date 12 P~01Jitcao be issued witbout administrative.approvaJ _ _ _ _ _ _ . _ _ _ _ . . _ . . _ _ . . _ .Y~s . . . . . . . . . . . . . . . . _ _ _ _ _ _ . . . . _ . _ _ _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ . . . _ _ _ _ . . . . SFD 3/11/2005 13 Can permit be approved before 15-daywait Yes 14 WellJocat~d within area alld_strataauthorized by.lojectioo Ord~r # (puUOtJ in_c.omm.eots) (For NA _ . _ . . . . _ _ _ _ _ _ _ _ . . . . _ _ . . . . . . . . . _ _ _ _ _ _ _ . . . . _ 15 .AJlwelJs.witl1tn.1l4.mile.area.ofreyiewid~otified(Forservj~.wellonIYL.............. .NA................................................................... _....... 16 Pre-produced iojector; _dur~tion.of pre-produc;tiplJ I~ss thall3 montbs (For.service well onJy) _ _ NA . . . . . . . _ . _ . _ _ . . . . . _ _ _ _ _ . _ . . . . . 17 ACMP. finding .of Conststeocy has bee_n issued for.tbis pr.oject _ _ _ . . . . . . .NA _ _ . . . . .. . _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . . . . . _ _ . _ _ _ _ _ . . . _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . _ . . _ 18 .C.oodu.ctor stringprov[ded _ _ _ . _ . . _ _ _ _ . _ . . . . . . _ . _ _ _ . _ _ _ _ _ _ . . . . . . . . Yes _ _ _ _ . . . . . . _ _ _ . _ _ . _ . . . .. _ _ . _ . . . . . . _ _ _ _ _ . . _ . . . . _ _ . . . . . 19Sudac~casilJgprotectsallknowIlUSDWs. . . . . . . . . _ _NA .,ð,llaquifersex.empt~d,40CFR1<47.'1Q2(b)(3). . _ _ _ _ _ . _ _ . _ .. . 20 _CMTvoladequate.to circ.ulate.on.cpnd.uctpr& surfcsg _ . . . .Y~s . _ _ _ _ _ _ . . .. _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ _ . .. . _ . _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . _ _ _ . . . 21CMT vol adequate.to tie-in Jong .string to.surf C$g . . . . . .. . _ _ _ _ _ _ _ . . . No.. _ _ _ _ ,ð,nyhydrpcarbonzones wjll.be.cpvered, AnouJar disposalmaybe proposed.. . _ _ . _ _ . _ . . . . 22 _CMTwill coyer all klJownproductiye borizon_s. . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ . No _ _ _ _ . . . SlpttedJioercompletioo plaoned._ . . _ _ _ _ . . . . 23C_asiog designs ad.equa.te for C,T, B.&.Rermafrost . _ _ _ _ _ _ _ . .Y~s. . . . . . . _ _ _ . _ _ . . . . . . _ _ _ _ . . . . _ . _ . . .. _ _ . _ _ _ _ _ _ _ . _ . 24 Adequ~tetankageorreseryepit. _ _ _. _...... .. _ _ _ .Y~s_ _.... .Rigisequipped.withst~elpjts.Norese.rve.pjt.planoed, Waste.toa¡::>provedallnulusor.djsposalwells. 25 Jf.a.re-dríll~ hasa 10:403 for ~bandOllment be~o apPJoved . . . _ _ _ _ _ _ _ _ _ _ _ _ . . . .NA _ _ _ _ _ . . . . . _ . . . . . . . _ . _ _ _ . . _ _ _ . . . . . 26 .AØequ~te.wellbore separation.pro'ppsed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . I?roJ5imit)'. analysis perfo01Je.d, Shallow jníerf~rance. identifje_d, Gyros probabJe.. . . _ _ . . . . . . . . . . _ . . . . . . 27 Jf.dNerter Jequired, does itmeet reguJatipos _ _ _ _ _ . . . . .. _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ .Y~s _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ . . . . . . _ . _ _ . . . . . . _ _ _ _ _ . _ . . . . _ _ _ _ _ _ _ . _ . . 28 .DJilliogfluid.Rrogramschematic&eq.uipJistadequate. . _. _ _ _. _ _ _ _. _ _. _... . _ Yes _.. .ExpectedKupform.ationpressuresZ.3:9.4EMW.F>lannedmudweighísasneedediIlKup,but9..2Jikely.... . 29 BOPEs,.d.o.they meetreguJatiplJ . . . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . . Yes. . _ _ _ _ _ _ _ . . . . _ . _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . . .. ... _ _ _ . _ _ _ . . . . _ _ _ _ . . . 30 BOPEpre_ssraíiogappropriate;testto.(pu.tpSigtn.cpmmelJts)_ _. _. ... _ _ _ _ _ _ .Y~s..... .MASl?calc;uJate.d.at2493psi, 35QO.psta.PProprjate,CP.t\lu.suallyte_sts_to5QOOpsÎ..... _ _ _ _ _ _ _... 31Chpke.manjfold compJies w/APlR.F>-53 (May 84) . _ . . . . . . _ _ _ _ _ _ _ . . Yes. . _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . . . 32 Work will pcc.ur withputoperationsbutdown _ _ _ _ _ _ _ . . . . . . . . _ . .Y.es _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ . _ _ _ _ . . . _ _ _ _ _ _ _ . . 33 Jspresence.ofH2Sgas_Rrobable _... _ _ _ _. _ _..... . Yes _ _ _ _ _ _DS:1Cl1asH2S._Mu.d.shouJd¡::>rec;ludeH2Soorig.Righasseosors_and.alarms. _ _. _ _... _ _ _ _ _ _ _ _... 34 Mecba.nlcalcpodjtiooof wells wlthin ,ð,OR yerified (fprs_ervice welJ ollly). . _ _ _ . .NA . . . _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ . . . . . _ _ . _ _ _ _ . . . Engineering Appr Date TEM 3/14/2005 i .Cfl'YVì tß.V , . Appr SFD Date 3/11/2005 35 Permitc.aobeissuedw/ohydrogensulfidemeas]Jœs_.... _ _ _ _.... No_ _ _ _ _ _ _ _KRU:1C-Padwells.have.measured2Q-.9.D_ppm.H2S. 36 DatapJeseoted on_ ¡::>otential overpressure .zones. . . . . _ _ _ _ _ _ _ _ . _ _ . . . . . . . . . _ .Y~s. . Expected reservoir .pressure is .1,3. - .9,4ppg EMW; wjllbe _drilled witb 8.5 - :1 0.0 P¡::>Q mud.. _ _ _ _ _ _ _ _ . . . 37 .S~ism¡c.analysjs of sbaJlow gaszooes _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ . _ _ . _ _ . . . . NA _ _ _ _ _ _ . . . . . . . _ . _ _ _ _ _ . . . . . . . _ . _ _ . . . . . _ _ . . . _ _ _ . _ _ _ . . 38 .Seabedconditioo survey.(if off-shore) . . _ . . . . . . . . _ . _ _ _ _ _ _ _ . . NA . . _ _ _ _ _ _ _ _ _ . . . _ . . _ _ _ _ _ . . . _ _ _ _ _ _ . _ . . . . 39 _ Contact namelpl1Ollefor.weekly prpgress.re¡::>orts [ex¡::>loratol)'only] _ . . . . . _ _ _ _ _ _ _ _ _NA . . . . . . _ _ _ _ _ . .. . _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ . . . Geology Geologic Commissioner: Date: Engineering Comm issioner: Date Public !ß5' Date 01s 3/11/S 3jqr£ . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding infonnation, 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. . . ~)~ "f f:Jç ~ tt: \}L8~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 21 09:34:27 2005 Reel Header Service name............ .LISTPE Date.................... .05/09/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .05/09/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1C-21 500292325300 ConocoPhillips Alaska, Inc. Sperry Drilling Services 21-SEP-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003706651 P. SMITH F. HERBERT MWD RUN 5 MW0003706651 P. SMITH F. HERBERT MWD RUN 11 MW0003706651 C. COCHRAN G. WHITLOCK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 12 MW0003706651 B. HENNINGSE G. WHITLOCK MWD RUN 13 MW0003706651 B. HENNINGSE G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 11N 10E 1601 1191 MSL 0) 101.80 60.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 16.000 10.750 7.625 DEPTH (FT) 116.0 5680.0 9153.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. NO PROGRESS WAS MADE ON RUN 2. 4. MWD RUNS 4, 5, 11 - 13 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE-WHILE-DRILLING (PWD). MWD RUNS 5 & 11 - 13 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). MWD RUN 5 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 11 - 13 INCLUDED AT-BIT INCLINATION (ABI) . 5. DUE TO A FULL RAPID SAMPLE MEMORY, THE DENSITY PRESENTATION FOR THE INTERVAL 13316.5'MD - 14059'MD (END OF RUN 12) COMPRISES BULK DENSITY DATA. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 4, 5, 11 - 13 REPRESENT WELL 1C-21 WITH API#: 50-029-23253-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15634'MD/6528'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) . 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. RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP · NON-ROTATED INTERVALS REFLECTING SEN. SLDSLIDE = DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.75" MUD WEIGHT: 9.2 - 9.7 PPG MUD SALINITY: 3000 - 29,000 PPM CHLORIDES FORMATION WATER SALINITY: 11,500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI PEF RHOB DRHO $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 5652.5 5660.0 5660.0 5660.0 5660.0 5660.0 5690.5 9076.5 9077.0 9077.0 9089.5 9153.5 9153.5 STOP DEPTH 15574.0 15581.0 15581.0 15581.0 15581.0 15581.0 15634.0 15537.5 15537.5 15537.5 15552.5 15552.5 15552.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 4 5 11 12 13 MERGED MAIN PASS. $ MERGE TOP 5645.0 9160.0 9630.5 12595.5 14148.0 MERGE BASE 9160.0 9630.0 12595.0 14148.0 15634.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down . . Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5652.5 15634 10643.3 19964 5652.5 15634 ROP MWD FT/H -31 1727 138.601 19888 5690.5 15634 GR MWD API 27.77 423.53 90.5678 19844 5652.5 15574 RPX MWD OHMM 0.3 702.39 5.02699 19843 5660 15581 RPS MWD OHMM 0.36 1634.5 6.09086 19843 5660 15581 RPM MWD OHMM 0.33 2000 9.03235 19843 5660 15581 RPD MWD OHMM 0.72 2000 13.7075 19843 5660 15581 FET MWD HOUR 0.19 136.42 2.73444 19843 5660 15581 NPHI MWD PU-S 18.08 58.97 25.4929 12922 9077 15537.5 FCNT MWD CNTS 114.4 704.15 448.449 12922 9077 15537.5 NCNT MWD CNTS 13446.1 31169.7 24066.8 12923 9076.5 15537.5 RHOB MWD G/CM 1.729 3.555 2.34007 12799 9153.5 15552.5 DRHO MWD G/CM -0.241 1. 102 0.0723229 12799 9153.5 15552.5 PEF MWD BARN 0.42 14.84 1.7813 12927 9089.5 15552.5 First Reading For Entire File......... .5652.5 Last Reading For Entire File.......... .15634 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO . Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPS RPM GR ROP $ 2 . header data for each bit run in separate files. 4 .5000 START DEPTH 5645.0 5645.0 5645.0 5645.0 5645.0 5652.5 5690.5 STOP DEPTH 9114.5 9114.5 9114.5 9114.5 9114.5 9121.5 9160.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 24-MAY-05 Insite 66.37 Memory 9160.0 5690.0 9160.0 46.2 81.2 TOOL NUMBER 097054 10505932 9.875 5680.0 Water 10.10 83.0 8.5 400 3.4 Based 2.300 1.110 1.940 1.970 65.0 142.0 65.0 65.0 . . # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5645 9160 7402.5 7031 5645 9160 ROP MWD040 FT/H 1 398.91 13 9.67 6940 5690.5 9160 GR MWD040 API 27.77 423.53 136.581 6939 5652.5 9121.5 RPX MWD040 OHMM 0.76 9.82 2.84543 6940 5645 9114.5 RPS MWD040 OHMM 0.78 1633.39 3.329 6940 5645 9114.5 RPM MWD040 OHMM 0.33 1592.93 3.68346 6940 5645 9114.5 RPD MWD040 OHMM 0.72 2000 13.2695 6940 5645 9114.5 FET MWD040 HOUR 0.19 95.6 2.01656 6940 5645 9114.5 First Reading For Entire File......... .5645 Last Reading For Entire File.......... .9160 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPX RPS RPM FET RPD GR RHOB DRHO ROP $ . 5 .5000 START DEPTH 9076.5 9077.0 9077.0 9089.5 9115.0 9115.0 9115.0 9115.0 9115.0 9122.0 9153.5 9153.5 9160.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: . 29-MAY-05 Insite 66.37 Memory 9630.0 9160.0 9630.0 86.0 92.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 FIo-pro 9.20 93.0 9.9 300 3.4 .300 .190 .200 .370 68.0 113.0 68.0 68.0 . . $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9076.5 9630 9353.25 1108 9076.5 9630 ROP MWD050 FT/H 1. 51 402.36 130.599 940 9160.5 9630 GR MWD050 API 28.91 83.33 61.659 1017 9122 9630 RPX MWD050 OHMM 0.3 702.39 10.8757 1031 9115 9630 RPS MWD050 OHMM 0.36 1634.5 16.6754 1031 9115 9630 RPM MWD050 OHMM 0.36 2000 65.0583 1031 9115 9630 RPD MWD050 OHMM 7.62 2000 121.982 1031 9115 9630 FET MWD050 HOUR 0.21 125.53 12.3216 1031 9115 9630 NPHI MWD050 PU-S 21.12 58.97 29.7139 1107 9077 9630 FCNT MWD050 CNTS 114.4 563.2 363.133 1107 9077 9630 NCNT MWD050 CNTS 13446.1 26891.8 22145.7 1108 9076.5 9630 RHOB MWD050 G/CM 2.266 3.555 2.4443 954 9153.5 9630 DRHO MWD050 G/CM -0.241 0.994 0.0484811 954 9153.5 9630 PEF MWD050 BARN 1. 02 14.84 4.02409 1082 9089.5 9630 First Reading For Entire File......... .9076.5 Last Reading For Entire File.......... .9630 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header . Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type....... . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF RPM RPD FET NPHI FCNT NCNT DRHO GR RHOB RPS ROP RPX $ 4 . header data for each bit run in separate files. 11 .5000 START DEPTH 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 12595.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 06-JUN-05 Insite 66.37 Memory 12595.0 9630.0 12595.0 84.1 97.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 Flo-Pro 9.20 41.0 9.0 25000 3.0 .260 68.0 · MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .130 .230 .260 1_ 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Refèrence Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD110 FT/H 4 1 68 4 2 GR MWD110 API 4 1 68 8 3 RPX MWD110 OHMM 4 1 68 12 4 RPS MWD110 OHMM 4 1 68 16 5 RPM MWD110 OHMM 4 1 68 20 6 RPD MWD 11 0 OHMM 4 1 68 24 7 FET MWD 11 0 HOUR 4 1 68 28 8 NPHI MWD 11 0 PU-S 4 1 68 32 9 FCNT MWD110 CNTS 4 1 68 36 10 NCNT MWD110 CNTS 4 1 68 40 11 RHOB MWD110 G/CM 4 1 68 44 12 DRHO MWD 11 0 G/CM 4 1 68 48 13 PEF MWD 11 0 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9630.5 12595 11112.8 5930 9630.5 12595 ROP MWD 11 0 FT/H 0.95 863.05 136.904 5930 9630.5 12595 GR MWD 11 0 API 33.76 119.01 63.7223 5930 9630.5 12595 RPX MWD 11 0 OHMM 2.93 24.04 6.07219 5930 9630.5 12595 RPS MWD110 OHMM 3.1 30.66 7.05895 5930 9630.5 12595 RPM MWD110 OHMM 3.27 31.24 7.63409 5930 9630.5 12595 RPD MWD110 OHMM 3.24 27.79 7.63313 5930 9630.5 12595 FET MWD110 HOUR 0.29 136.42 1.1611 5930 9630.5 12595 NPHI MWD110 PU-S 18.08 35.61 24.5373 5930 9630.5 12595 FCNT MWD110 CNTS 263.78 673.15 458.275 5930 9630.5 12595 NCNT MWD110 CNTS 18004.2 31169.7 24196.6 5930 9630.5 12595 RHOB MWD110 G/CM 1.987 3.194 2.3458 5930 9630.5 12595 DRHO MWD110 G/CM -0.216 1.014 0.0673133 5930 9630.5 12595 PEF MWD 11 0 BARN 0.74 5.6 1.57807 5930 9630.5 12595 First Reading For Entire File......... .9630.5 Last Reading For Entire File.......... .12595 File Trailer . Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/09/21 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT RPD ROP GR RPX RPS RPM FCNT RHOB DRHO PEF FET NPHI $ 5 . header data for each bit run in separate files. 12 .5000 START DEPTH 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 12595.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 14052.5 14087.0 14148.0 14080.0 14087.0 14087.0 14087.0 14052.5 14059.0 14059.0 14059.0 14087.0 14052.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 09-JUN-05 Insite 66.37 Memory 14148.0 12595.0 14148.0 83.7 94.8 TOOL NUMBER 87224 154267 10603684 130908 . . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZ~ (IN): DRILLER'S CASING DEPTH (FT): 6.750 9153.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-pro 9.20 42.0 9.0 20000 3.0 .300 .140 .240 .320 65.0 148.9 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 GR MWD120 API 4 1 68 8 3 RPX MWD120 OHMM 4 1 68 12 4 RPS MWD120 OHMM 4 1 68 16 5 RPM MWD120 OHMM 4 1 68 20 6 RPD MWD120 OHMM 4 1 68 24 7 FET MWD120 HOUR 4 1 68 28 8 NPHI MWD120 PU-S 4 1 68 32 9 FCNT MWD120 CNTS 4 1 68 36 10 NCNT MWD120 CNTS 4 1 68 40 11 RHOB MWD120 G/CM 4 1 68 44 12 DRHO MWD120 G/CM 4 1 68 48 13 PEF MWD120 BARN 4 1 68 52 14 First Last Name ServiCe Unit Min Max Mean Nsam Reading Reading DEPT FT 12595.5 14148 13371.8 3106 12595.5 14148 ROP MWD12 0 FT/H 0.6 1537.7 152.864 3106 12595.5 14148 GR MWD120 API 31.39 92.99 65.2783 2970 12595.5 14080 RPX MWD120 OHMM 3.34 13.99 5.71953 2984 12595.5 14087 RPS MWD120 OHMM 4.19 14.62 6.54116 2984 12595.5 14087 RPM MWD120 OHMM 4.3 18.92 7.07713 2984 12595.5 14087 RPD MWD120 OHMM 4.41 22.43 7.14955 2984 12595.5 14087 FET MWD120 HOUR 0.44 20.36 1.90677 2984 12595.5 14087 · .595.5 NPHI MWD120 PU-S 19.17 32.73 25.467 2915 14052.5 FCNT MWD120 CNTS 282.2 642.91 456.569 2915 12595.5 14052.5 NCNT MWD12 0 CNTS 17922.9 31037.8 24415.1 2915 12595.5 14052.5 RHOB MWD120 G/CM 1.729 3.254 2.3017 2928 12595.5 14059 DRHO MWD12 0 G/CM -0.145 1.066 0.10113 2928 12595.5 14059 PEF MWD120 BARN 0.42 5.83 1.63538 2928 12595.5 14059 First Reading For Entire File......... .12595.5 Last Reading For Entire File.......... .14148 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ 6 header data for each bit run in separate files. 13 .5000 START DEPTH 14053.0 14053.0 14053.0 14059.5 14059.5 14059.5 14080.5 14087.5 14087.5 14087.5 14087.5 14087.5 14148.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): STOP DEPTH 15537.5 15537.5 15537.5 15552.5 15552.5 15552.5 15574.0 15581.0 15581.0 15581.0 15581.0 15581.0 15634.0 15-JUN-05 Insite 66.37 Memory 15634.0 14148.0 15634.0 . BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 88.1 95.3 TOOL NUMBER 151107 154267 10603684 148579 6.750 9153.0 Flo Pro 9.50 41.0 9.3 28000 4.0 .280 .120 .240 .380 65.0 158.6 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 13 0 FT/H 4 1 68 4 2 GR MWD 13 0 API 4 1 68 8 3 RPX MWD 13 0 OHMM 4 1 68 12 4 RPS MWD 13 0 OHMM 4 1 68 16 5 RPM MWD 13 0 OHMM 4 1 68 20 6 RPD MWD 13 0 OHMM 4 1 68 24 7 FET MWD 13 0 HOUR 4 1 68 28 8 NPHI MWD 13 0 PU-S 4 1 68 32 9 FCNT MWD 13 0 CNTS 4 1 68 36 10 NCNT MWD 13 0 CNTS 4 1 68 40 11 RHOB MWD 13 0 G/CM 4 1 68 44 12 DRHO MWD 13 0 G/CM 4 1 68 48 13 PEF MWD 13 0 BARN 4 1 68 52 14 [ '! . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14053 15634 14843.5 3163 14053 15634 ROP MWD 13 0 FT/H -31 1727 127.115 2972 14148.5 15634 GR MWD 13 0 API 41.32 148.93 71.9666 2988 14080.5 15574 RPX MWD 13 0 OHMM 1. 64 9.9 5.31551 2988 14087.5 15581 RPS MWD 13 0 OHMM 2.36 11.11 6.50074 2988 14087.5 15581 RPM MWD 13 0 OHMM 2.83 12.32 6.8846 2988 14087.5 15581 RPD MWD 13 0 OHMM 2.96 11.32 7.35977 2988 14087.5 15581 FET MWD 13 0 HOUR 0.24 61.57 5.92725 2988 14087.5 15581 NPHI MWD 13 0 PU-S 18.56 43.42 25.8532 2970 14053 15537.5 FCNT MWD 13 0 CNTS 211.92 704.15 452.662 2970 14053 15537.5 NCNT MWD 13 0 CNTS 16266.3 30618 24182.7 2970 14053 15537.5 RHOB MWD 13 0 G/CM 1.982 3.239 2.33299 2987 14059.5 15552.5 DRHO MWD 13 0 G/CM -0.176 1.102 0.0616451 2987 14059.5 15552.5 PEF MWD130 BARN 0.76 5.6 1.5154 2987 14059.5 15552.5 First Reading For Entire File......... .14053 Last Reading For Entire File.......... .15634 File Trailer Service name........... ..STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/09/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File