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Home My WebLink About205-176• 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. p2~ tj - ~ ~ ~p Well History File Identifier Organi2ing (aone> ^ Two-sided 111 II111111 III II III ^ Rescan Needed III 111111 II II III III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: Greyscale Items: ~ ~~~ ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: M ~ ~ ~ ~ / / / BY: aria Date: - s Project Proofing II I II iI II I I III I I III BY: Maria Date: ~--~ ~D ~ g /s/ / i P =TOTAL PAGES ~ -/ Scanning reparat on x 30 = + BY: _ Maria Date: ~U - Q I~ y (Count does not include cover sheet) /s/ ~, IIIIIIIIIIIIIIIIIII Production Scanning Stage 1 Page Count from Scanned File: ~~ (count does include cover sneer) Page Count Matches Number in Scanning Pre aration: V YES NO BY: Maria Date: ~,~~,~ ~ C~ lsl ~l~i l"' Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 1 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 11111'111 ~i111~1 Ilf P 10/612005 Well History File Cover Page.doc FW: 1L-25AL1 Page 1 of 2 - ~ ~ .zos-i ~~ Davies, Stephen F (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, July 31, 2007 12:05 PM To: Lemke, Sandra D (ConocoPhillips); Mahnken, Christine R (DOA); Davies, Stephen F (DOA) Subject: RE: 1 L-25AL1 Cancellation Letter Attachments: XL PTD 1L-25AL1.pdf Here is a copy of the letter that was submitted to the AOGCC to cancel 1 L-25AL1 (PTD 205-176, 50- 029-22174-60). The BOP test for 12/25/05 must have been for 1 L-25AL1-02 since it was the last leg drilled and it spudded on 12/19/2005, TD was reached on 12!27/05. If there is anything else I can check for you, please just let me know. Thanks! Terrie From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Friday, July 27, 2007 10:25 AM To: Hubble, Terrie L Cc: Christine_mahnken@admin.state.ak.us; Stephen Davies Subject: FW: 1L-25AL1 Just talked to Christine Mahnken and Steve Davies at AOGCC and they do not have a copy (did not receive a copy) of BP's 2/16/2006 letter saying please cancel permit 205-176; however Steve Davies said their well file had a copy of a BOP test for 1 L-25AL1 dated 12/25/05. Please contact Steve and discuss what paperwork is missing from AOGCC's files and which paperwork may need well name modification/clarification. Thanks. Sandra D. Lemke ConocoPhitlips Alaska Globo! Information Services (907) 265-6947 sandro. d. I emke@conocophill ips. cam ---Original Message-- Fmm: Lemke, Sandra D Sent: r-riday, July 27, 2007 10:04 AM To: Terrie Hubble Cc: 'christine__mahnken@admin.state.ak.us' Subject: FW:1L-25AL1 Terrie, we just pulled the file containing BP's paperwork notifying AOGCC that this leg was not drilled. I routinely get AOGCC paperwork generated by BP; but in this case a copy of the letter did not make it to me to make edits in ATDB to show the borehole as not drilled. We've got it corrected in ATDB now. No further action needed except to make sure I get this type of paperwork. I'm going to show 1L-25AL1 as not drilled effective 2/16/2007. Sandra D. Lemke ConocoPhill ips 8/1/2007 . FW: 1L-25AL1 ~ Page 2 of 2 • Alaska Global Information Services (9'07) 265-6947 sands. d.lemke@conocophillips. com --Original Message-- From: Lemke, Sandra D Sew: Friday, July 27, 2007 9:40 AM To: 'Hubble, Terrie L' Cc: Elgarico, Richard E Subject: 1L-25AL3 Terrie, Was this leg of the 1 L-25A complex drilled. We're waiting on logs and survey from Baker. The other borehole data was loaded back in January 2006. AOGCC shows no TD or other 'drilled' status info. Was this leg not drilled? Get back to Ricky with the answer when you tan. Thanks Terrie Sandra D. Lemke ConocoPhillips Alaska Global Information Services (907) 265-6947 sands. d. Lemke@conocophillips. com 8/1/2007 ~, by Terrie Hubble Technical Assistant GPB Dritlrng & weps February 16, 2006 Alaska ~i! & Gas Conservation Commission 333 Wes# 7'h Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-22174-60 Permit # 205-176, Kuparuk 1 L-25AL1 Direct: 1907} 564-4626 fiubb7etl®bp.corn To Whom It May Concern: ~' BP Exploration (Alaska} inc. 900 East Benson Boulevard P.O Box 79&612 Anchorage, Alaska 99 5 1 9-661 2 {3071 567-57 7 t Please cancel approved Permit to Drill for Kuparuk 1 L-25A1_1, Permit Number 205-176 {50-029-22174-60), This leg of this multilateral was not drilled. Thank you very much for your assistance in this matter. Sincerely, ~~ Terrie Hubble xc: Wel! Files PDC Performance Unit 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .€3E"3..ff`g~ ~~r~i~3_s~~'tf;~>t;u c~Z:~~~"d; ~'.i'~E.E~3~7 E?£? i3r'+0+~ ctt~:T?et~.a~;~~,'.c~~C._Ee ~3f~~...E£?~~E'115~£'~_f1 3~tF"E{~3;_S~c~'_f~;~?C;US Contractor: Nordic Rig No.: 2 DATE: 12/25/05 Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik/Feketi E-Mailsi~ac~~~~c~~i~;r~_r_tic"~c?ply?q~(~E~E_;,~~~~?.~_~~3 Well Name: 1 L-25AL1 PTD # 206-176 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2150 P Quantity Test Result 200 psi Attained 0:20 P No. Valves 14 P Full Pressure Attained 1:30 P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2150 Test Results Number of Failures: 0 Test Time: 5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviserat: ~iE~3_,.t~'g~~t~t~i~3_~Y~'kf;~~c,p Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-WE~II File YES NO X c - Oper./Rig Waived By John Crisp c - Dat~ibase Date 12/24/05 Time 0000 c -Trip Rpt File Witness Chuck Sevcik c -Inspector Test start 0700 Finish 1200 Coil Tubing BFL 11/09/04 Nordic 2 BOP 12-25-05p.xls Sean McLaughlin CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk 1L-25AL1 -FAX (907) 276-7542 Conoco Phillips Alaska Inc. Permit No: 205-176 Surface Location: 597' FNL, 143' FEL, SEC. 31, T11N, R10E, UM Bottomhole Location: 250' FNL, 3377' FWL, SEC. 05, T10N, R10E, UM Dear Mr. McLaughlin: 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 an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1 L-25A, Permit No 205-175, API 50-029-22174-0 l . Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the .Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, John K. Norman Chairman DATED this day of month, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ` ALASKA IL AND GAS CONSERVATION C EMISSION PERMIT TO DRILL 20 AAC 25.005 ,~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: Kuparuk 1 L-25AL1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 11600 ~ TVD 5843ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk ~ 4a. Location of Well (Governmental Section): Surface: ~ o 597' FNL 143' FEL SEC 31 T11N R10E UM 7. Property Designation: ADL 025664 ~ River Pool , , . , , , Top of Productive Horizon: 1292' FNL, 1284' FWL, SEC. 05, T10N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 20, 2005 Total Depth: 250' FNL, 3377' FWL, SEC. 05, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10250' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539925 ' - 5948371 ~ Zone- ASP4 10. KB Elevation (Height above GL): 130' feet 15. Distance to Nearest wen within Pool 1 L-26A is offset by 730' 16. Deviated Wells: Kickoff Depth: 10400 ~ feet Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3600 Surtace: 3016 18. asing rogram: Size SpeClfications Setting Depth To Bottom.. uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVDss MD TVD ° r1~-:;; includin sta a data 3" 2-3/8" 4.6# L-80 STL 2880' 8720'i 5771' 11600: 5843' ~ Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill AND Re-en#ry Operations) Total Depth MD (ft): 11600 Total Depth TVD (ft): 5870 Plugs (measured): None Effective Depth MD (ft): 11600 Effective Depth TVD (ft): 5870 Junk (measured): None Casin Len h Size Cement Volume MD TVD r r 122' 16" 35 sx Arcticset I 122' 122' 4978' 9-5/8" 00 sx Permafrost 'E', 550 sx Class 'G' 4978' 3614' Pro n 9331' 7" 50 sx Class 'G' 9331' 6293' r Liner 1 L-25A 2665' 2-3/8" Uncemented Slotted Liner 8935' - 11600' 5907' - 5870' Liner 1 L-25AL1-01 400' 2-3/8" Uncemented Slotted Liner 9350' - 9750' 5847' - 5840' Liner 1 L-25AL1-2 400' 2-3/8" Uncemented Slotted Liner 10400' - 10800' 5861' - 5847' Pertoration Depth MD (ft): None Pertoration Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Neme/Number: Si nature Jam- ~~L/~ Phone 564-4387 Date t~ 05 Terris Hubble, 56a-x628 Commission Use Only Permit To Drill Number: 2~~= /?~0 API Number: 50- 029-22174-60-00 Permit ro I ~{+~ Date: ~P ~~,Q ' (SD See cover letter for other requirements Conditions of Approval: Samples Required ~,, Yes ~;'No Mud Log Required ^ Yes ~j No Hydrogen Sulfide Measures I,~'Yes ^ No Directional Survey Required Yes ^ No Other: '~S ~ ~gi w~~ v~°cv~~..C~}Q ~s9~. ~`-~tcrrR~ C~C'`~~cs~n~~e ~~~ ~6 A i~L'~~~®~iS C~-1~ (,~1) ~ri~3„r~lt'~~ APPROVED BY DAN SEAMOUNT THE COMMISSION ? ' A roved B : Date Form i0-aot Revised o6/20oa Submit In Duplicate KRU 1~A, AL1-01, AL1-02, and AL1 Sidet~s -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling unit will dri1141aterals in producer KRU 1L-25 using the managed pressure drilling technique (MPD, see description below). These horizontal laterals will target Kuparuk C sand reserves for Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT,OA ~~~~~ ~ ~'-~~~ 5. Caliper 3-1/2 finer ~. Cemen~asing in preparatiyar--fm~cement ramp exit Rig Work ~./ 7. MIRU Nordic 2. NU 7-1/16" BOPE, test 1 L-25A 8. Mill 2.74" window off a cement ramp. Plan the top of ramp to start at 8838'. 9. Drill 3" bicenter hole horizontal lateral from window to 11600' TD targeting Kuparuk C sands. ] 0. Complete with a 2 segmented 2 3/8" slotted liner from TD to 8935' md. An aluminum billet will be on top of the second liner to use as a KOP for L1-O1. Use SSSV for liner run. 1 L-25AL l -01 11. Mill 2.74" window off the aluminum billet at 8935'. 12. Drill 3" bicenter hole horizontal lateral from window to 9750' TD targeting Kuparuk A sands. 13. Complete with a 2 3/8" slotted liner from TD, to 9350'. Use SSSV for liner run. 1 L-25AL 1-02 14. Mill 2.74" window off the aluminum billet at 9350'. 15. Drill 3" bicenter hole horizontal lateral from window to 10800' TD targeting Kuparuk A sands. m 2 3/8" slotted liner from TD, to 10400'. Use SSSV for liner run. l L-25AL 1 - ~,'~(~ 17. Mi112.74" window off the aluminum billet at 10400'. ~ 18. Drill 3" bicenter hole horizontal lateral to 11600' targeting Kuparuk A sands. ~ 19. Complete with 2 segmented 2 3/8" slotted liner from TD, to 8720'. Use SSSV for liner run. 20. ND BOPE. RDMO Nordic 2. ~`...~` ~~ Post Rig work 21. Post CTD rig -Run GLVs. Mud Program: • Step 8: chloride-based biozan brine (8.6 ppg) • Steps 9-20: chloride-based Flo-Pro (8.6 ppg} Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. KRU 1 ~iA, AL1-01, AL1-02, and AL1 Sidet~s -Coiled Tubing Drilling Casing Program: • 1 L-25A: 2 3/8", 4.6#, L-80, STL slotted liner from 8935' and to 11600' and • 1L-25AL 1-01: 2 3/8", 4.6#, L-80, STL slotted liner from 9350' and to 9750' and • 1L-25AL1-02: 2 3/8", 4.6#, L-80, STL slotted liner from 10400' and to 10800' and • IL-25AL1: 2 3/8", 4.6#, L-80, STL slotted liner from 8720' and to 11600' and Casin~/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4140; collapse 2900 psi 3 i/s", J-55, 9.3#, Burst 6990; collapse 7400 psi Well Control: • Two well bore volumes (-200 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1 L-25A, AL 1-01, AL 1-02, AL 1 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to IL-25A is 1L-26A which is offset by 2625'. KPA boundary is 11000' away. • The nearest well to l L-25AL 1-01, AL l -02, and AL 1 is also 1 L 26A which is offset by 730' . KPA boundary is 10250' away. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards • 1L-25A lateral will cross one mapped faults. Lost circulation risk is moderate. • 1L-25AL1-01 and AL1-02 will TD at a mapped fault. • 1 L-25AL 1 will cross 2 mapped faults • Expect to encounter increasing pressure as lateral is drilled away from the mother well. • Well 1L-29 has recorded 250 ppm H2S. All H2S monitoring equipment will be operational. Reservoir Pressure , • The most recent SBHP survey (9/05) was gauged at 3470 psi after a long term shut-in. The max. expected pressure is 3600 psi. The EMW is 11.9 ppg at 5840' TVD (ALl-Ol TD). Max. surface pressure with gas (0.1 psi/ft) to surface is 3016 psi. Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1L-25 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction KRU 1~A, AL1-01, AL1-02, and AL1 Sidet~s -Coiled Tubing Drilling and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and yvill be independent of the BOPE choke. This well has a tubing retrievable sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. However, it is still possible that deployment of the BHA under trapped wellhead pressure would be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2- 3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 1L-25A TD: • Estimated reservoir pressure: 3470 psi at 5870' TVD, 11.4 ppg EMW. ` ~{{~,x~• {=~~'`~ ~~ ~~' ~19~~1 ~/19~ti.<• • Expected annular friction losses while circulating: 1044 psi (based on 90 psi/1000 ft) iS~ , Planned mud density: 8.6 ppg equates to 2625 psi hydrostatic bottom hole pressure. "`~~~ • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3669 psi or 12.0 ~ ppg ECD • When circulation is stopped, a minimum of 1044 psi surface pressure will be applied to maintain constant BHP. KRU 1 L-25 ConocoPhillips Alaska, inc. 1 L-25 API: 500292217400 Well T INJ le TS: 51 8840 sssv SSSV Type: TRDP Orig li C 5/31!1991 Angle @ TD: 50 deg @ 9353 (~e~a~6~i. Annular Fluid: om on: Last W/O: 8/26/1992 Rev Reason: TAG FILL oo.s.soo) Reference L Ref L Date: Last U te: 2/27/2004 Last T : 9093 T0: 9353 ftKB Last Ta Date: 2/23/2004 Max Hole A le: 54 7100 Casin Stri -A LL STRING S Descri lion Size To Bottom TVD Wt Grede Thread CONDUCTOR 16.000 0 78 78 62.50 H-40 SUR. CASING 9.625 0 4978 3614 36.00 J-55 PROD. CASING 7.000 0 9331 6293 26.00 J-55 Tubi SW -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 8742 5915 9.30 J-55 EUE 8RD AB MOD Pertoretions Su mma Interval TVD Zone Status Ft SPF Date T Comment 8838 -8840 5976 - 5977 2 6 2/22/1992 RPERF 2 1/8" D na Stri • 0 h 8840 -8870 5977 - 5996 C-4 30 10 3/4/1993 RPERF 21/8" Scalbp Gun U; 0 deg. ph; Oriented 180 deg. F! Low Side 8870 -8872 5996 - 5997 C-4 2 4 3/4/1993 RPERF 2118" Scalkbp Gun U; 0 deg. ph; Oriented 180 deg. F/ Low Side 9039 -9065 6104 - 6121 A-5 26 4 6/16/1991 IPERF 4.5" Carrier 180 h 9138 - 9159 6168 - 6182 A-4 21 4 6/16/1991 IPERF 4.5" Carver 180 d h Gas Lift Ma ndre lsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2316 1905 Camco KBUG DMY 1.0 BK2 0.000 0 4/11/1993 2 3729 2809 Camco KBUG DMY 1.0 BK2 0.000 0 9/16/1994 3 4627 3391 Camco KBUG DMY 1.0 BK2 0.000 0 8/26/1992 4 5434 3905 Camco KBUG DMY 1.0 BK2 0.000 0 8/26/1992 5 6240 4395 Camco KBUG DMY 1.0 BK 0.000 0 9/16/1994 6 7076 4896 Camco KBUG DMY 1.0 BK2 0.000 0 8/26/1992 7 7910 5397 Camco KBUG DMY 1.0 BK2 0.000 0 8/26/1992 8 8629 5844 Camco MMG-2 DMY 1.5 RK 0.000 0 9/18/1994 Oth er lu s ui .etc. -JEWELRY De th TVD T Descri Uon ID 181 0 1582 SSSV Camco TRDP-4A-RO' 2.813 8678 5875 PBR Baker 3.000 8692 5884 PKR Baker'HB' 2.890 8708 5894 NIP Camco'D' Ni NO GO 2.750 8741 5914 SOS Baker 2.992 8742 5915 TTL 2.992 Generel Notes PeR Date Note (ee7e-ae7s• ~'3'50D) 3/21/1993 Coukf not get to bottom w/ 1(75" CTU; sucxessfut Go with 115" CTU See WSR 3/15193 PKR (86928693, 00:6.156) NIP (8708.8709• 00:3.500) TUBWJG (0.8742. 00:3.500. D:2.992) Pert (88388870) Parr (8838.8870) PeR (9039065) Pert (9138.9159) KRU 1 L-25A & L1 Producer Proposed C-sand CTD Completion DEV 10/21/05 ConocoPhillips Alaska, Inc, H. 3• h" Campo TRDP-4A•RO SSSV set at 1810' RKB, 2.813" iD E. 3• t2" 9.3A J-SS EUE 8rd Mod tubing w! 3.112" x 1" Campo 'KBtJG' mandrels 11-25A western lateral TD @ 11600' and ~ Aluminum billet @ 8935' and , 93rd" >~ J.SS Ct!litty Q 1978' 2.318" Iingr Kro [~ .68720' MD Window in 7" Top of Cement KOP at +/•8835' MD D. Campo 3.12' MMt3 gas1111 mandrel al 8829' RKB C. Baker 3.12' FIB pother et 8892' RKB B. 3 SS" Campo D rtipple with 2.75' ID at 8708' RKB A 3-12" tubing tail at 8742' RKB C-sand perfs C-sand perfs 1 L-25AL 1-01 1 L-25AL 1-02 1 l_-25AL 1 eastern lateral TD a(~. 11600' and 2-3/8" slotted liner 7" 2611 J-56 ~ a33~• Mo 2-318" blank liner across shale sections 500' stub liners (2-318" slotted) w/ aluminum billet KO BP Amoco rrnts°Tw 71RYlJ tai a ttatuu~ ..,..n 31.7r31M n.ea+l.+s.~tm Tb -w nor twlom lts. Ib1. D3dr WtL tM.lM °- M°~.1. °.r~°ia .~w i~r! T3.!!• aeo em a.m REFERENCE INFORMATION Ca-adhere (N/E) Reference: Well Centre: 25, True NoM VBNCeI D) Reference: Syslem: Mean Sea Level Section (VS) Reference: Sbl - (O.OON,O.OOE) Measured Depth Reference'. sb125 130.00 CalcuWeon Method: Minimum CurvaNre w M°a! 3r ` w.e • ell TIr Trp1 aem 7 ± ,3rn~A3 hM a~il~ i 0 >fNdms eXMOT.T10Me rug r rui TT MO M.wt-e-n rv~m~ w . w n ~ vy3o° 3leO.M 1MOOL0 TY m 1LilLLI-03 ~ 3teew3 lW]0.00 lM 110'MOP ~! Y61.l1 t03a0A0 3 iiN) M.~n Z~.i-Y~Y 6W Wri Ponl Nri.T t b°.00 ! 1L a~uii-~-pw1 S~tlEW N.¢ro Lq..b van 3!30!2 t0lNA3 f elTTAT 10936A! 1 3le0.n 11031 A! ! N3l.Yt tll37.N ! 3ML06 11lOOLO 19 saoo -600 -500 -400 fiit~ B (~~~ GNES t7p .r+~C -1200-1000 -600 -600 LEGEND T Pla". ~" ~ (~B" e, iL 25AL7) zs 7L-zs - 25 Plan ,iL-25AL1-0 ___ P 7 Azimuths to True North M Ma neticNorth:24.04° g Createde arMirhaelson Dale:lvtrzoos Y _. _ ______-. lan 6. 7L-25AL 25 - 25 PIanS. iL-25A) -Plan s,7L-zsALt p8n~ Magnetic Field Strength:57608nT .. __ _ .;>~wa Imormauon M Dip Angle:60.72° Die a~(9o7j 267-662a Date: 11/1/2005 Cell: (907)301-73570 Model: bggm2004 E-rnail~. bilLmichaelwn~integmm West(-)/East(+) [200ft/in] .._ Vertical Section at 75.00° [100ft/in] Cor~coPhil{ips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~tvTE Company:; ConocoPhillips Alaska, Inc. Date: 11/1/2005 Time: - 15:36:09 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 25, True North Site: KRU 1 L Pad Vertical(TVl)) Reference: slot 25' 130A Well: 25 Section'(VS) Reference: Well(O.OON,O.OOE,75.OOAzi) Wellpath: Plan 6, 1L-25AL1 Survey Calculation Method: Minimum Curvature Db: Oracle. Targets Map Map <- Latitude -> <- Longitude -> ~ Name Description TVD +N/-5 +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1L-25AL1 Faultl 130.00 -5363.03 3041.93 5943024.94 542992.90 70 15 18.836 N 149 39 9.224 W -Polygon 1 130.00 -5363.03 3041.93 5943024.94 542992.90 70 15 18.836 N 149 39 9.224 W -Polygon 2 130.00 -4562.96 3046.17 5943824.94 542992.90 70 15 26.705 N 149 39 9.091 W -Polygon 3 130.00 -4762.98 3045.11 5943624.94 542992.90 70 15 24.738 N 149 39 9.125 W 1L-25AL1 Faultl 130.00 -5363.03 3041.93 5943024.94 542992.90 70 15 18.836 N 149 39 9.224 W -Polygon 1 130.00 -5363.03 3041.93 5943024.94 542992.90 70 15 18.836 N 149 39 9.224 W -Polygon 2 130.00 -5563.04 3040.87 5942824.94 542992.90 70 15 16.869 N 149 39 9.258 W -Polygon 3 130.00 -5763.06 3039.81 5942624.94 542992.90 70 15 14.902 N 149 39 9.291 W 1 L-25AL1 Polygon 130.00 -5852.28 1389.14 5942526.97 541342.89 70 15 14.029 N 149 39 57.306 W -Polygon 1 130.00 -5852.28 1389.14 5942526.97 541342.89 70 15 14.029 N 149 39 57.306 W -Polygon 2 130.00 -5931.66 1269.71 5942446.97 541223.89 70 15 13.249 N 149 40 0.780 W -Polygon 3 130.00 -6221.08 1343.18 5942157.97 541298.89 70 15 10.402 N 149 39 58.645 W -Polygon 4 130.00 -6367.98 1697.44 5942012.97 541653.89 70 15 8.957 N 149 39 48.341 W -Polygon 5 130.00 -6295.32 2140.87 5942087.97 542096.89 70 15 9.670 N 149 39 35.443 W -Polygon 6 130.00 -6057.05 2660.20 5942328.97 542614.89 70 15 12.012 N 149 39 20.336 W -Polygon 7 130.00 -5717.27 3087.05 5942670.97 543039.89 70 15 15.352 N 149 39 7.916 W -Polygon 8 130.00 -5337.13 3445.10 5943052.97 543395.89 70 15 19.089 N 149 38 57.496 W -Polygon 9 130.00 -4926.44 3701.31 5943464.97 543649.89 70 15 23.127 N 149 38 50.037 W -Polygon 10 130.00 -4802.41 3508.95 5943587.97 543456.89 70 15 24.348 N 149 38 55.631 W -Polygon 11 130.00 X950.58 3350.14 5943438.97 543298.89 70 15 22.891 N 149 39 0.253 W -Polygon 12 130.00 -5199.91 3217.81 5943188.97 543167.89 70 15 20.440 N 149 39 4.106 W -Polygon 13 130.00 -5479.21 2891.29 5942907.97 542842.89 70 15 17.694 N 149 39 13.608 W -Polygon 14 130.00 -5832.33 2529.37 5942552.97 542482.89 70 15 14.222 N 149 39 24.139 W -Polygon 15 130.00 -5953.46 2173.69 5942429.97 542127.89 70 15 13.032 N 149 39 34.486 W -Polygon 16 130.00 -6009.90 2068.38 5942372.97 542022.89 70 15 12.477 N 149 39 37.550 W -Polygon 17 130.00 -6074.42 1787.01 5942306.97 541741.89 70 15 11.844 N 149 39 45.734 W Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1 L Pad Site Position: Northing: 5948968.90 ft Latitude: 70 16 17.459 N From: Map Easting: 540062.68 ft Longitude: 149 40 33.550 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.31 deg Well: 25 Slot Name: Well Position: +N/-S -596.97 ft Northing: 5948371.23 ft Latitude: 70 16 11.588 N +E/-W -143.01 ft Easting : 539922.87 ft Longitude: 149 40 37.713 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 1 L-25AL1 Drilled From: Plan 6, 1 L-25AL7-02 Tie-on Depth: 10400.00 ft Current Datum: slot 25 Height 130.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2005 Declination: 24.04 deg Field Strength: 57608 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 75.00 Plan: Plan #6 Date Composed: 11/1/2005 copy Lamar's plan 6 Version: 4 Principal: Yes Tied-to: From: Definitive Path Conoco~illips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report «vTtE~ Companye ConocoPhillips Alaska. .lna Date: . 11/1/2005 Time: 15[36:09 Page: 2 Field: Kuparuk Rive r Unit. Co-ordinate(NE) Reference: Weil 25, True North Site: RRIJ 1 L Pad Vertical (TVD) Reference: slot 25 1.30.0 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,75.OOAzi) Wellpath: Plan 6, 1L-25AL1 Survey Calculation Method: Minimum Gunrature Db: Oracle ~ Targets - Map ' Map <- Latitude --> ~ <- Longitude --> Name Description TVD +Ni-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 18 130.00 -6051.44 1603.11 5942328.97 541557.89 70 15 12.070 N 149 39 51.083 W -Polygon 19 130.00 -5835.91 1507.24 5942543.97 541460.89 70 15 14.190 N 149 39 53.870 W 1L-25AL1 Fault3 130.00 -4792.36 3492.02 5943597.93 543439.91 70 15 24.447 N 149 38 56.124 W -Polygon 1 130.00 -4792.36 3492.02 5943597.93 543439.91 70 15 24.447 N 149 38 56.124 W -Polygon 2 130.00 -4992.37 3490.96 5943397.93 543439.91 70 15 22.480 N 149 38 56.157 W -Polygon 3 130.00 -5192.39 3489.90 5943197.93 543439.91 70 15 20.512 N 149 38 56.191 W 1 L-25AL1 Target 9 5973.00 -4937.67 3548.25 5943452.93 543496.91 70 15 23.017 N 149 38 54.490 W 1L-25AL1 Target8 6000.00 -5347.83 3194.03 5943040.94 543144.90 70 15 18.985 N 149 39 4.800 W 1L-25AL1 Target 7 6010.00 -5510.03 3040.15 5942877.94 542991.90 70 15 17.390 N 149 39 9.278 W Annotation MD TVD ft " ft: 10400.00 5990.68 Tie to l 1-25AL1-02 10420.00 5990.45 End 20°1100' DLS 10520.00 5992.61 3 10660.00 5994.94 4 10740.00 6002.71 5 10826.48 6010.52 6 10926.48 6007.47 7 11051.48 5999.95 8 11251.48 5988.91 9 11600.00 5972.96 TD Plan Section Information MD Incl Azim TVD ' +N/,S +E/-W DLS Build Turn TFO Target ft deg deg ft tt ft :::: deg/100ft degi100ft deg/100ft deg ; 10400.00 92.65 47.60 5990.68 -5801.53 2740.23 0.00 0.00 0.00 0.00 10420.00 88.65 47.60 5990.45 -5788.04 2755.00 20.00 -20.00 0.00 180.00 10520.00 88.89 59.60 5992.61 -5728.82 2835.32 12.00 0.24 12.00 89.00 10660.00 89.22 42.80 5994.94 -5641.41 2944.01 12.00 0.24 -12.00 271.00 10740.00 79.62 42.80 6002.71 -5583.06 2998.04 12.00 -12.00 0.00 180.00 10826.48 90.00 42.80 6010.52 -5519.95 3056.48 12.00 12.00 0.00 0.00 10926.48 93.49 31.31 6007.47 -5440.33 3116.60 12.00 3.49 -11.49 287.00 11051.48 93.37 46.33 5999.95 -5343.39 3194.60 12.00 -0.10 12.02 90.00 11251.48 92.87 22.30 5988.91 -5179.66 3306.35 12.00 -0.25 -12.02 269.50 11600.00 92.14 64.16 5972.96 -4931.63 3539.58 12.00 -0.21 12.01 90.00 Survey MD Incl Azim "SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 10400.00 92.65 47.60 5860.68 -5801.53 2740.23 5942584.89 542693.56 0.00 1145.31 0.00 MWD 10420.00 88.65 47.60 5860.45 -5788.04 2755.00 5942598.45 542708.25 20.00 1163.07 180.00 MWD 10425.00 88.66 48.20 5860.57 -5784.69 2758.70 5942601.82 542711.94 12.00 1167.52 89.00 MWD 10450.00 88.71 51.20 5861.14 -5768.53 2777.76 5942618.08 542730.91 12.00 1190.11 88.99 MWD 10475.00 88.77 54.20 5861.69 -5753.38 2797.64 5942633.33 542750.71 12.00 1213.23 88.92 MWD 10500.00 88.83 57.20 5862.21 -5739.30 2818.29 5942647.53 542771.28 12.00 1236.82 88.85 MWD 10520.00 88.89 59.60 5862.61 -5728.82 2835.32 5942658.09 542788.25 12.00 1255.98 88.79 MWD 10525.00 88.90 59.00 5862.71 -5726.27 2839.61 5942660.67 542792.53 12.00 1260.79 271.00 MWD 10550.00 88.95 56.00 5863.18 -5712.84 2860.69 5942674.21 542813.54 12.00 1284.62 271.01 MWD 10575.00 89.01 53.00 5863.62 -5698.32 2881.04 5942688.83 542833.80 12.00 1308.03 271.07 MWD 10600.00 89.07 50.00 5864.04 -5682.76 2900.60 5942704.49 542853.28 12.00 1330.95 271.12 MWD 10625.00 89.13 47.00 5864.44 -5666.20 2919.32 5942721.15 542871.91 12.00 1353.32 271.17 MWD ConocoPhillips • • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~ii~ ~~T~~ Company: ConocoPhillips Alaska, Inc. Date: . 11/1/2005 Time: " 15:36:09 Page: 3 Field:: Kuparuk River Unit Co-ordinnte(NE) Reterence: WeIL• 25, True North Site: KRU 1 L'Pad Vertical (TVD) Reference: slot 25 130.0 Well: 25 Section (VS) Reference: Well (O.OON, O.OOE,75. OOAzi) Wellpath: , Pla n 6, 1L-25AL1 Survey Calculation Method: Minimum Curvature 1)b: Oracle Survey MD " Inch Azim SS TVD N/S' E/W MapN MapE DLS VS , TFO Tool ft deg deg ft ft ft ft' ft .: :deg/1OOft ft deg 10650.00 89.20 44.00 5864.80 -5648.68 2937.14 5942738.77 542889.64 12.00 1375.08 271.22 MWD 10660.00 89.22 42.80 5864.94 -5641.41 2944.01 5942746.07 542896.47 12.00 1383.59 271.26 MWD 10675.00 87.42 42.80 5865.38 -5630.41 2954.20 5942757.12 542906.59 12.00 1396.28 180.00 MWD 10700.00 84.42 42.80 5867.16 -5612.12 2971.14 5942775.50 542923.44 12.00 1417.38 180.00 MWD 10725.00 81.42 42.80 5870.24 -5593.91 2987.99 5942793.79 542940.19 12.00 1438.37 180.00 MWD 10740.00 79.62 42.80 5872.71 -5583.06 2998.04 5942804.70 542950.18 12.00 1450.89 180.00 MWD 10750.00 80.82 42.80 5874.40 -5575.83 3004.74 5942811.97 542956.84 12.00 1459.22 0.00 MWD 10775.00 83.82 42.80 5877.74 -5557.65 3021.57 5942830.23 542973.57 12.00 1480.19 360.00 MWD 10800.00 86.82 42.80 5879.78 -5539.37 3038.50 5942848.60 542990.40 12.00 1501.27 0.00 M W D 10825.00 89.82 42.80 5880.51 -5521.04 3055.47 5942867.02 543007.28 12.00 1522.41 0.00 MWD 10826.48 90.00 42.80 5880.52 -5519.95 3056.48 5942868.12 543008.28 12.00 1523.67 360.00 MWD 10850.00 90.82 40.10 5880.35 -5502.32 3072.04 5942885.82 543023.75 12.00 1543.26 287.00 MWD 10875.00 91.70 3723 5879.80 -5482.81 3087.66 5942905.42 543039.26 12.00 1563.39 286.98 MWD 10900.00 92.57 34.36 5878.87 -5462.55 3102.27 5942925.75 543053.76 12.00 1582.75 286.92 MWD 10925.00 93.43 31.48 5877.56 -5441.59 3115.83 5942946.78 543067.21 12.00 1601.28 286.81 MWD 10926.48 93.49 31.31 5877.47 -5440.33 3116.60 5942948.05 543067.97 12.00 1602.35 286.66 MWD 10950.00 93.48 34.13 5876.04 -5420.58 3129.29 5942967.86 543080.55 12.00 1619.71 90.00 MWD 10975.00 93.47 37.14 5874.52 -5400.30 3143.83 5942988.21 543094.98 12.00 1639.00 90.17 MWD 11000.00 93.44 40.15 5873.02 -5380.81 3159.41 5943007.78 543110.46 12.00 1659.10 90.35 MWD 11025.00 93.41 43.15 5871.52 -5362.17 3175.99 5943026.51 543126.94 12.00 1679.94 90.54 MWD 11050.00 93.37 46.16 5870.04 -5344.42 3193.53 5943044.35 543144.38 12.00 1701.48 90.71 MWD 11051.48 93.37 46.33 5869.95 -5343.39 3194.60 5943045.38 543145.45 12.00 1702.77 90.89 MWD 11075.00 93.34 43.51 5868.58 -5326.77 3211.17 5943062.09 543161.93 12.00 1723.09 269.50 MWD 11100.00 93.30 40.50 5867.13 -5308.23 3227.87 5943080.72 543178.53 12.00 1744.02 269.33 M W D 11125.00 93.25 37.50 5865.70 -5288.83 3243.58 5943100.20 543194.13 12.00 1764.21 269.16 MWD 11150.00 93.19 34.49 5864.30 -5268.64 3258.25 5943120.46 543208.69 12.00 1783.60 268.99 MWD 11175.00 93.13 31.49 5862.92 -5247.71 3271.84 5943141.47 543222.17 12.00 1802.15 268.82 MWD 11200.00 93.05 28.49 5861.57 -5226.09 3284.32 5943163.15 543234.53 12.00 1819.79 268.65 MWD 11225.00 92.97 25.48 5860.26 -5203.84 3295.64 5943185.45 543245.74 12.00 1836.49 268.49 MWD 11250.00 92.88 22.48 5858.99 -5181.03 3305.79 5943208.31 543255.76 12.00 1852.20 268.34 MWD 11251.48 92.87 22.30 5858.91 -5179.66 3306.35 5943209.69 543256.32 12.00 1853.10 268.18 MWD 11275.00 92.87 25.13 5857.73 -5158.16 3315.80 5943231.24 543265.65 12.00 1867.79 90.00 MWD 11300.00 92.86 28.13 5856.48 -5135.84 3326.99 5943253.61 543276.72 12.00 1884.37 90.14 MWD 11325.00 92.84 31.14 5855.24 -5114.14 3339.33 5943275.37 543288.95 12.00 1901.91 90.29 MWD 11350.00 92.81 34.14 5854.01 -5093.12 3352.80 5943296.47 543302.30 12.00 1920.36 90.44 MWD 11375.00 92.78 37.14 5852.79 -5072.83 3367.35 5943316.83 543316.74 12.00 1939.66 90.59 MWD 11400.00 92.73 40.15 5851.59 -5053.33 3382.94 5943336.42 543332.23 12.00 1959.77 90.74 MWD 11425.00 92.68 43.15 5850.41 -5034.67 3399.53 5943355.16 543348.72 12.00 1980.63 90.88 MWD 11450.00 92.63 46.15 5849.25 -5016.90 3417.08 5943373.01 543366.17 12.00 2002.18 91.02 MWD 11475.00 92.56 49.15 5848.12 -5000.08 3435.54 5943389.93 543384.54 12.00 2024.36 91.16 MWD 11500.00 92.49 52.16 5847.02 -4984.25 3454.85 5943405.87 543403.76 12.00 2047.11 91.30 MWD 11525.00 92.41 55.16 5845.95 -4969.45 3474.97 5943420.77 543423.80 12.00 2070.37 91.43 MWD 11550.00 92.33 58.16 5844.91 -4955.72 3495.83 5943434.61 543444.59 12.00 2094.08 91.56 MWD 11575.00 92.24 61.16 5843.92 -4943.10 3517.39 5943447.34 543466.07 12.00 2118.17 91.68 MWD 11600.00 92.14 64.16 5842.96 ~ -4931.63 3539.58 5943458.93 543488.20 12.00 2142.57 91.80 MWD ! • • PERMIT TO ®RILL 20 AAC 25.005 • (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need n®t include the $100 fee. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pAR?,GRAPHS TO BE INCLLiDED IN TRANSMITTAL LETTER WELL NAME ~l~ ~~ ~ Z ~ ~ PTD# `~~~- Zvi- ~-~~ " " CHECK WHAT ~ ADD-ONS CLUE APPLIES (OPTIONS) ment of llb MULTI o a seg The permit is for a new we r ~ ~~` Z ~ ' LATERAL ; existing well K zZi 7 ~-/- ~''_~Z~. Permit No, ~b5= l~~API No, ~ i V API number (If Production should continue to be reported as ~ ' last two (2) digits a function of .the original API number stated i ~~ are between 60-69) ~ above. all 005(f} 25 ~ PILOT HOLE I , . In accordance with 20 AAC data and logs acquired for the pilot records i (per ~ , hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - ~ 70/SO} from records, data and logs acquired ~ j i for well (name on permit). ~ t to full b r SPACIl~TG i ~ )ec The permit is approved su ` EXCEPTION ' to compliance with 20 AAC 25.055. Approval ~ perforate and produce/infect is contingent I ~ upon issuance of a conservation order approving a spacing exception. I, i (Company Name)_assumes ~ ~ the liability of any protest to the spacing ~ exception that may occur. i d to the itt b , DRY DITCH e m Alt dry ditch sample sets su I ~ SAMPLE Commission must be in no greater than 30' , j i i sample intervals from below the permafrost i or from where samples are first caught and ~ w I ~ i 10' sample intervals through target zones. ~ i i ~ r, Rev: 04/01/05 C\jody\transm itta I_checklist W LL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL - 490100 -Well Name: KUPARUK RIV UNIT 1L-25AL1 Program DEV Well bore seg [] PTD#:2051760 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/off Shore On Annular Disposal ^ Administration 1 Permit-fee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ . - _ _ _ _ Multilateral well bore; fee Waived- er 20_AAC 25.005 e p O 2 Lease number appropriates--.~-~~~~--~______________________._ Yes ___- 3 Uniquewell_nameandnumber________________________-____-,...___ Yes_ ____--.,_-_- 4 Well located in_a_d_efinedpool- . - - Yes KUPARUK RIVER,-KUPARUK RVOIL - 4Q0.100, governed by Conservation Order No. 432C. 5 Well located proper distance from drilling unitboundary_ - - - _ - Yes _ Conservation Order No. 4320 ~ntains no spacin restrictions with respect to dr_illin unik boundaries. - g- g 6 Well located proper distance_from other wells- _ _ _ - - _ Yes - _ Conservation Order No. 4320 has.no in_terwell-spacing restrictions. 7 Sufficient acreage available in-drilling unit- _ - - - Yes Conservation Order No. 4320 has_no intenyell_spacing-restrictions: Wellbore will be_more than 500' from _ - - 8 If deviated, is-Wellbore platincluded - - - - - - - - - Yes _ - - - - an_external _ro rt line_whe[e-ownership or-lan_downershi chan es.. P Pe Y p 9 - 9 Operator only affected party - - - Yes - - - - - 10 Ope[atorhasappropriate-bondinfQrce_________________________..--_-- Yes. _.-___.___.___________._________.._-_ 11 Permit can be issued without conservation order - Yes - - - - - - Appr Date 12 Permit can be issued without administrative_appr_oval _ . - - _ - Yes - _ - - - -- SFD 11/1412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_Injection Order # (put 10# in_comments)-(For- NA_ - - . 15 AIt wells within 1!4_milearea of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ . _ _ - _ _ . - _ _ - - _ _ _ _ _ - 16 Pre-produced injector duration of pre production Less than 3 months-(For service well only) _ - NA_ - _ - - - - 17 ACMP_Finding of Consistency_has been issued_forthis project- . _ - - - _ _ . NA_ - - - Engineering 18 _on_u_ctorstring,provre___----__-_---__---____--____- NA_- ___--_-onductorset-in motherbgre,_1L-25_(1.91-070)___________________-____---__ ---------- 19 Surface casing_protectsallknown-USDWs_____________________-_____--_ NA__ ___-.-Allaquifersexempted, 40CFR-147.102(bj(3),___----_____---__,-__________ 20 CMT_vol-adequate_to circulate-on conductor_& surf_csg - _ _ - - - _ NA_ - - - - Surface casing set in_ motherbore-- - - - - - - - - - -- - - - - - - - - 21 _C_MT-vol adeguate_to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ - - _ Pr_oduction_casing set in_motherbore. _ - - _ _ - _ _ _ - - - _ 22 CMT_will cover all known-productive horizons- - No_ - - _ Slotted liner completion planned, - - - 23 Casing designs adequate far C, T B &-permafrost- .. - - NA_ - original well tubulars_met design_requirements. _NA for slotted liner.- - . - ~ _ 24 Adequate ianicage_or reserve pit - - _ - - - . - Yes _ - - _ Rig is.equipped with steel-pits. No reserve_pitplanne_d, All waste to approved disposal wells.- _ 25 Ifa_re-drill,has_a10-403forabandonmentbeenapproved______________________ Yes_ ___- _305-348,-processed 11108105.____---_____-._____--_-___-,--__--.- 26 Adequate wellbore- separation_proposed_ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - . _ _ _ _ _ Proximity. analysis performed, Nearest well section.is 1 L-25A-and paths diverge, _ _ . _ _ - _ _ _ . , _ _ - _ . - - - _ 27 If diverter required, does it meet regulations- _ - _ _ - NA_ Bop_stack will already be in_place.. - . - - . . Appr Date 28 Drilling fluid-program schematic-& equip list adequate- _ - - Yes - - - ...Maximum expected fprmation pressure 11.9 EMW._ Managed- pressure drilling-planned, w/8,6_ppg fluid and-applie_ TEM 11/1512005 29 BOPEs, do the meet re elation _ _ . _ Y 9 Yes _ _ - pressure via friction or trapped pressure. _2_well volumes of kill weight fluid available on_location. - _ _ _ - } 30 BOPE_ ress ratio a ro riate; test to- ut si m comments P 9PpP P P9• ) - - No_ . . MASP calculated at 3016 si 3500_ sr minimum BOP test p P ~/j~j- ~~ 31 Choke_manifoldcomp_liesw/API-RP-53 (May$4)_--____ _--_ Yes_ __ ----------------- _---_ 32 Work willoccu[withoutoperationshutdown__-____---._________----- Yes_ ______--._____-___ - - - 33 Is presence-of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ _ . Up to 240 ppm H2S reported on 1L pad. Mud should preclude H2S on rig... Rig has_sensors_ and alarms. _ - - _ - _ 34 Mechanical-condition of wells within AOR verified (Forseruice well only) NA_ - _ - - . - - Geology 35 Permit_can be issued wlo hydrogen_s_ulfide measures _ - - - - - - No_ _ - - Concentrations up to_2.50 ppm H2$ have been- measured on 1 L-Pad-we_Ils. H2S measures [equired._ _ 36 Data_presented on_potential overpressure zones- _ . - - Yes - - - - - -Expected resen!oirpressure is 11.4-11.9ppg EMW; will be drilled with coiled_tubingand 8,6_ppg mud Appr Date 37 Seismic analysis ofshallow gaszones- - _ - . _ - NA_ using overbalanced pressure drilling_techniques to achieve 12.0 ppg-equivalent circulating density. SFD- - - - SFD 11/14!2005 38 Seabed condition surYey-(if off-shore) - . - _ _ - - _ NA- - -~ - 39 -Contact namelphone_forweekly progress_reports [exploratory only]- NA_ - . _ Geologic Engineering Public Com 'ssio er: Da te r: D ate Commissioner Date C o mmi ione s s /J~ ///// / / ~ / ~ ) p ~ ~ lI ~ ~' ~ ~L/ ~ ' / ~ `~/ V "c~J/~ { a