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207-044
Imo Pr~o'ect Well Histo File Co~r Pa e ge 1 rY g 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. `-'4 Q ~ - Q ~~-~- Well History File Identifier Or anizin (aone> 9 9 ^ Two-sided III IIIIIIII II) VIII ^ Rescan Needed III II~IIIIIII IIIIII RES AN 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:: BY: Maria Date: d /s/ Proogn Project g I IIIIIIIIIIIIIIIIII BY: Maria Date: ~Q ~s~ = + =TOTAL PAGES Scanning Preparation x 30 ` (Count ~~es nit include cover sheet) BY: Maria ~ Date: / ~ /©~ ~s~ Production Scanning Stage 7 Page Count from Scanned File: ~~ (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~,~p~ ~~ ~s~ 1 1 Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO I BY: Maria Date: ~s~ f l Scanning is complete at this point unless rescanning is required. III III)II III II III ReScanned BY: Maria Comments about this file: Date: ~s~ Quality Checked IIIIIIIIIIIIIIIIII 10/6/2005 Well History File Cover Page.doc ~,ti °. ~~~,. ~; .= ;~;~ ,~. ,, ,, ~. ~, P _. ~~; ~. ~; ~~ „r ~: ~ _~ ~~~ _~•~ f ~~' '~ ,. MICROFILMED 6/30/2010 DO NOT PLACE. ANY .NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc by Terrie Hubble Technical Assistant Drilling & Wells May 8, 2007 ~~,~,~, ~~\~~~,: ~•= =~. ~~. ~~~ ~~:~',~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-20535-60-00 Direct: (907) 564-4628 hubbletl~bp.com Permit # 207-044, Kuparuk 1 C-03L1 To Whom It May Concern: i~E~E~~E® MAY Q g ZOp7 Alaska OFI & Gas Cons, Canmission AOCf10fa~g Please cancel approved Permit to Drill for Kuparuk 1 C-03L1, Permit Number ~---~ 207-044 (50-029-20535-60-00). This well will now be drilled as a Sidetrack (1 C- 03A) instead of a lateral leg. Anew Pemit to Drill for this sidetrack is respectfully submitted. Thank you very much for your assistance in this matter. Sincerely, ./-~ ~~~,w Terrie Hubble xc: Well Files PDC Gary Eller, ConocoPhillips Re: 1C-03L1: Cement for Cement Ramp Exit Subject: Re: 1C-03L1: Cement for Cement Ramp Exit From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 03 May 2007 15:49:35-.0800 I'o: "Eller, J G~~ry-" ~=.1.Gary.Eller~u!eonocophillips.conl== C'C: Sie~,e Day ies <stc~ e davicsi~i'admin.state.ak.us:.> Gary, This confirms our conversation of a few moments ago regarding the process forward on this well. Since the existing perforations in the well will be covered with cement the penetration is considered abandoned. A 403 will be needed for authorization of the cementing work. Further the new penetration will now be a sidetrack so a new 401 with check for 1 C-03A will need to be submitted. CPAI should request that the existing permit be canceled. You have indicated that you are working on the 403 and that it should be delivered to the AOGCC office today. You further indicated that the pumping of the cement via service coil is the only time critical task since actual drilling is not planned for about a week. I will look forward to receiving the sundry. I should be here until at least 1630. Call or message with any questions. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 5/3/2007 2:52 PM: Tom - As I explained over the phone, the whipstock that was planned for well 1 C-03L1 (PTD 207-044) will not be ready in time for the spud of that well. Instead, as was identified as our contingency plan on the original PTD application, we'll place a cement plug from PBTD (-9160' MD) up to 9010' MD for purposes of a cement ramp exit. Our procedure calls for laying in 10 bbl of cement then washing back down to the tubing tail at 9010' MD. We plan to perform this operation tomorrow. Please let me know if you have any questions, and thanks for your help. cell: 907-529-1979 fax: 907-265-t535 1 of 1 5/3/2007 4:00 PM SARAH PAL1N, GOVERNOR ~aa78~ OI~ ~D uva~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA~'I011T COrIIrI155I01~' ANCHORAGE, ALASKA 99501-3539 PHONE . (907) 279-1433 Gary Eller FAx (so7~ 27sasa2 CT Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 C-03L 1 ConocoPhillips Alaska, Inc. Permit No: 207-044 Surface Location: 1583' FNL, 1165' FWL, SEC. 12, T11N, R10E, UM Bottomhole Location: 2163' FNL, 2073' FEL, SEC. 11, T11, R10E, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above. referenced development well. The permit is for a new wellbore segment of existing well KRU 1 C-03, Permit No 180- 138, API 50-029-20535-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the C mission to witness any required test, contact the Commission's petroleum f 11d ins a for at (907) 659-3607 (pager). DATED this.~T/ day of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - CC ~~G~ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N ~~~~5 NEAR 2 7 2007 PERMIT TO DRILL t~,iaska 0~; ~ Gas Cons. Commission 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ~ ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180. 11. Well Name and Number: 1 C-03L1 3. Address: c!o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 12525. TVD 6390ss 12. Field /Pool(s): Kuparuk River Unit I Kuparuk 4a. Location of Well (Governmental Section): Surface: 1583' FNL 1165' FWL 12 R10E UM SEC T11 N 7. Property Designation: ADL 025649 River Pool , , . , , , Top of Productive Horizon: 3991' FNL, 4210' FEL, SEC. 11, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 18, 2007 Total Depth: 2163' FNL, 2073' FEL, SEC. 11, T11N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 14,650' 4b. Location of Well (State Base Plane Coordinates): Surface: x-562173 y-5968656 Zone-ASP4 10. KB Elevation (Height above GL): 94 feet 15. Distance to Nearest Well Within Pool: 850' 16. Deviated Wells: Kickoff Depth: 8125 ~ feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3413 ' Surface: 3072 ' 18:' Casin `Pr ram: S ecificatio ns To -'Settin De th -:Bo ttom uah ' of ment c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 3525' 9000' 6262' 12525' 6390' Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed. for Redrill: and Re-entry Operations) Total Depth MD (ft): 9700 Total Depth TVD (ft): Plugs (measured): 6821 None Effective Depth MD (ft): 9589 Effective Depth TVD (ft): 6747 Junk (measured): None Casing Length ize ement Volume MD TVD Conductor! Structural g0' 16" 200 sx P rmafrost 80' 80' Surface 3214' 10-3/4" 1500 sx Fondu 250 sx AS II 3214' 2682' Intermediate Production 9675' 7" 72 sx CI 75' 6 04' Liner Perforation Depth MD (ft): 9101' - 92 1' Perforation Depth TVD (ft): 6421' - 6500' 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 c ify that the fore oing is true and correct. Contact Gary Eller, 529-1979 Printed Na Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 529-1979 Date ~ (0 01 Terrie Hubble, 564-4628 .Commission .Use Onl Permit To Drill Number: ? ~T API Number: 50-029-20535-60-00 Permit Approval See cover letter for Date: • oth r re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/a'ne, gas hydra , or gas contained shales: ~/' Samples Req'd: ^ Yes LrJ No Mud Log Req'd: ^ Yes L~JNo HzS Measures: Q'Yes ^ No nal Survey Req'd: [r]'S'es ^ No Other: ~~ ~ < ~~ .~~,~ ~n PROVED BY THE COMMISSION Date ~~~v ~^'~~ ,COMMISSIONER Form 10-401 Revised 12!2005 ~~~r,~r,i®~ ~./ ~ Submit In Duplicate 3•z~.o~ ~/~~ 7 KR~-03L7 Sidetrack Lateral - Coile ubing Drilling Summary of Operations: ; A coiled tubing drilling unit will drill a single 3400' lateral in producer KRU 1C-03 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk C3/4 sand reserves for increased pattern throughput and sweep efficiency. - CTD Drill and Complete 1C-03 program: Planned for Apri12007 ' Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs - T & IC. 3. Slickline tag fill. 4. Slickline dummy off GLVs. 5. MTT-IA, MTT-OA. 6. Run 24-arm caliper in 7" casing below tubing tail. 7. Coil tubing: mill out 2.75" D nipple to 2.80" ID to allow running of whipstock Rig Work 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Set 3'/z" x 7" through-tubing whipstock at 9125' MD. a. It is planned that we will run a new style through-tubing whipstock in 1C-03 which will allow the perfs in the parent well to remain open. If the through-tubing whipstock is not successful, we will place cement across the existing perfs for a cement ramp exit. A separate sundry application will be filed if cement is to be pumped to isolate the C sand perfs in 1 C-03. 3. Mi112.74" window off of the whipstock and 10' of open hole from 9125' MD. 4. Drill the 1C-03L1 lateral to the east with a 2.74" x 3" bi-center bit from the window at 9125' MD to TD of 12,525' MD targeting the Kuparuk C3/4 sand. 5. Complete the L1 lateral with a 23/8" slotted liner. The top of the 23/8" liner will be inside the 31/z" tubing tail at 9000' MD. a. There is a contingency that the L1 lateral be completed with a 23/8" solid, cemented liner. In that event, we will install aliner-top packer and perforate the liner at select intervals. The ultimate completion particulars as installed will be communicated via the 10-407 completion notice. 6. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Post CTD rig -Run GLVs, obtain static BHP. Mud Program: • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud (8.6 ppg) for drilling operations. Will have to kill the well to deploy 23/8" slotted liner since the SCSSV has been locked out. 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. Page 1 of 3 March 26, 2007, FINAL KR~C-03L1 Sidetrack Lateral - Coilubing Drilling Casing Program: • 23/8", 4.6#, L-80, STL slotted liner from 10,100' MD to 12,525' MD ' • 23/8", 4.6#, L-80, STL solid liner cemented in place from 9000' MD to 10,100' MD Existing Casing/Liner Information Surface: 103/a", K-55, 45.5# Burst 3580 psi; Collapse 2090 psi. Production: 7", K-55, 26# Burst 4980 psi; Collapse 4320 psi Well Control: • Two well bore volumes (--220 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure is 3072 psi assuming a gas gradient to surface and maximum expected formation pressure (i.e. 3413 psi based on SBHP in 1D-14 in October 1999). • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plans for 1C-03L1. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1C-03L1 is 1C-04 which will be offset by 850' at the TD of 12,525' MD. The KRU boundary is 14650' away. Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Hazards • Significant lost circulation is expected to be a low/medium risk due to somewhat low BHP in the 1C-03 wellbore (i.e. 8.3 ppg EMW in October 2006) and potentially high ECD. Expect to encounter slightly increasing pressure as the lateral is drilled away from the mother well. • Well 1C-03L1 is planned to be the first field application of a new 3'/i" x 7" through-tubing whipstock. This whipstock is undergoing additional shop testing at this time. If the whipstock proves to not be ready in time for 1C-03L1 or if it fails in the well, a cement plug will be placed across the C sand perfs in preparation for a cement ramp exit. This contingency exit will be at 9112' MD in 1C-03. • Well 1C-03 has a HZS reading of 60 ppm as measured on 6/18/06. Wells 1C-14 and 1C-21 are adjacent to 1C-03. Well 1C,21 has 80 ppm HZS as measured on 6/18/06, and well 1C-14 has no HZS (injection well). The maximum HZS level on the 1C pad is 170 ppm from well 1C-104 on 6/18/06. All HZS monitoring equipment will be operational. Reservoir Pressure The most recent static BHP survey in well 1C-03 in October 2006 showed reservoir pressure of 2798 psi at 6460' TVD which corresponds to 8.3 ppg EMW. Expect to encounter increasing pressure as lateral is drilled away froth mother well. Maximum expected pressure is 3413 psi which corresponds to an EMW of 10.2 ppg at 6429' TVD (L1 KOP). Maximum surface pressure with gas (0.1 psUft) to surface is 3072 psi. ^ - Variance request • none Page 2 of 3 March 26, 2007, FINAL KR~C-03L1 Sidetrack Lateral - Coil~ubing Drilling Managed Pressure Drilling Managed pressure drilling (MPD) 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 and choke pressure also allow use of less expensive 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 he installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (i.e. 23/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. The SCSSV in well 1C-03 has been locked out, so the well will have to be killed prior to running 23/8" slotted liner. 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 TD: • Estimated reservoir pressure: 2798 psi at 9160' MD (6460' TVD), or 8.3 ppg EMW. • Expected annular friction losses while circulating: 824 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 8.6 ppg equates to 2889 psi hydrostatic bottom hole pressure at 6460' TVD d • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3713 psi or 11.1 ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that no additional surface pressure shall have to be applied because the mud weight should slightly overbalance reservoir pressure. Page 3 of 3 March 26, 2007, FINAL sssv (1871-1872, OD:3.500) Gas Lift MandreWatve 1 (2719-2720, OD:5.313) Gas Lift MandreWaNe 2(5399-5400, OD:5.373) Gas Lift IandreVDummy Valve 3 (ssaa-seas, OD:5.313) Gas Lift IandreVDummy Valve 4 (7852-7853, OD:5.313) ~ Gas L'rft IandreVDummy Valve 5 (8348-8349, OD:5.313) Gas Lift IandreVDummy Valve 6 (888i-8882, OD:5.313) SBR (8947-8948, OD:3.500) PKR (8974-8975, OD:8.156) TUBING (0.9013, OD:3.500, ID:2.992) NIP (9012-9013, OD:3.500) Perf (9101-9221) • • KRU 1C-03 1 C-03 API: 500292053500 Well T e: PROD An le TS: 49 de 9101 SSSV Type: LOCKED OUT Orig Com letion: 12/31/1980 Angle @ TD: 48 deg @ 9700 Annular Fluid: Last W/O: Rev Reason: TAG Reference Lo Ref Log Date: Last Update: 10/28/2006 Last Ta : 9384' RKB TD: 9700 ftK6 Last Tag Date: 10/19/2006 Max Hole An le: 56 deg @ 8400 Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 6.50 H-40 SURFACE 10.750 0 3214 2682 45.50 K-55 PRODUCTION 7.000 0 9675 6804 26.00 K-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 9013 6365 9.20 K-55 BTC Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 9101 - 9221 6421 - 6500 -4,G3,C- O en 120 8 2/31/198 Gas 'Lift Mandrels/Valves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2719 2374 Camco KBUG GLV 1.0 BK 0.156 1211 /14/200 2 5399 3978 Camco KBUG OV 1.0 BK 0.250 0 /13/200 3 6944 4968 Camco KBUG DMY 1.0 BK 0.000 0 /13/200 4 7852 5629 Camco KBUG DMY 1.0 BK 0.000 0 2/31/198 5 8348 5959 Camco KBUG DMY 1.0 BK 0.000 0 2/31/198 6 8881 6280 Camco KBUG DMY 1.0 BK 0.000 0 /26/199 Other lu s, a ui ., etc. -JEWELRY De th TVD T e Descri tion ID 1871 1795 SSSV Camco'TRDP-1AE' Locked Out 2.813 8947 6322 SBR Baker EL-1 2.813 8974 6339 PKR Baker FHL 3.000 9012 6364 NIP Camco 'D' Ni le NO GO 2.750 9013 6365 SOS Baker 2.992 9013 6365 TTL 2.992 General Notes Date Note /23/199 WAIVERED WELL: IA x OA ANNULAR COMMUNICATION KRU 1 C-03 C-sand Producer Proposed CTD Completion 1 C-O3L1 (wpOS) 3'/" Camco TRDP-1AE SSSV (locked out) at 1871' MD 3'/z" 9.2# K-55 IBT Tubing 10-3/4" , 45.5# K-55 @ 3214' ~~ ~I ~I ~I ~I ~I ~~ KOP 9125' . MD, in C-sand 7" 26# K-55 @ 9675' MD ~~~ ConocoPhilli s p Alaska, Inc. 3'/2' Camco KBUG GLM's @ 2719', 5399', 6944', 7852', 8348', and 8881' MD Baker FHL Packer w/SBE @ 8974' MD 2'/s" STL liner top w/ "G" fishneck and seal bore @ 9000' MD D nipple (2.750" ID) at 9012' MD (covered by 2'/a" slotted liner) 3'/2" tubing tail @ 9013' MD Top of 2'/e' slotted liner at 9000' MD C-sand perfs 9101'-9221' •.~~..~ ~_~ ~_~ Whipstock exit planned, cement ramp contingency ii ~~ i i~ ~~ ~~ . 3" openhole • 1 C-03L1 TD @ 12,525' MD --- ~= = = ~~ -- 2'/e" slotted liner Updated 3/9/07, JGE Y#~`# ~ ~ BP Alaska ,~ ~ by "',Y~6. Baker Hughes INTEQ Planning Report ~.-' B HvE61#S L'VTEQ Cumprny: BP Amoco llatc: 3/1 412 0 0 7 Time 14:11.29 l':~gc 1 Field: Kuparuk Cn-ordinate(iVE) Reference: Vv etl: 03, True North - Sih~: KRU 1 C Pad Vertical (TVD) Reference: Datum(94') 94.0 Well: 03 Section (VS) Reference: Well (O.OON,O.OOE,230. OOAzi) Wellpath: Plan 5, 1 C-03L1 ~ Survey Calculation Method: Mi nimum Curvature Db: Orar_le i Field: Kuparuk _ _ 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: bggm2006 Site: KRU 1C Pad UNITED STATES :North Slope Site Position: Northing: 5968605 .00 ft Latitude: 70 19 29.107 N From: Map Easting: 562247 .20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 03 Slot Name: Well Position: +N/-S 51.04 ft Northing: 5968655 .42 ft Latitude: 70 19 29.609 N +E/-W -74.21 ft Easting : 562172 .58 ft ~ Longitude: 149 29 45.084 W Position Uncertainty: 0.00 ft Wellpath: Plan 5, 1C-03L1 Drilled From: 1C-0 3 Tie-on Depth: 9100.00 ft Current Datum: Datum(94') H eight 94 .00 ft ~ Above System Datum: Mean Sea Level ,~ Magnetic Data: 3/14/2007 Declination: 23.63 deg Field Strength: 57625 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 94.00 0.00 0.00 230.00 Plan: Plan #5 Date Composed: 3/14/2007 Copy Lamar's Plan 5 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1C-03L1 Polygon 94.00 -2483.20 -5369.87 5966128.05 556823.98 70 19 5.168 N 149 32 21.770 W -Polygon 1 94.00 -2483.20 -5369.87 5966128.05 556823.98 70 19 5.168 N 149 32 21.770 W -Polygon 2 94.00 -2570.96 -5641.64 5966038.05 556552.98 70 19 4.303 N 149 32 29.698 W -Polygon 3 94.00 -2411.45 -5821.34 5966196.05 556371.98 70 19 5.871 N 149 32 34.945 W -Polygon 4 94.00 -2095.82 -5772.72 5966512.05 556417.98 70 19 8.975 N 149 32 33.533 W -Polygon 5 94.00 -1849.85 -5522.65 5966760.05 556665.98 70 19 11.396 N 149 32 26.241 W -Polygon 6 94.00 -1823.36 -5099.37 5966790.05 557088.98 70 19 11.660 N 149 32 13.890 W -Polygon 7 94.00 -1412.93 -4419.88 5967206.05 557764.98 70 19 15.701 N 149 31 54.069 W -Polygon 8 94.00 -754.04 -3551.31 5967872.05 558627.98 70 19 22.185 N 149 31 28.730 W -Polygon 9 94.00 -527.02 -3309.40 5968101.05 558867.98 70 19 24.419 N 149 31 21.673 W -Polygon 10 94.00 -741.99 -3075.15 5967888.05 559103.98 70 19 22.306 N 149 31 14.834 W -Polygon 11 94.00 -1413.23 -3780.80 5967211.05 558403.98 70 19 15.701 N 149 31 35.418 W -Polygon 12 94.00 -1904.65 -4461.96 5966714.05 557726.98 70 19 10.864 N 149 31 55.288 W -Polygon 13 94.00 -2213.37 -5345.64 5966398.05 556845.98 70 19 7.822 N 149 32 21.068 W -Polygon 14 94.00 -2483.20 -5369.87 5966128.05 556823.98 70 19 5.168 N 149 32 21.770 W 1C-03L1 Fault 1 94.00 -1719.25 -5352.54 5966892.05 556834.98 70 19 12.682 N 149 32 21.280 W -Polygon 1 94.00 -1719.25 -5352.54 5966892.05 556834.98 70 19 12.682 N 149 32 21.280 W -Polygon 2 94.00 -1944.85 -5162.38 5966668.05 557026.98 70 19 10.464 N 149 32 15.726 W -Polygon 3 94.00 -2191.47 -4971.40 5966423.05 557219.98 70 19 8.040 N 149 32 10.148 W -Polygon 4 94.00 -1944.85 -5162.38 5966668.05 557026.98 70 19 10.464 N 149 32 15.726 W 1C-03L1 Target6 6433.00 -1249.53 -3985.46 5967373.04 558197.99 70 19 17.310 N 149 31 41.394 W 1C-03L1 Target 3 6453.00 -1943.88 -5159.37 5966669.05 557029.98 70 19 10.474 N 149 32 15.638 W 1C-03L1 Targets 6456.00 -1653.21 -4511.88 5966965.04 557674.98 70 19 13.337 N 149 31 56.749 W }°~ t ~ BP Alaska ti ~ ~r~ `~t'°a ~--// Baker Hughes INTEQ Planning Report ®ri~ BAKER FWGNES 1NTEQ Cumpan~: BP Amoco safe: 3/14/2007 Time: 14:1129 F age: 2 Meld: Kuparuk Co-or dinate(VE) Reference : W ell: 03, Tr~ie North Site: KRU 1C Pad Vertical (TVD) Reference: Datum~94') 94.0 Well: 03 Section (VS) Reference: W ell (O.OON.O.OOE,230. OOAzi) Wellpath: Plan 5, 1C-03L1 Surrey Calculation Method : M inimum Curvature Db: Oracle Tar~~cts Map Map <-~ Latitude ----- ~- Longitude -> Name Description 1'VD +N/-S +EI-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1C-03L1 Target2 6460.00 -2150.54 -5565.14 5966459.05 556625.98 70 19 8.439 N 149 32 27.475 W 1C-03L1 Target 7 6464.00 -715.4 8 -3379.95 5967912.03 558798.99 70 19 22.565 N 149 31 23.730 W 1C-03L1 Target 1 6469.00 -2384.24 -5605.08 5966225.06 556587.98 70 19 6.140 N 149 32 28.635 W 1C-03L1 Target 4 6470.00 -1837.55 -4835.45 5966778.05 557352.98 70 19 11.522 N 149 32 6.188 W 1C-03L1 Target 8 6484.00 -604.83 -3215.01 5968024.03 558962.99 70 19 23.654 N 149 31 18.917 W Annotation MD TVD ft ft 9100.00 6420.72 TIP 9125.00 6437.00 KOP ` 9145.00 6449.83 End of 9 Deg/100' DLS 9175.00 6465.99 4 9245.88 6479.55 5 9370.88 6469.21 6 9495.88 6462.48 End of 45 Deg/100' DLS 9645.88 6460.01 8 9865.88 6456.63 9 10085.88 6453.17 10 10260.88 6461.17 11 10435.88 6470.26 12 10635.88 6464.76 13 10810.88 6456.21 14 10960.88 6449.33 15 11285.88 6436.01 16 11485.88 6432.91 17 11635.88 6436.95 18 11960.88 6451.80 19 12310.88 6464.07 20 12525.00 0.00 TD Plan Section Information MD [ncl Azim TVD ~+N!-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9100.00 49.50 250.00 6420.72 -2405.44 -5373.50 0.00 0.00 0.00 0.00 9125.00 49.25 250.00 6437.00 -2411.93 -5391.33 1.00 -1.00 0.00 180.00 9145.00 50.94 250.79 6449.83 -2417.07 -5405.79 9.00 8.47 3.96 20.00 9175.00 63.75 255.90 6465.99 -2424.22 -5429.95 45.00 42.68 17.03 20.00 9245.88 94.00 266.34 6479.55 -2434.48 -5497.82 45.00 42.68 14.73 20.00 9370.88 94.71 322.76 6469.21 -2384.82 -5606.61 45.00 0.57 45.14 87.00 9495.88 90.96 18.97 6462.48 -2266.48 -5625.54 45.00 -3.00 44.97 92.00 9645.88 90.91 36.97 6460.01 -2134.56 -5555.48 12.00 -0.03 12.00 90.00 9865.88 90.82 63.38 6456.63 -1994.92 -5388.03 12.00 -0.04 12.00 90.00 10085.88 90.95 89.78 6453.17 -1944.31 -5175.96 12.00 0.06 12.00 89.50 10260.88 83.86 69.98 6461.17 -1913.85 -5004.81 12.00 -4.06 -11.31 250.00 10435.88 90.24 49.94 6470.26 -1826.77 -4854.41 12.00 3.65 -11.45 287.00 10635.88 92.86 73.81 6464.76 -1733.18 -4679.40 12.00 1.31 11.93 83.50 10810.88 92.67 52.78 6456.21 -1655.07 -4524.13 12.00 -0.11 -12.01 270.00 10960.88 92.54 34.76 6449.33 -1547.32 -4420.89 12.00 -0.09 -12.01 270.00 11285.88 91.97 73.79 6436.01 -1361.39 -4162.32 12.00 -0.17 12.01 90.00 11485.88 89.77 49.89 6432.91 -1267.69 -3987.30 12.00 -1.10 -11.95 265.00 11635.88 87.17 32.07 6436.95 -1154.96 -3889.36 12.00 -1.74 -11.88 261.50 11960.88 87.80 71.10 6451.80 -957.15 -3639.85 12.00 0.19 12.01 90.00 12310.88 88.36 29.08 6464.07 -737.73 -3377.52 12.00 0.16 -12.01 270.00 12525.00 81.23 53.89 6483.78 -579.18 -3237.67 12.00 -3.33 11.58 107.00 e°°~~ : ~ BP Alaska ~ Bs '~~ .,. by Hu6~s s"fit~'~ Baker Hughes INTEQ Planning Report INTEQ Cumpan}: BP Amoco Date: 3114!2007 Time: 14 :11. 29 P:i~;c: 3 }irld: Kuparuk Co-ord inate(IV1~) Keferenc e: Well: 03. True North tiitc KR U 1C Pad Vertical (TVD) Re ference: D atu m(94 ') 94.0 ~tcll: 03 Section (VS) Keference: Well ( O.OON,O.OO E230 .OOAzi) Wcllpath: Pla n 5, 1C-03L1 Survey Calculatio n Method: M inim um Curvat ure Db: Orade Sure ev MD Jncl Azim SS"fVD N!S E/W Map:V ~ Ttaph: DL S VS TFO 1'uol ft deg deg ft rt ft ft ft deg/100ft ft deg 9100 .00 49. 50 250. 00 6326. 72 -2405. 44 -5373. 50 5966205 .78 556819. 70 0 .00 5662. 53 0 .00 MWD 9118 .87 49. 31 250. 00 6339. 00 -2410. 34 -5386. 97 5966200 .77 556806. 28 1 .00 5675. 99 180. 00 1C-03L 9125 .00 49. 25 250. 00 6343. 00 -2411. 93 -5391. 33 5966199 .14 556801. 93 1 .00 5680. 36 180 .00 MWD 9145 .00 50. 94 250. 79 6355. 83 -2417 .07 -5405. 79 5966193 .88 556787. 52 9 .00 5694. 74 20. 00 MWD 9150 .00 53. 06 251. 76 6358. 91 -2418. 34 -5409 .52 5966192 .58 556783. 80 45 .00 5698. 41 20 .00 MWD 9150 .15 53. 06 251. 76 6359. 00 -2418 .38 -5409 .64 5966192 .54 556783. 68 0 .00 5698. 52 0 .00 1C-03L 9155 .28 55. 31 252. 72 6362. 00 -2419 .65 -5413 .60 5966191 .24 556779. 73 46 .34 5702. 38 19 .41 1C-03L 9162 .60 58. 43 253. 96 6366. 00 -2421 .40 -5419 .47 5966189 .44 556773. 87 45 .00 5708. 00 18 .85 1C-03L 9170 .64 61. 88 255. 24 6370. 00 -2423 .25 -5426 .19 5966187 .53 556767. 17 45 .00 5714. 34 18 .16 1C-03L 9175 .00 63. 75 255. 90 6371. 99 -2424 .22 -5429 .95 5966186 .53 556763. 42 45 .00 5717. 84 17 .53 MWD 9182 .19 66. 79 257. 10 6375. 00 -2425 .74 -5436 .30 5966184 .96 556757 .08 45 .00 5723. 68 20 .00 1C-03L 9184 .79 67. 90 257. 53 6376. 00 -2426 .27 -5438 .64 5966184 .41 556754 .75 45 .00 5725. 81 19 .50 1C-03L 9200 .00 74. 37 259. 87 6380. 92 -2429 .08 -5452 .74 5966181 .48 556740 .67 45 .00 5738. 43 19 .33 MWD 9225 .00 85. 06 263. 45 6385. 37 -2432 .63 -5477 .04 5966177 .73 556716 .40 45 .00 5759. 32 18 .57 MWD 9245 .88 94. 00 266. 34 6385. 55 -2434 .48 -5497 .82 5966175 .71 556695 .65 45 .00 5776. 43 17 .93 MWD 9250 .00 94. 09 268. 19 6385. 26 -2434 .68 -5501 .92 5966175 .47 556691. 54 45 .00 5779. 70 87 .00 MWD 9275 .00 94. 58 279. 47 6383. 36 -2433 .02 -5526 .75 5966176 .93 556666. 70 45 .00 5797. 65 87 .13 MWD 9300 .00 94. 88 290. 75 6381. 29 -2426 .54 -5550 .77 5966183 .21 556642. 64 45 .00 5811. 88 87 .99 MWD 9325 .00 95. 00 302. 04 6379. 13 -2415 .48 -5573 .04 5966194 .08 556620. 27 45 .00 5821. 84 88 .92 MWD 9350 .00 94. 92 313. 33 6376. 96 -2400 .28 -5592 .72 5966209 .12 556600 .47 45 .00 5827. 14 89 .89 MWD 9370 .88 94. 71 322. 76 6375. 21 -2384 .82 -5606 .61 5966224 .46 556586 .45 45 .00 5827. 85 90 .87 MWD 9375 .00 94. 65 324. 62 6374. 87 -2381 .51 -5609 .04 5966227 .75 556583 .99 45 .00 5827. 58 92 .00 MWD 9400 .00 94. 14 335. 89 6372. 95 -2359 .91 -5621 .39 5966249 .25 556571 .47 45 .00 5823. 15 92 .15 MWD 9425 .00 93. 47 347. 15 6371. 29 -2336 .29 -5629 .28 5966272 .80 556563 .38 45 .00 5814. 02 93 .02 MWD 9450 .00 92. 67 358. 38 6369. 94 -2311 .56 -5632 .42 5966297 .50 556560 .04 45 .00 5800. 53 93 .77 MWD 9475 .00 91. 77 9. 61 6368. 97 -2286 .68 -5630 .68 5966322 .39 556561 .57 45 .00 5783. 20 94 .37 MWD 9495 .88 90. 96 18. 97 6368. 48 -2266 .48 -5625 .54 5966342 .63 556566 .55 45 .00 5766. 27 94 .81 MWD 9500 .00 90. 96 19. 47 6368. 41 -2262 .59 -5624 .18 5966346 .54 556567 .88 12 .00 5762. 73 90 .00 MWD 9525 .00 90. 96 22. 47 6367. 99 -2239 .25 -5615 .24 5966369 .95 556576. 62 12 .00 5740. 88 90 .01 MWD 9550 .00 90. 95 25. 47 6367. 57 -2216 .41 -5605 .08 5966392 .87 556586. 59 12 .00 5718. 42 90 .06 MWD 9575 .00 90. 95 28. 47 6367. 16 -2194 .13 -5593 .75 5966415 .23 556597 :73 12 .00 5695. 42 90 .11 MWD 9600 .00 90. 94 31. 47 6366. 75 -2172 .48 -5581 .27 5966436 .99 556610 .04 12 .00 5671. 94 90 .16 MWD 9625 .00 90. 92 34. 47 6366. 34 -2151 .51 -5567 .67 5966458 .07 556623 .46 12 .00 5648. 04 90 .21 MWD 9645 .88 90. 91 36. 97 6366. 01 -2134 .56 -5555 .48 5966475 .11 556635 .51 12 .00 5627. 81 90 .26 MWD 9650 .00 90. 91 37. 47 6365. 94 -2131 .28 -5552 .99 5966478 .41 556637 .97 12 .00 5623. 79 90 .00 MWD 9675 .00 90. 91 40. 47 6365. 55 -2111 .85 -5537 .27 5966497 .97 556653 .53 12 .00 5599. 26 90 .01 MWD 9700 .00 90. 91 43. 47 6365. 15 -2093 .26 -5520 .55 5966516 .69 556670 .08 12 .00 5574. 51 90 .06 MWD 9725 .00 90. 90 46. 47 6364. 76 -2075 .58 -5502 .89 5966534 .52 556687 .60 12 .00 5549. 62 90 .10 MWD 9750 .00 90. 89 49. 47 6364. 37 -2058 .85 -5484 .33 5966551 .41 556706 .02 12 .00 5524. 64 90 .15 MWD 9775 .00 90. 88 52. 47 6363. 98 -2043 .11 -5464 .91 5966567 .31 556725 .31 12 .00 5499. 65 90 .20 MWD 9800 .00 90. 86 55. 47 6363. 60 -2028 .40 -5444 .70 5966582 .17 556745 .39 12 .00 5474. 71 90 .24 MWD 9825 .00 90. 85 58. 47 6363. 23 -2014 .78 -5423 .74 5966595 .97 556766 .23 12 .00 5449. 90 90 .29 MWD 9850 .00 90. 83 61. 47 6362. 86 -2002 .27 -5402 .10 5966608 .65 556787 .77 12 .00 5425. 29 90 .33 MWD 9865 .88 90. 82 63. 38 6362. 63 -1994 .92 -5388 .03 5966616 .12 556801 .78 12 .00 5409. 78 90 .38 MWD 9875 .00 90. 83 64. 47 6362. 50 -1990 .91 -5379 .84 5966620 .20 556809 .93 12 .00 5400. 93 89 .50 MWD 9900 .00 90. 85 67. 47 6362. 13 -1980 .73 -5357 .01 5966630 .56 556832 .68 12 .00 5376. 90 89 .52 MWD 9925 .00 90. 87 70. 47 6361. 76 -1971 .77 -5333 .68 5966639 .72 556855 .93 12 .00 5353. 26 89 .56 MWD 9950 .00 90. 89 73. 47 6361. 37 -1964 .03 -5309 .91 5966647 .66 556879 .63 12 .00 5330. 08 89 .60 MWD 9975 .00 90. 91 76. 47 6360. 98 -1957 .55 -5285 .77 5966654 .34 556903 .71 12 .00 5307. 43 89 .65 MWD 10000 .00 90. 92 79. 47 6360. 58 -1952 .34 -5261 .33 5966659 .75 556928 .11 12 .00 5285. 35 89 .70 MWD 10025 .00 90. 94 82. 47 6360. 18 -1948 .42 -5236 .65 5966663 .87 556952 .76 12 .00 5263. 92 89 .75 MWD 10050 .00 90 .94 85. 47 6359. 77 -1945 .79 -5211 .79 5966666 .70 556977 .59 12 .00 5243. 19 89 .79 MWD 10075 .00 90 .95 88. 47 6359. 35 -1944 .47 -5186 .83 5966668 .23 557002 .53 12 .00 5223. 23 89 .84 MWD ~~~~~~ # BP Alaska A : by '~~~~;` Baker Hughes INTEQ Planning Report i~r~r B ~EGiEf4 . s,...~ Company: BP Amoco llate: 3/14/2007 lime 14 :11:29 Pa4c : 4 Field: Kuparu k C0-ordinate(i~~E) Reference: Well: 03, True N orth Site: KR U 1C Pad \crtica l (TVll) Re ference: Datu m(94 ') 94.0 Well: 03 Section (VS) Refer ence: Well (O.OON,O-OO E,230 .OOAzi) ~ Wellpath: Pla n 5. 1C-03 L1 Survey Calculation Metho d: M inimum Curvat ure Db: Orade ~ Sursey MD inc l ~zim SS TVD N/S E/~'V MapN MapE DL$ VS TF O '1'001 ft cieg de g ft ft ft ft ft deg/100ft ft deg 10085. 88 90 .95 89. 78 6359. 17 -1944. 31 -5175. 96 5966668. 48 557013. 41 12. 00 5214 .79 89. 89 MWD 10100. 00 90 .37 88 .19 6359. 01 -1944. 06 -5161. 84 5966668. 85 557027. 52 12. 00 5203. 81 250. 00 MWD 10125. 00 89 .35 85 .37 6359. 07 -1942. 65 -5136. 88 5966670. 46 557052. 46 12. 00 5183. 79 249. 98 MWD 10150. 00 88 .32 82 .55 6359. 58 -1940. 02 -5112. 03 5966673. 30 557077. 29 12. 00 5163. 06 249. 99 MWD 10175. 00 87 .30 79 .72 6360. 53 -1936. 17 -5087. 35 5966677. 35 557101. 94 12. 00 5141. 68 250. 05 MWD 10200. 00 86 .29 76 .90 6361. 93 -1931. 12 -5062. 91 5966682. 61 557126. 33 12. 00 5119. 71 250. 15 MWD 10225. 00 85 .28 74 .06 6363. 77 -1924. 87 -5038. 77 5966689. 06 557150. 41 12. 00 5097. 20 250. 31 MWD 10250. 00 84 .29 71 .22 6366. 04 -1917. 44 -5015. 01 5966696. 68 557174. 10 12. 00 5074 .23 250. 52 MWD 10260. 88 83 .86 69 .98 6367. 17 -1913. 85 -5004. 81 5966700. 36 557184. 28 12. 00 5064 .10 250. 78 MWD 10275. 00 84 .35 68 .35 6368 .62 -1908. 85 -4991. 68 5966705. 46 557197. 36 12. 00 5050 .83 287. 00 MWD 10300. 00 85 .25 65 .48 6370 .88 -1899. 09 -4968. 78 5966715. 41 557220. 18 12. 00 5027 .02 287. 17 MWD 10325. 00 86 .15 62 .61 6372 .76 -1888. 18 -4946. 37 5966726. 51 557242. 50 12. 00 5002 .83 287. 43 MWD 10350. 00 87 .06 59 .75 6374 .24 -1876. 15 -4924. 50 5966738. 72 557264. 26 12. 00 4978 .35 287. 64 MWD 10375. 00 87 .99 56 .89 6375. 32 -1863. 03 -4903. 25 5966752. 01 557285. 40 12. 00 4953 .64 287. 81 MWD 10400. 00 88 .91 54 .03 6376. 00 -1848. 86 -4882. 67 5966766. 35 557305. 86 12. 00 4928. 77 287. 94 MWD 10425. 00 89 .84 51 .18 6376. 27 -1833. 68 -4862. 81 5966781. 69 557325. 59 12. 00 4903. 80 288. 01 MWD 10435. 88 90 .24 49 .94 6376. 26 -1826. 77 -4854. 41 5966788. 67 557333. 93 12. 00 4892. 92 288. 04 MWD 10450. 00 90 .44 51 .62 6376. 18 -1817. 84 -4843. 47 5966797. 69 557344. 80 12. 00 4878 .80 83. 50 MWD 10475. 00 90 .77 54 .60 6375. 91 -1802. 84 -4823. 48 5966812. 85 557364. 66 12. 00 4853 .84 83. 51 MWD 10500. 00 91 .11 57 .58 6375. 50 -1788. 90 -4802. 73 5966826. 97 557385. 29 12. 00 4828 .99 83. 54 MWD 10525. 00 91 .44 60 .57 6374 .94 -1776. 05 -4781. 30 5966839. 99 557406. 62 12. 00 4804 .31 83. 59 MWD 10550. 00 91 .77 63 .55 6374 .24 -1764. 35 -4759. 22 5966851. 88 557428. 59 12. 00 4779 .88 83. 66 MWD 10575. 00 92 .10 66 .53 6373 .40 -1753. 80 -4736. 57 5966862. 60 557451. 15 12. 00 4755 .75 83. 74 MWD 10600. 00 92 .42 69 .52 6372 .41 -1744. 46 -4713. 41 5966872. 14 557474. 24 12. 00 4732 .00 83. 84 MWD 10625. 00 92 .73 72 .51 6371 .29 -1736. 33 -4689. 80 5966880. 46 557497. 78 12. 00 4708 .69 83. 96 MWD 10635. 88 92 .86 73 .81 6370 .76 -1733. 18 -4679. 40 5966883. 69 557508. 15 12. 00 4698 .70 84. 09 MWD 10650. 00 92 .86 72 .11 6370 .05 -1729. 05 -4665. 91 5966887. 94 557521. 60 12. 00 4685 .71 270. 00 MWD 10675. 00 92 .85 69 .11 6368. 81 -1720. 76 -4642. 36 5966896. 42 557545. 08 12. 00 4662 .34 269. 92 MWD 10700. 00 92 .84 66 .10 6367. 57 -1711. 25 -4619. 28 5966906. 12 557568. 08 12. 00 4638 .54 269. 77 MWD 10725. 00 92 .81 63 .10 6366. 33 -1700. 54 -4596. 73 5966917. 02 557590. 54 12. 00 4614 .38 269. 62 MWD 10750. 00 92 .78 60 .10 6365. 11 -1688. 66 -4574. 76 5966929. 08 557612. 40 12. 00 4589 .93 269.47 MWD 10775. 00 92 .74 57 .09 6363 .91 -1675. 65 -4553. 45 5966942. 26 557633. 60 12. 00 4565 .24 269. 32 MWD 10800. 00 92 .70 54 .09 6362 .72 -1661. 54 -4532. 85 5966956. 54 557654. 08 12. 00 4540 .39 269. 18 MWD 10810. 88 92 .67 52 .78 6362 .21 -1655. 07 -4524. 13 5966963. 08 557662. 75 12. 00 4529 .54 269. 03 MWD 10825. 00 92 .67 51 .09 6361 .55 -1646. 37 -4513. 02 5966971. 87 557673. 78 12. 00 4515 .44 270. 00 MWD 10850. 00 92 .66 48 .08 6360 .39 -1630. 18 -4494. 01 5966988. 22 557692. 66 12. 00 4490 .47 269. 92 MWD 10875. 00 92 .65 45 .08 6359 .23 -1613. 02 -4475. 87 5967005. 53 557710. 65 12. 00 4465 .55 269. 78 MWD 10900. 00 92 .63 42 .08 6358 .08 -1594. 93 -4458. 66 5967023. 76 557727. 71 12. 00 4440 .73 269. 64 MWD 10925. 00 92 .60 39 .07 6356 .94 -1575. 97 -4442. 42 5967042. 86 557743. 80 12. 00 4416 .10 269. 50 MWD 10950. 00 92 .56 36 .07 6355 .82 -1556. 17 -4427. 19 5967062. 77 557758. 86 12. 00 4391 .71 269. 37 MWD 1Q960. 88 92 .54 34 .76 6355. 33 -1547. 32 -4420. 89 5967071. 68 557765. 08 12. 00 4381 .20 269. 23 MWD 10975. 00 92 .54 36 .46 6354 .71 -1535. 85 -4412. 68 5967083. 22 557773. 20 12. 00 4367 .53 90. 00 MWD 11000. 00 92 .53 39 .46 6353 .60 -1516. 16 -4397. 32 5967103. 03 557788. 40 12. 00 4343 .11 90. 08 MWD 11025. 00 92 .52 42 .47 6352 .50 -1497. 30 -4380. 94 5967122. 02 557804. 61 12. 00 4318 .44 90. 21 MWD 11050. 00 92 .50 45 .47 6351 .40 -1479. 33 -4363. 61 5967140. 13 557821. 80 12. 00 4293 .61 90. 34 MWD 11075. 00 92 .47 48 .47 6350 .32 -1462. 29 -4345. 35 5967157. 33 557839. 91 12. 00 4268 .67 90. 47 MWD 11100. 00 92 .43 51 .47 6349 .25 -1446. 22 -4326. 23 5967173. 54 557858. 90 12. 00 4243 .70 90. 60 MWD 11125. 00 92 .39 54 .48 6348 .20 -1431. 18 -4306. 29 5967188. 75 557878. 71 12. 00 4218 .76 90. 73 MWD 11150. 00 92 .34 57 .48 6347 .16 -1417. 21 -4285. 59 5967202. 89 557899. 29 12. 00 4193 .92 90. 86 MWD 11175. 00 92 .29 60 .48 6346 .15 -1404. 34 -4264. 18 5967215. 94 557920. 59 12. 00 4169 .24 90. 98 MWD 11200. 00 92 .23 63 .48 6345 .17 -1392. 61 -4242. 13 5967227. 85 557942. 54 12. 00 4144 .81 91. 10 MWD 11225. 00 92 .16 66 .48 6344 .21 -1382. 04 -4219. 50 5967238. 60 557965. 08 12. 00 4120 .68 91. 22 MWD 2~~>,,~ • BP Alaska • ~ ~~ ,.,it~b., Baker Hughes INTEQ Planning Report ~~~ BAKER I~EIIGI~ES -~-.~ Cumpan}: Field: Site: Well: Wellpath: BP Amoco Kupaitik KRU 1 C Pad b3 Plan S, 1 G03L1 L)atc: 3/14/2007 I~imc: 14:1129 Pa~c Co-tirdinate(IVE) Reference: Well: 03, True Norlti Vertical (TVD) Reference Datum(94') 94.0 Section (~'S) Reference: Well (O.OON,O.OOt=,230 OOAzi} Sune~ Calculation Method: Minimum Curvature Db: : 5 racle ~ Survey ~ - - Ml) loc i Aunt SSTVD 1\/S P:!W 41apV MapE ULS VS fF0 Tool j ft deg deg ft ft ft ft ft deg il~JO ft ft deg 11250. 00 92. 09 69. 49 6343. 28 -1372. 68 -4196. 34 5967248. 16 557988.16 12. 00 4096. 92 91. 34 MWD 11275. 00 92 .01 72. 49 6342. 39 -1364. 54 -4172. 72 5967256. 49 558011.71 12. 00 4073. 60 91. 45 MWD 11285. 88 91. 97 73. 79 6342. 01 -1361. 39 -4162. 32 5967259. 73 558022.08 12. 00 4063. 60 91. 55 MWD 11300. 00 91 .83 72. 10 6341. 54 -1357. 25 -4148. 82 5967263. 98 558035.54 12. 00 4050. 60 265. 00 MWD 11325. 00 91 .56 69 .11 6340. 80 -1348. 95 -4125. 25 5967272. 47 558059.04 12. 00 4027. 22 264. 94 MWD 11350. 00 91 .29 66 .12 6340. 18 -1339. 44 -4102. 15 5967282. 17 558082.06 12. 00 4003. 40 264. 86 MWD 11375. 00 91 .01 63 .14 6339. 68 -1328. 73 -4079. 57 5967293. 07 558104.55 12. 00 3979. 22 264. 78 MWD 11400. 00 90 .74 60 .15 6339 .30 -1316. 86 -4057. 57 5967305. 12 558126.45 12. 00 3954 .74 264. 72 MWD 11425. 00 90 .46 57 .16 6339 .04 -1303. 85 -4036. 22 5967318. 30 558147.68 12. 00 3930 .03 264. 68 MWD 11450. 00 90 .18 54 .18 6338 .90 -1289. 76 -4015. 58 5967332. 56 558168.21 12. 00 3905 .15 264. 64 MWD 11475. 00 89 .90 51 .19 6338 .88 -1274. 60 -3995. 70 5967347. 88 558187.96 12. 00 3880 .18 264. 63 MWD 11485. 88 89 .77 49 .89 6338 .91 -1267. 69 -3987. 30 5967354. 86 558196.30 12. 00 3869 .31 264. 63 MWD 11500. 00 89 .52 48 .21 6339 .00 -1258. 43 -3976. 64 5967364. 21 558206.88 12. 00 3855 .19 261. 50 MWD 11525. 00 89 .08 45. 25 6339. 30 -1241. 30 -3958. 44 5967381. 49 558224.94 12. 00 3830 .23 261. 51 MWD 11550. 00 88 .64 42. 28 6339. 80 -1223. 25 -3941. 15 5967399. 68 558242.07 12. 00 3805. 39 261. 55 MWD 11575. 00 88 .21 39 .31 6340. 49 -1204. 33 -3924. 83 5967418. 73 558258.24 12. 00 3780 .72 261. 61 MWD 11600. 00 87 .77 36 .34 6341. 36 -1184. 60 -3909. 51 5967438. 59 558273.39 12. 00 3756. 30 261. 69 MWD 11625. 00 87 .35 33 .36 6342. 43 -1164. 10 -3895. 24 5967459. 20 558287.49 12. 00 3732 .20 261. 79 MWD 11635. 88 87 .17 32 .07 6342. 95 -1154. 96 -3889. 36 5967468. 39 558293.29 12. 00 3721 .82 261. 92 MWD 11650. 00 87 .17 33 .77 6343. 65 -1143. 12 -3881. 70 5967480. 29 558300.86 12. 00 3708 .34 90. 00 MWD 11675. 00 87 .18 36 .77 6344 .88 -1122. 74 -3867. 28 5967500. 79 558315.10 12. 00 3684 .19 89. 92 MWD 11700. 00 87 .19 39 .77 6346 .11 -1103. 14 -3851. 82 5967520. 51 558330.40 12. 00 3659 .75 89. 77 MWD 11725. 00 87 .22 42 .78 6347 .33 -1084. 37 -3835. 35 5967539. 41 558346.71 12. 00 3635 .07 89. 62 MWD 11750. 00 87 .25 45 .78 6348 .54 -1066. 50 -3817. 92 5967557. 43 558364.00 12. 00 3610 .23 89. 47 MWD 11775. 00 87 .29 48 .78 6349 .73 -1049. 56 -3799. 57 5967574. 52 558382.20 12. 00 3585 .28 89. 33 MWD 11800. 00 87 .33 51 .79 6350 .90 -1033. 61 -3780. 36 5967590. 63 558401.27 12. 00 3560 .32 89. 19 MWD 11825. 00 87 .39 54 .79 6352 .05 -1018. 68 -3760. 35 5967605. 72 558421.16 12. 00 3535 .39 89. 04 MWD 11850. 00 87 .45 57 .79 6353 .18 -1004. 82 -3739. 57 5967619. 75 558441.82 12. 00 3510 .56 88. 91 MWD 11875. 00 87 .52 60 .79 6354 .28 -992. 07 -3718. 10 5967632. 68 558463.18 12. 00 3485 .92 88. 77 MWD 11900. 00 87 .59 63 .80 6355. 35 -980. 46 -3695. 99 5967644. 47 558485.19 12. 00 3461 .52 88. 64 MWD 11925. 00 87 .67 66 .80 6356 .38 -970. 02 -3673. 30 5967655. 10 558507.79 12. 00 3437 .43 88. 51 MWD 11950. 00 87 .76 69 .80 6357 .38 -960. 78 -3650. 09 5967664. 52 558530.92 12. 00 3413 .71 88. 39 MWD 11960. 88 87 .80 71 .10 6357 .80 -957. 15 -3639. 85 5967668. 24 558541.13 12. 00 3403 .53 88. 27 MWD 11975. 00 87 .80 69 .41 6358 .34 -952. 38 -3626. 57 5967673. 12 558554.37 12. 00 3390 .29 270. 00 MWD 12000. 00 87 .81 66 .41 6359 .30 -942. 98 -3603. 42 5967682. 71 558577.44 12. 00 3366 .52 270. 07 MWD 12025. 00 87 .82 63 .40 6360 .26 -932. 39 -3580. 80 5967693. 49 558599.97 12. 00 3342 .38 270. 18 MWD 12050. 00 87 .84 60 .40 6361 .20 -920. 63 -3558. 77 5967705. 43 558621.90 12. 00 3317 .94 270. 29 MWD 12075. 00 87 .86 57 .40 6362 .14 -907. 72 -3537. 38 5967718. 51 558643.18 12. 00 3293 .26 270. 41 MWD 12100. 00 87 .89 54 .40 6363 .07 -893. 72 -3516. 69 5967732. 68 558663.75 12. 00 3268 .41 270. 52 MWD 12125. 00 87 .93 51 .40 6363 .98 -878. 65 -3496. 77 5967747. 91 558683.54 12. 00 3243 .47 270. 63 MWD 12150. 00 87 .97 48 .40 6364 .88 -862. 56 -3477. 66 5967764. 16 558702.52 12. 00 3218 .48 270. 74 MWD 12175. 00 88 .02 45 .39 6365 .75 -845. 49 -3459. 42 5967781. 38 558720.61 12. 00 3193 .54 270. 85 MWD 12200. 00 88 .07 42 .39 6366 .61 -827. 48 -3442. 10 5967799. 53 558737.78 12. 00 3168 .70 270. 95 MWD 12225. 00 88 .13 39 .39 6367 .44 -808. 60 -3425. 75 5967818. 55 558753.98 12. 00 3144 .03 271. 06 MWD 12250. 00 88 .19 36 .39 6368 .24 -788. 88 -3410. 40 5967838. 39 558769.16 12. 00 3119 .60 271. 16 MWD 12275. 00 88 .26 33 .39 6369 .01 -768. 39 -3396. 11 5967859. 00 558783.28 12. 00 3095 .48 271. 25 MWD 12300. 00 88 .33 30 .39 6369 .76 -747. 17 -3382. 91 5967880. 32 558796.30 12. 00 3071 .73 271. 35 MWD 12310. 88 88 .36 29 .08 6370 .07 -737. 73 -3377. 52 5967889. 81 558801.61 12. 00 3061 .53 271. 44 MWD 12325. 00 87 .87 30 .71 6370 .54 -725. 49 -3370. 48 5967902. 10 558808.54 12. 00 3048 .28 107. 00 MWD 12350. 00 87 .00 33 .58 6371 .66 -704. 35 -3357. 20 5967923. 35 558821.65 12. 00 3024 .51 106. 95 MWD 12375. 00 86 .13 36 .46 6373 .15 -683. 91 -3342. 88 5967943. 90 558835.80 12. 00 3000 .41 106. 82 MWD 12400. 00 85 .28 39 .34 6375 .03 -664. 24 -3327. 57 5967963. 70 558850.95 12. 00 2976 .03 106. 65 MWD 12425. 00 84 .44 42 .23 6377 .27 -645. 39 -3311. 31 5967982. 68 558867.05 12. 00 2951 .46 106. 43 MWD ~.~~y~r , BP Alaska ~ s~R '~~ ~~' ~~ Baker Hughes INTEQ Planning Report li~TEQ ~~~ Cumpanr: BP Amoco U:~tc: 3/1~i200? Timc 14.1129 Page: 6 Field: Kuparuk Co-ordinate(NE)Reference: ~b'eH: 03, True North Site KRU 1 C Pad Vertical (TVD) Reference: Datum(94') 94.0 wdl: 03 Section (VS)Reference: Well (O.OON,O.OOE230.OOAzi) ~tellpath: Plan 5. 1 C-03L1 Survey Calculation Merhodt Minimum Curvature Db: Oracle Survcv Mll incl Azim SS TVD N/S P:IW MapN MapE DLS VS 1~F0 Tool ft deg deg ft ft ft ft - ft deg/100ft ft deg 12450.00 83.61 45.13 6379.87 - -627.41 - - - -3294.14 5968000.80 558884.07 12.00 2926.75 106.17 MWD 12475.00 82.80 48.04 6382.83 -610.35 -3276.11 5968018.00 558901.96 12.00 2901.97 105.87 MWD 12500.00 82.00 50.96 6386.14 -594.26 -3257.27 5968034.25 558920.66 12.00 2877.19 105.52 MWD 12525.00 81.23 53.89 6389.78 -579.18 -3237.67 5968049.49 558940.13 12.00 2852.49 105.14 2 3/8" • • F _- ~ ~fi1 F Ea i~j `~ i ~j ~ 1 ` ~ j.. {. Ig Y a .a ~ '4~~li~t}Ii~li;l~itl i Ill, ii ~~1f4 ittl; G~~a i l' ~~ ; g Ijl I~~~il+i ~. t: ~ ~.: ~~ ~{ ~~ ~ ~~ Q !ti. ~ ~~F~~Fd~k~ s sa~'sa9as '~ Aw~~'7~a~i$ ...r :c:::::: ~:::::: aaaa sazaa a RBi~~AS$ ~ , iii j[~ i ~~3 3988888888 ' ~~~aaa~ Y ~y//~ ~ g~wa, ~ i _; ei;;:. is sii : : :: i 11[1111: ;Li 2 [S [[ y~S ii3g~jig~ii - ~ 3 , ;; ., i~ S}}~ ~~ $: ~ w ~p -os p i f t ~ 29~5~ ~ ;i i :: e d _ . ..:. i....::::.:-...11; ::::a::::::::::::a: : i 8 ~ f :.r.. :::::::::::::::::: 2:8111?iEiiEiiii=. F;p e:3.g..g3gg..a:ea:anaae ~ f ~i ... ::::::::::: ~~3 3 #il~i~"~ii~~~~~~ :: s .. .s i f i~~¢ao~~z28i52aa~26ai ~,: ~: ~~ ~s ;; e l';. ~ ',sayg r i f ~~ I ; } '~ ~a t 8 l.: ~ ~~. t' ~ l:i ~ L. ,8 i~ 1, ~~ ~; ' ~ Iai. I~ fi' s ii ~~ }i , ~ Ii • • a a :t a a U ~ G S Ip P ~~ ~ ~ §'° b ~ ~€ .~ S~ ~/ ~I ~ 333333§~~~~~ss~~ °~'3~~5~~~~~''yy99w .,e ~o e~3888889 ~' ^-$PoBFFFFpiJ fJlBpBry£dj ~.~ ~ ~ ~~~ E 7 g g w 9 S ~ i-ii:; -=iiiii :;;{ € i 3--::- f :ii-•i: •: iisiix:i~.~rarii.:iix i{ii iii{;i{i{{xiiii.ii i 2 , , _ Q Z iB a B~ i n:iiiiiiiiii;ji{:iii { iii4' ..x:x .CC.xO 4 _....._. kk P, m = lMi W ~~ ~~ ;: g ~; ; ~ R ~ ,~ ~~~~° o rc -oi'n a; i3~liltf~lii~~~'t3~)~! i'zxxixi;;,xii;xs i i ~_ F ~'a~ e ~ o ~ ~ i=-=-==:ixx. is ! d ~~ a , qix::sii .{iii ii iix !!rx ~ ~ - j 3i~rii i ':e: - ~ ~ - # 1 i _ ; -.._ IfCIC 1 ._ -- ~ k F ~~ # - o ~ ~ jam, _ O ~ ~ ~ T ~ ` ~ ~ ~ ~ ~~ G ~ N .. f ~~ tlt ~ ~~ ~ ~ ~ I ~~_ Q ~ ~ ~ I +~ I ~ 1 4 4 {j a s ~: ,~ oa < ~ f r }{ f 0o I 1}j i ~ ~ r"i. ~ ~~.. i ~~--.. ~-~_ ~ fi + 1, ~ \$ 1,. i t~r ~#~t~ r r ~ o ~ I ~ { t- ~~ ; + I f }} xE :. o i t .. . ~~ I } 1 y 1< ~ `` I + L . ~ ~ G . i l ~ E~ l ~ll ~ l_ N Y .+^.. r o A ~W ~„ o s ~~ ffi [~~MOOZ] (+)~ii+owl-lyvios Kuparuk DOBCTD BOP configuration 2" CT Well 1 C-03L1 Rig Floor C C 3" 5000 psi I HCR M Choke Line C C Tree Size 3-1 /8", 5M Flow Tee ~ Lubricator ID = 6.375" with 6" Otis Unions 7 1/16" 5000 psi BOP's. ID = 7.06" 7 1/16" 5000 psi, RX-46 1/4 Turn LT Valve 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve SSV Master Valve Base Flan e Page 1 - - Re: 1 C-03L 1 Subject: Re: 1C-03L1 From: Thomas Maunder <tom_maunder a.admin.state.ak.us> Date: Thu, 29 Mar 200713:27:.39 -0800 To: "Eller,l Garti-" "I.Garv.F,llcr a~.conocophilliE~s.com> Thanks Gary. I understand the need for options. Tom Eller, J Gary wrote, On 3/29/2007 1:17 PM: Tom - which one would you like? I'll let you choose this time! I failed to remove that reference to a cemented banzai liner on page 2 of the text description. We originally had talked about a banzai completion, but on further discussion that was dropped. Our plan is definitely to run slotted liner, which will leave the original perfs open and capable of flow. we do have a contingency to run a cemented liner, but that is at most a 1-in-10 possibility. We would only do so if we saw very compelling evidence of significant wet thief zones that could jeopardize the well. While we very well may encounter thief zones, our expectation is that they will not be so prolific that they cause us to change our completion style. However, it is a contingency and a possibility. Does that explain things OK. Thanks much, -Gary Eller CPAI -----Original Message----- From: Thomas Maunder [t1ail.to:tozn maunder~~adm..r..state.ak..us] Sent: Thursday, March ', 29, 2007 12:46 PM ', To: Eller, J Gary Subject: 1C-03L1 Gary, I am reviewing the application. A question ... 1. The 401 sheet shows slotted liner and 5 a under rig work says while slotted is preferred, it might be necessary to fully cement the liner. At the top of page 2, a banzai type completion is described. What flavor of completion are you planning? Thanks in advance. Tom Maunder, PE AOGCC 1 of 1 3/29/2007 1:27 PM • PERMIT TO DRILL 20 AAC 25.005 (e) Each well branch requires a separate Permit to Drill. If a previously drilled well is proposed to be redrilled below the structural or conductor casing to a new bottom-hole location, the application for a Permit to Drill must be accompanied by all items required under (c) of this section. If concurrent multiple well branches are proposed from a single conductor, surface, or production casing, (2) for each other well branch, the application for a Permit to Drill need only include information-under (c) of this section that is unique to that well branch and need not be accompaniied by the 5100 fee. • • ~~~5~~~~A~ L~~-~~~ ~~~~~~~5~ vvl~LL NAME ~~- ~ ~ L ~. PT~# ~~`~ -o"`-~L-\ ®evelopment Service Exploratory Stratigraphic Test Yon-Conventional Well Circle 4ppropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER V6'HAT ~ (OPTIONS) APPLIES - j ~ ~ MULTI LATERAL 'The permit is for a new wellbore segment of existing ~ ~ well ~~~ ~ ~,- ~~ ' ~ (If last two digits in I Permit No. ~~d'~3~5 , API No. ~0-Oaf -053 ~ -C)~. , ' ,API number are between 60-69) j Production should continue to be reported as a function of the original API number stated above. PILOT HOLE [n accordance with 20 A.AC 25.005(f), .all records, data and. logs ;acquired for the pilot hole must be clearly differentiated in both i ;well name ( PH) and API number ' (SO- - -_~ from records, data and logs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.0». Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing 'i j exception. assumes the ' ~i liability of any protest to the spacing exception that may occur. DRY D[TCH ~ All dry ditch sample sets submitted to the Commission must be in SAMPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and l0' sample intervals j ,' ~ through target zones. Please note the following. special condition of this permit: jNon-Conventional i production or production testing of coal bed methane is not allowed Well ~ for (name of well) until afrer (Company Name) has designed and - ~ implemented a water well testing program to provide baseline data I i ~ on water quality and quantity. (Company Name) must contact the ~ ~ Commission to obtain advance approval of such water well testing program. ~ Rev: l 2~i06 C `jody~transmitta(_checklist ^~^ ~ L, O ~ i ~ ~ , d _ ° o ~, m o ' p: V ~ ~ ", ° a c a, ' ` c ~ O ~ ~ c. ~ o ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~' ~ ~ ~ n> c ~ o. ~ ~ ~ c. ~ ~ ~ ~ Z. m c ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ a ~ ~ a~, ~ ~ n ' ~ c ~ ~ ~ ~ t ~ `. s, -~ N a ai ~ ~ ~ 08 ~ W to ~ ~ v O. o~ ~ 3' ~ i ~ ~ ~ ~ ~ ~ a. ~ a~, ~ o; ,a_, ~ r ~ ~ ~ ~~ ~ , m O 4. v. ~ o. ~ a~ > 'v' w- ~ ~ °- , ~ ~ ~ ~ ~ p •~ a `~ ~ ~, a~, n ~ L, m ~ t, a m ~ ~ ~' E. m, , '~ ~ a i ~ ' I $ ' 3, ~: m. L o ~ ~ a oo, ~, w o s o ~ a ~ 3, 3 g, ° ~ ~ _ 3, O O• a, .-~ ~, N• ~ ~ ~ ~ ~ ~ ~ •~ ~ , a, N. 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