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Home My WebLink About206-174I a e sect ell ist® File ~er Page 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. ~~) ~ - ~ ~ ~ Well History File Identifier Or anizing (done) ^ Two-sided III IIIIII IIIII IIIII ^ Rescan Needed III II~III II II IIIIII 9 RESCAN DIGITAL DATA OVERSIZED (Scannable) for 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: <~ ~ ~ /s/ Pro "ect Proofin ! g II (II'I'I I' III I I III BY: Maria Date: ~ / ~ ~ ~s~ + =TOTAL PAGES~ Scannin Pre aration g p x 30 = _ (Count does not include cover sheet) ~~ BY: Maria ~ Date: ~ l~3 l J ~ ~ lsl Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include c ver sheet) tches Number in Scannin Preparation: (~ YES NO Page Count Ma 9 BY: Maria Date: ~ ~ ~ ~ ~ /s~ ~~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 111 BY: Maria Date: /s~ Scannin is complete at this point unless rescanning is required. II I II ~I (~ ~ (III I I III 9 ReScanned III IIIIII IIII) II III BY: Maria Date: /s~ Comments about this file: Quality Checked III II IIII III () II III 10/6/2005 Well History File Cover Page.doc • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, January 09, 2009 9:11 AM To: Allsup-Drake, Sharon K Cc: Eller, J Gary; Venhaus, Dan E; Okland, Howard D (DOA) Subject: RE: 2D-05L1 (206-174) and 2D-05L1-01 (206-175) Sharon, et al, The permits automatically expire in 2 years unless the operator requests to cancel them earlier. It appears these laterals were permitted in late 2006 so they should now be expired. The actual paperwork to revise the entries in the well lists may not have been accomplished yet. Call or message with any questions. Tom From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Friday, January 09, 2009 9:05 AM To: Maunder, Thomas E (DOA) Cc: Eller, J Gary; Venhaus, Dan E Subject: 2D-05L1 and 2D-05L1-01 Tom - What is the process to formally cancel a permit to drill? There are 2 permits we submitted in 2006 for 2D-05L1 and 2D-05L1-01. Do these just automatically get cancelled if not drilled in 2 years or is there another process to cancel them? Thank you, Sharon 263-4612 ~, ' ~'~',~°1 ! ~ %~ ,~ ~ ~ is 3/26/2009 i ! ~~ ~'' w~' ~' ~ ~ ; ~;:r'?'~y'; ,~ ~ y~,"~ „n ~ ~ .rte ~ S h .. y _ ~ ~.~ ~~ J ~: ~ 4;%~~ f(~a. ' ~ ~~ a ',r 'P' j` P+y~ °4 MICROFILMED 6/30/2010 DO NOT PLACE ANY N EW MATERIAL UNDERTHISPAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc SARAH PALIN, GOVERNOR 333 W. 7`h AVENtiE, SQITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F.1X (907)276-75423 Gary Eller CT Drilling Engineer ConocoPhillips Alaska Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 2D-05L1 ConocoPhillips Alaska Inc. Permit No: 206-174 Surface Location: 188' FSL, 550' FEL, SEC. 23, T11N, R09E, UM Bottomhole Location: 1479' FSL, 526' FWL, SEC. 13, T11N, R09E, 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 2D-05, Permit No. 184- 126, API No. 50-029-21157-00. 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 Commission to witness any required test, contact the Commission's petroleum field inspec~at (907) 659-3607 (pager). y Norman DATED this~day of December, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASk~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~ECEIVE~ l~(`~ DEC 1 2 2006 AI__i__ /1'1 A es 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 prop$se or: ^ Coalbed Methane ~~Qates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 2D-05L1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10950 ' TVD 6011 ss~ 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 550' FEL SEC 168' FSL 23 T11 N R09E UM 7. Property Designation: ADL 025653 ~ River Pool , , . , , , Top of Productive Horizon: 3929' FSL, 1367' FWL, SEC. 24, T11N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 10, 2007 Total Depth: 1479' FSL, 526' FWL, SEC. 13, T11 N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,500' - 4b. Location of Well (State Base Plane Coordinates): Surface: x-529214 ~ y-5954367 ~ Zone-ASP4 10. KB Elevation (Height above GL): 126 feet 15. Distance to Nearest WeII Within Pool: 1,500' - 16. Deviated Wells: Kickoff Depth: 7655 ~ feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4500 ' Surface: 3892 - 18. Casin Pr ram: ` ecifi f s T ' ttin D th - Bo m nti of Ce n c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 2.7" x 3" 2-3/8" 4.6# L-80 STL 1650' 9300' 10950' 6011' Uncemented lotted Liner 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 7990 Total Depth TVD (ft): Plugs (measured): 6363 None Effective Depth MD (ft): 7802 Effective Depth TVD (ft): 6190 Junk (measured): None Casing Length Size Cement Votume M D Conductor /Structural Surface 116' 16" 224 sx Coldset II 116' 116' Intermediate 3823' 9-5/8" 1075 sx Arcticset III 685 sx Class 'G' 3823' 3159' Produc ion 7971' 7" 2 x I 'G' 200 sx A I 7971' 63 5' Liner Perforation Depth MD (ft): 7534' - 774 ' Perforation Depth TVD (ft): 5949' - 6135' 'L 20. Attachments fling 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 App oval: Commis' n Representative: Date: 22. I hereby cert., that the foregoin is true and correct. Contact Gary Eller, 529-1979 Printed Narrte ary Eller Title CT Drilling Engineer Prepared By NamelNumber: Si nature ` ` Phone 529-1979 Date i2~07 ~r7U Terrie Hubble, 584-x628 Commission Use Onl Permit To Drill Number: ?-moo'/~ A ber. 50-029-21157-60-00 Permit A proval See cover letter for Date: ~~' a other re uirements Conditions of Approval: ~ ~v,,~,~ If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ,_,/ ~~~ `Y ~ ~ ~ }L.S~ CAS ~~~~~ Samples Req'd: ^,_, /Yes t~0 No Mud Log Req'd: ^ es L7 No ~~~.)l~~Y~~~ ~ a Q«5~~3~ ~` HZS Measures: IYJ Yes ^ No al Survey Req'd: (Yes ^ No Other: ~ ~~' Z _ a APPROVED BY THE COMMISSION a e ~ ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005: ~~" ' ' s { V `-~ / Submit In Duplicate .-11~~~ n i i KRU 2D-05L1 and 2D-05L2 Sidetrack Laterals Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling unit will drill two laterals from injector KRU 2D-05 using the managed pressure ~ drilling technique. These horizontal laterals will target Kuparuk A4 sand reserves for increased pattern throughput. The 2D-OSL1 will be a 3300' lateral drilled to the northwest, and the 2D-OSL2 will be a 1550' lateral kicked off from the 2D-OSL1 and drilled to the south. Both laterals will be pre-produced for a period of months prior to conversion to injection. 2D-OS CTD Drill and Complete Program: Planned for January 2007: Pre-CTD Prep Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs - T & IC. 3. MIT-IA, MIT-OA. 4. Slickline tag fill. Obtain static BHP on A sand alone. a. If A sand static BHP exceeds 4500 psi, allow A sand to crossflow to C sand perfs. Re- ~r~ measure static BHP on A sand. ( ~`~j 5. Pressure test tubing to confirm that the C sand straddle has integrity. a. If the C sand straddle does not test, locate the leak and attempt repairs. 6. E-line shoot tubing punches in 31/z" tubing tail at 7617' MD. T. Coil tubing lay in cement plug across existing A sand perfs up across tubing tail to 7613' MD. 8. Slickline drift and tag top of cement. 9. Pressure test cement plug. CTD Rig Work 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. ~`~~ 2. Mill cement ramp, 2.74" window, and 10' of open hole from 7655' MD. ' 1~\S~ 3. Drill the 2D-ObLI trunk lateral to the northwest with a 2.70" x 3" bi-center bit from the window at 7655' MD to TD of 10,950', MD targeting the Kuparuk A4 sand. ~o~~~~~ 4. Complete the L1 lateral with 23/8" slotted liner from TD up (9300' MD. An aluminum billet will be run an (9300' for kickoff of the L2 lateral. 5. Mi11 off the aluminum billet at 9300' MD. 6. Drill the L2 lateral to the south with a 2.70" x 3" bi-center bit from 9300' to 10,.850' MD targeting Kuparuk A4 sands. 7. Complete the L2 lateral with 23/8" slotted liner. The 23/8" liner will be run to TD, and the liner top will be 10' inside the 3'/z" tubing tail at 7616' MD. 8. ND BOPS. RDMO Nordic 2. Post-CTD Rig Work 1. Run GLVs, obtain static BHP. Leave the C Sand perfs isolated for the time being. 2. Pre-produce the L1 and L2 laterals of 2D-O5. 3. Submit separate 10-403 to convert 2D-OS to injection when ready to do so: Mud Program• • Will use chloride-based Biozan brine (10.0 ppg) for milling operations,. and chloride-based Flo-Pro mud (10.0 ppg) for drilling operations. Will have to kill the well to deploy 23/8" slotted liner since the SCSSV has been locked out. Page 1 of 3 December 7, 2006, FINAL KRU 2D-O5L1 and 2D-O5L2 Sidetrack Laterals Coiled Tubing Drilling Disnosal• • 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. CaS1nE Program• • 2D-OSL1: 23/8", 4.6#, L-80, STL slotted liner from 9300' MD to 10,950' MD • 2D-OSL2: 23/8", 4.6#, L-80, STL slotted liner from 7616' MD to 10,850' MD Existing Casing/L,iner Information Surface: 95/8", J-55, 36# Burst 3520 psi; Collapse 2020 psi. Production: 7", J-55, 26# Burst 4980 psi; Collapse 4320 psi Well Control• • Two well bore volumes (190 bbl) of kill weight fluid 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 4000 psi. Maximum potential surface pressure is 3892 psi assuming a gas gradient to surface and maximum expected formation pressure (i.e. 4500 psi). • The annular preventer will be tested to 400 psi and 2500 psi. Directional• • See attached directional plans for 2D-OSL1 and 2D-OSL2. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • .The nearest well to the 2D-OSL1 lateral is 2D-06 which is 1500' away. The nearest well to the 2D-OSL2 lateral is 2D-03 which is approximately 2000' away. The KRU boundary is 23,500' away. Lo~ging- • MWD directional, resistivity, and gamma ray logs will be run over the entire open hole section in both laterals. Drilling Hazards:. • Lost circulation is a risk due to fault crossings and lack of injection support into isolated fault blocks in the A sand. Expect to encounter reduced formation pressure as the laterals are drilled away from the motherbore. • The risk of encountering excess pressure while drilling a fault crossing is considered low ~ Because 2D-OS is an injection well, the highest pressure we expect to encounter is immediately around the motherbore. Because 2D-OS has recently been on miscible gas injection, any formation influx is likely to contain hydrocarbon gas. • The highest HZS reading on the 2D pad is 85 ppm as measured in the 2D-15 we1L Well 2D-OS is an injection well so it has no associated HzS. We112D-06B is adjacent to 2D-OS and has 70 ppm HZS (10/17/06). All HZS monitoring equipment will be operational. / Page 2 of 3 December 7, 2006, FINAL KRU 2D-05L1 and 2D-05L2 Sidetrack Laterals Coiled Tubing Drilling Reservoir Pressure: • The most recent static BHP survey in we112D-OS was taken in August 2005 after the well had been shut- in for 12 days with both the A and C sands open. The measured reservoir pressure was 3812 psi at 7802' MD, 6190' TVD which corresponds to 11.8 ppg EMW. Separate A sand and G sand pressures will. be obtained prior to drilling these CTD laterals. Since 2D-OS is an injection well, expect to encounter decreasing formation pressure as the laterals are drilled away from the mother well. Maximum expected pressure is 45_00 psi in the A sand, which corresponds to an EMW of 14.2 ppg at 6078' TVD (top of AS perfs). Maximum potential surface pressure with gas (assume 0.1 psi/ft gradient) to surface is 3892 psi. Variance. request: ~ a~-a-S~~ Co ~~ • ConocoPhillips requests a variance to 20 AAC 25.036(d)(4) regarding the requirement to function pressure test ram-type BOP equipment after using such for purposes other than well control.. The variance will not apply when the use of ram-type BOP equipment may have compromised their effectiveness, such as if the-pipe rams are inadvertently closed on a tool joint during routine operations. While drilling the 2D-OS laterals it will be routine to close the 23/8" combi-rams (i.e. pipe/slip rams). These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling: Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 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 be 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. We112D-OS is not equipped with a SCSSV, 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: 3688 psi at 7650' MD (6053' TVD), or 11.7 ppg EMW. • Expected annular friction losses while circulating: 689 psi (assuming friction of 90 psi/1000. ft). • Planned mud density: 10.0 ppg equates to 3148 psi hydrostatic bottom hole pressure at 6053' TVD • While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 3837 psi or 12.2 +~ ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that an additiona1540 psi of surface pressure shall have to be applied to balance reservoir pressure. Page 3 of 3 December 7, 2006, FINAL e ConocoPhillips Alaska, Inc. • KRU 2D-05 2 D-05 API: 500292115700 Well T INJ An le TS: 28 d 7532 SSSV Type: TRDP Orig 9/20/1984 Angle @ TD: 23 deg @ 7990 sssv Com letion: (1s7o-1871, OD 3 500 Annular Fluid: Last W/O: Rev Reason: C/O CVs : . ) Reference L Ref L Date: Last U ate: 10/27/2005 Last Ta : 7802 CTMD TD: 7990 ftKB Last Ta Date: 8/7/2005 Max Hole An le: 47 d 3700 Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 116 116 62.50 H-40 SUR. CASING 9.625 0 3823 3159 36.00 J-55 PROD. CASING 7.000 0 7971 6345 26.00 J-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7626 6031 9.30 J-55 EUE 8RD Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7534 - 7578 5949 - 5988 C-4,UNIT B 44 12 9/28/1984 IPERF Dresser Atlas 7678 - 7688 6078 - 6087 A-5 10 4 9/28/1984 IPERF Dresser Atlas 7700 - 7742 6097 - 6136 A-4 42 4 9/28/1984 IPERF Dresser Atlas Gas Lift MandrelsNalves ~ ` St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2074 1907 MMH FMHO DMY 1.0 BK-2 0.000 0 9!28/1994 2 4210 3427 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1994 3 5722 4526 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1994 4 6842 5376 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1994 5 7319 5762 Otis HP Round DMY 1.5 RO 0.000 0 10/2/1989 ~i In'ection Mandrels/Valves PBR St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv (73ssa367, Mfr Run Cmnt OD:3.500) 6 7418 5847 MMH MMH FMHO HFCV 1.0 BK 0.188 0 0/22/200 O en 7 7485 5906 MMH MMH FMHO HFCV 1.0 BTM 0.188 0 0/22/200 O n 8 7587 5996 MMH MMH FMHO DMY 1.0 0.000 0 10/14/2 1 PKR 1. LATCH BROKEN OFF WHEN ATTEMPT MADE TO PULL DMY 4/7/2001 (7379-73so, 151) OD:6 Other lu s, a ui ., etc. -JEWELRY . De th TVD T e Descri lion ID 1870 1751 SSSV Baker'FVL' Locked Out 7/26/94 2.810 7366 5802 PBR Baker 10 3.000 Injection lN l M d 7379 5813 PKR Baker'FHL' h d set PERM 3.000 an re a ve s 7606 6013 PKR Baker'FB-1' 4.000 (7a1s-741 s, 7621 6027 NIP Camco'D' Ni le NO GO 2.750 7625 6030 SOS Baker 2.992 7626 6031 TTL 2.992 Injection MandrelNalve 7 (7485-7486, Injection MandreWalve 8 (7587-7588, PKR (7606-7607, OD:6.151) NIP (7621-7622, OD:3 500) . TUBING (0-7626, OD:3.500, ID:2.992) Pert (7678-7688) Perf (7700-7742) --- - - -_-- I KRU 2D-05 CTD Sidetrack A4-sand Injector Completion Total Proposed Footage = 4850' G. 3-'/2' SSSV set at 1870' (locked out) F. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing with 3-1/2" x 1" gas lift mandrels 9-5/8" shoe E. 3-'/z' x 7" packer at 7379' C-sand perfs D. 3-1/2" production mandrels ~;ci i~°wi "- - ~ ~, , ----- C. 3-'/2' x 7" packer at 7606' Possible leak in production mandrel B. 3-'/2' nipple with 2.75" ID at 7621' at 7587' RKB A. 3-1/2" tubing tail at 7626' 2-3/8" liner top @ 7616' .... ...._. Window in T' 26# J55 casing ement KOP at 7650' MD Aluminum billet at 9300' MD A5 sand perfs ~~ A4 sand perfs 2-3/8" slotted liner • / 2D-05L1 north lateral, TD @ 10950' MD ----- -_____ _---- 2D-05L2 south "curl" lateral , TD @ 10850' MD 7" shoe • • by BP Alaska s Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 11/28/2006 Time: 10:16:24 Page: i Field: Kuparuk `Co-otdheate(NE)Refermce: Well: 2D-05, True North' Site: KRU 2D Pad Vertical (TVD) Reference: 2 D-05 Orig Rig 128.0 Well: 2D-05 Section (VS) Reference: WeII (O.OON,O.OOE,350. OOAzi) Welipath: Pien 3, 2D-05L1 Survey Calculation Method: Minimum Curvature - Db: Orade Field: Kuparuk Map System:US State Plane Coordinate System 192 7 Map 7.oae: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bgg m2006 Site: KRU 2D Pad UNITED STATES :North Slope Site Position: Northing: 5954200. 61 ft Latitude: 70 17 9.387 N From: Map Easting: 529765. 39 ft Longitude: 149 45 32.755 W Position Uncertainty: 0.00 ft North Rekrence: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg WeII: 2D-05 Sbt Name: Well Position: +N/-S 168.83 ft Northing: 5954367 .24 ft ~ Latitude: 70 17 11.047 N +E/-W -550.66 ft Easting : 529214 .12 ft ~ Loegihrde: 149 45 48.798 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, 2D-05L1 Drilled From: 2D-05 Tic-oo Depth: 7600.00 ft Current Datum: 2D-05 Orig Rig Heigbt 126 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/28/2006 Declination: 23.60 deg Fiehl Strength: 57605 nT Mag Dip Aegle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 126.00 0.00 0.00 350.00 Plan: Plan #3 Date Composed: 11/28/2006 Copy Lamar's plan 3 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets -.Map Map 4-- Latitude --> <- Longitude --> Name Description TVD +N/-S +FJ-W Northing Easting Deg Rtin Sec Deg Min Sec Dip. Dir.. _ft ft ~ ft ~ 2D-0SL1 Polygon 126.00 3917.77 2164.33 5958293.00 531363.00 70 17 49.575 N 149 44 45.710 W -Polygon 1 126.00 3917.77 2164.33 5958293.00 531363.00 70 17 49.575 N 149 44 45.710 W -Polygon 2 126.00 4732.95 2397.52 5959109.00 531593.00 70 17 57.592 N 149 44 38.905 W -Polygon 3 126.00 5202.02 2136.31 5959577.00 531330.00 70 18 2.206 N 149 44 46.516 W -Polygon 4 126.00 5522.30 1814.52 5959896.00 531007.00 70 18 5.357 N 149 44 55.895 W -Polygon 5 126.00 6001.18 1601.36 5960374.00 530792.00 70 18 10.067 N 149 45 2.107 W -Polygon 6 126.00 6742.78 1210.20 5961114.00 530398.00 70 18 17.361 N 149 45 13.509 W -Polygon 7 126.00 6599.11 862.61 5960969.00 530051.00 70 18 15.948 N 149 45 23.645 W -Polygon 8 126.00 6330.53 1006.58 5960701.00 530196.00 70 18 13.307 N 149 45 19.448 W -Polygon 9 126.00 5637.31 1299.92 5960009.00 530492.00 70 18 6.489 N 149 45 10.898 W -Polygon 10 126.00 5086.63 1718.82 5959460.00 530913.00 70 18 1.072 N 149 44 58.688 W -Polygon 11 126.00 4837.46 2012.88 5959212.00 531208.00 70 17 58.621 N 149 44 50.117 W -Polygon 12 126.00 4500.41 2016.58 5958875.00 531213.00 70 17 55.306 N 149 44 50.012 W -Polygon 13 126.00 3994.78 1906.60 5958369.00 531105.00 70 17 50.333 N 149 44 53.222 W -Polygon 14 126.00 3917.77 2164.33 5958293.00 531363.00 70 17 49.575 N 149 44 45.710 W 2D-05L2 Polygon 126.00 5109.26 1812.92 5959483.00 531007.00 70 18 1.294 N 149 44 55.945 W -Polygon 1 126.00 5109.26 1812.92 5959483.00 531007.00 70 18 1.294 N 149 44 55.945 W -Polygon 2 126.00 5367.45 1771.82 5959741.00 530965.00 70 18 3.834 N 149 44 57.138 W -Polygon 3 126.00 5378.67 1457.93 5959751.00 530651.00 70 18 3.945 N 149 45 6.293 W -Polygon 4 126.00 5093.66 1194.79 5959465.00 530389.00 70 18 1.142 N 149 45 13.966 W -Polygon 5 126.00 4747.16 1057.43 5959118.00 530253.00 70 17 57.735 N 149 45 17.972 W -Polygon 6 126.00 4142.76 1144.09 5958514.00 530342.00 70 17 51.790 N 149 45 15.448 W -Polygon 7 126.00 4104.41 1489.98 5958477.00 530688.00 70 17 51.412 N 149 45 5.366 W -Polygon 8 126.00 4858.57 1469.91 5959231.00 530665.00 70 17 58.830 N 149 45 5.946 W -Polygon 9 126.00 5050.15 1583.66 5959423.00 530778.00 70 18 0.714 N 149 45 2.629 W -Polygon 10 126.00 5109.26 1812.92 5959483.00 531007.00 70 18 1.294 N 149 44 55.945 W • • by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Datc: 11/28/2006 Timc: 10:16:24 Page: 2 Field: Kuparuk Ce-erdinate(NE) Reference: Well: 2D-05, True North Site: KRU 2D Pad Vertical (TVD) Reference: 2D-05 Orig Rig 126.0 VVei4 2D-05 Section (VS) Reterrnce: Well (O.OON,O.OOE,350.OOAzi) Wclipath: Plan 3, 2D-05L1 Survey Cakaiation Method: M inimum Curvature I?b: Orade Targets Map 11Iap ~---- Latitude -> <- Longitude -> Name Description 'R'D +N/-S +E!-W Northing Easting Deg Min Sec Deg Mie Sec Dip. Dir. ft ft ft ft ft 20-05L2 Target3 6077.00 4148.99 1343.14 5958521.00 530541.00 70 17 51.851 N 149 45 9.646 W 20-05L2 Target2 6097.00 4725.55 1212.36 5959097.00 530408.00 70 17 57.522 N 149 45 13.455 W 2D-05L1 Targets 6106.00 5373.89 1659.93 5959747.00 530853.00 70 18 3.897 N 149 45 0.403 W 2D-05L1 Target4 6116.00 5156.08 1862.11 5959530.00 531056.00 70 18 1.755 N 149 44 54.511 W 2D-05L2 Targetl 6116.00 5004.20 1312.46 5959376.00 530507.00 70 18 0.262 N 149 45 10.536 W 2D-05L1 Target6 6116.00 5695.44 1526.16 5960068.00 530718.00 70 18 7.060 N 149 45 4.301 W 2D-05L1 Target3 6126.00 4926.93 2150.25 5959302.00 531345.00 70 17 59.500 N 149 44 46.112 W 2D-05L1 Targetl 6134.00 4243.80 2166.59 5958619.00 531364.00 70 17 52.782 N 149 44 45.641 W 2D-05L1 Target2 6136.00 4589.67 2208.94 5958965.00 531405.00 70 17 56.183 N 149 44 44.404 W 2D-05L1 Target? 6136.00 6055.49 1265.54 5960427.00 530456.00 70 18 10.602 N 149 45 11.898 W 2D-05L1 Target9 6137.00 6600.37 1053.63 5960971.00 530242.00 70 18 15.961 N 149 45 18.075 W 2D-05L1 Target8 6139.00 6396.80 1195.85 5960768.00 530385.00 70 18 13.958 N 149 45 13.929 W Annotation MD TVD ft, ft 7600.00 6007.74 TIP • 7655.00 6056.95 KOP 7669.00 6069.20 End of 40 Deg/100 DLS 7794.04 6129.48 End of 45 Deg/100 DLS 7969.04 6132.69 5 8169.04 6133.68 6 8344.04 6135.11 7 8494.04 6135.97 8 8894.04 6126.24 9 9169.04 6117.42 10 9269.04 6115.95 11 9419.04 6110.09 12 9544.04 6106.18 13 9644.04 6107.90 14 9894.04 6116.29 15 10019.04 6121.18 16 10369.04 6136.34 17 10494.04 6138.85 18 10719.04 6139.34 19 10950.00 6137.04 TD Plan Section Information MD Iad Azim TVD +N/-S +E/-W DL3 Brild Turu TFO Target ft deg deg ft . ft ft deg/10pft deg/i00ft'deg/100ft deg 7600.00 26.92 20.52 6007.74 3788.63 1925.90 0.00 0.00 0.00 0.00 7655.00 26.13 20.95 6056.95 3811.61 1934.59 1.48 -1.44 0.78 166.53 7669.00 31.73 20.95 6069.20 3817.93 1937.01 40.00 40.00 0.00 0.00 7794.04 88.00 20.95 6129.48 3914.91 1974.14 45.00 45.00 0.00 0.00 7969.04 89.92 41.87 6132.69 4063.41 2064.82 12.00 1.10 11.95 85.00 8169.04 89.52 17.87 6133.68 4235.57 2163.70 12.00 -0.20 -12.00 269.00 8344.04 89.55 356.87 6135.11 4408.15 2186.02 12.00 0.02 -12.00 270.00 8494.04 89.79 14.87 6135.97 4556.75 2201.29 12.00 0.16 12.00 89.30 8894.04 92.83 326.94 6126.24 4940.17 2140.02 12.00 0.76 -11.98 274.00 • • by BP Alaska $ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 11/28/2006 Time: 10:16:24 Pagr. 3 Field: Kuparuk Go-erdinate(NE) Reference: Well: 2D-05, True North Site: KRU 2D Pad Vertical (TVD) Reference: 2D-05 Orig Rig 126.0 Well: 2D-05 Section (VS) Reference: Well (O.OON,O.OOE,350.OOAzi) WeBpatb: Pl an 3, 2D-05L1 Snrvey Calculation Method: Minimum Curvature Db: Orade Plae Section Information MD Ind Azim TAD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft degl100ft deg/100ft deg 9169.04 90.74 293.99 6117.42 5116.07 1933.77 12.00 -0.76 -11.98 267.00 9269.04 90.93 305.99 6115.95 5165.96 1847.33 12.00 0.19 12.00 89.00 9419.04 93.51 323.82 6110.09 5271.33 1741.60 12.00 1.72 11.89 81.50 9544.04 90.06 338.43 6106.18 5380.43 1681.45 12.00 -2.76 11.69 103.00 9644.04 87.99 350.25 6107.90 5476.52 1654.51 12.00 -2.07 11.82 100.00 9894.04 88.26 320.24 6116.29 5700.83 1551.07 12.00 0.11 -12.01 270.00 10019.04 87.28 305.26 6121.18 5785.37 1459.61 12.00 -0.78 -11.98 266.00 10369.04. 87.98 347.29 6136.34 6069.73 1269.81 12.00 0.20 12.01 90.00 10494.04 89.73 2.19 6138.85 6193.83 1258.39 12.00 1.40 11.92 83.50 10719.04 90.03 335.19 6139.34 6412.42 1214.68 12.00 0.13 -12.00 270.60 10950.00 91.09 307.50 6137.04 6591.02 1071.82 12.00 0.46 -11.99 272.30 Snrvey MD Ind Azim SS TVD N/S EIR' MrpN 11fapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 7600.00 26.92 20.52 5881.74 3788.63 1925.90 5958162.95 531125.09 0.00 3396.65 0.00 MWD 7655.00 26.13 20.95 5930.95 3811.61 1934.59 5958185.95 531133.70 1.48 3417.76 166.53 MWD 7660.00 28.13 20.95 5935.40 3813.73 1935.41 5958188.09 531134.50 40.00 3419.72 0.00 MWD 7669.00 31.73 20.95 5943.20 3817.93 1937.01 5958192.29 531136.09 40.00 3423.57 0.00 MWD 7678.39 35.96 20.95 5951.00 3822.81 1938.88 5958197.18 531137.94 45.00 3428.05 0.00 2D-05L 7680.00 36.68 20.95 5952.29 3823.70 1939.22 5958198.07 531138.28 45.00 3428.87 360.00 MWD 7690.00 41.18 20.95 5960.07 3829.57 1941.47 5958203.94 531140.50 45.00 3434.26 360.00 MWD 7700.00 45.68 20.95 5967.33 3835.99 1943.92 5958210.37 531142.94 45.00 3440.15 0.00 MWD 7705.37 48.10 20.95 5971.00 3839.65 1945.33 5958214.03 531144.32 45.00 3443.51 360.00 2D-05 7710.00 50.18 20.95 5974.03 3842.92 1946.58 5958217.31 531145.56 45.00 3446.51 0.00 MWD 7719.78 54.58 20.95 5980.00 3850.15 1949.35 5958224.55 531148.30 45.00 3453.16 360.00 2D-05L 7720.00 54.68 20.95 5980.13 3850.32 1949.41 5958224.72 531148.37 45.00 3453.31 0.00 MWD 7730.00 59.18 20.95 5985.58 3858.14 1952.41 5958232.55 531151.33 45.00 3460.50 0.00 MWD 7739.19 63.31 20.95 5990.00 3865.66 1955.29 5958240.09 531154.18 45.00 3467.40 360.00 2D-05L 7740.00 63.68 20.95 5990.36 3866.34 1955.55 5958240.77 531154.44 45.00 3468.03 0.00 MWD 7750.00 68.18 20.95 5994.44 3874.87 1958.81 5958249.30 531157.67 45.00 3475.85 0.00 MWD 7760.00 72.68 20.95 5997.79 3883.66 1962.18 5958258.11 531161.00 45.00 3483.93 0.00 MWD 7768.30 76.42 20.95 6000.00 3891.14 1965.04 5958265.59 531163.83 45.00 3490.79 360.00 2D-05L 7770.00 77.18 20.95 6000.39 3892.68 1965.63 5958267.14 531164.42 45.00 3492.21 0.00 MWD 7780.00 81.68 20.95 6002.22 3901.86 1969.14 5958276.33 531167.90 45.00 3500.64 360.00 MWD 7790.00 86.18 20.95 6003.28 3911.14 1972.70 5958285.63 531171.42 45.00 3509.17 0.00 MWD 7794.04 88.00 20.95 6003.48 3914.91 1974.14 5958289.40 531172.84 45.00 3512.63 0.00 MWD 7800.00 88.06 21.66 6003.69 3920.46 1976.31 5958294.96 531174.99 12.00 3517.72 85.00 MWD 7825.00 88.33 24.65 6004.48 3943.43 1986.13 5958317.96 531184.72 12.00 3538.63 84.98 MWD 7850.00 88.60 27.64 6005.15 3965.86 1997.14 5958340.44 531195.64 12.00 3558.81 84.88 MWD 7875.00 88.87 30.63 6005.70 3987.69 2009.31 5958362.31 531207.73 12.00 3578.19 84.80 MWD 7900.00 89.15 33.62 6006.13 4008.86 2022.60 5958383.53 531220.93 12.00 3596.73 84.74 MWD 7925.00 89.43 36.60 6006.44 4029.30 2036.98 5958404.03 531235.23 12.00 3614.37 84.68 MWD 7950.00 89.71 39.59 6006.63 4048.98 2052.40 5958423.76 531250.57 12.00 3631.07 84.65 MWD 7969.04 89.92 41.87 6006.69 4063.41 2064.82 5958438.23 531262.94 12.00 3643.12 84.62 MWD 7975.00 89.91 41.15 6006.70 4067.87 2068.77 5958442.71 531266.87 12.00 3646.83 269.00 MWD 8000.00 89.86 38.15 6006.75 4087.11 2084.72 5958462.01 531282.74 12.00 3663.01 269.00 MWD 8025.00 89.81 35.15 6006.83 4107.17 2099.64 5958482.12 531297.59 12.00 3680.17 269.01 MWO 8050.00 89.75 32.15 6006.92 4127.97 2113.50 5958502.98 531311.36 12.00 3698.26 269.02 MWD 8075.00 89.70 29.15 6007.04 4149.48 2126.24 5958524.54 531324.02 12.00 3717.22 289.03 MWD 8100.00 89.65 26.15 6007.18 4171.62 2137.84 5958546.72 531335.53 12.00 3737.01 269.04 MWD 8125.00 89.60 23.15 6007.34 4194.34 2148.27 5958568.48 531345.87 12.00 3757.57 269.06 MWD 8150.00 89.56 20.15 6007.53 4217.57 2157.49 5958592.74 531355.00 12.00 3778.85 269.08 MWD 8169.04 89.52 17.87 6007.68 4235.57 2163.70 5958610.77 531361.13 12.00 3795.50 269.10 MWD 8175.00 89.52 17.15 6007.73 4241.25 2165.49 5958616.45 531362.90 12.00 3800.79 270.00 MV1~ • • . , by BP Alaska s Baker Hughes INTEQ Planning Report INTE Q Company: 8P Amoco Date: 1}/2812006 Time: 10:16:24 Pale: 4 Fkld: Kuparuk Go-erdinatc(NE) Reference: WeIL 2D-05, True North Sitr. KRU 2D Pad VcrHcal (TVD) Refereece: 2D-05 Orig Rig 126.0 5Ve11: 2D-05 Seetion (VS) Re(creuce: Well (O.OON,O.OOE,350.OOAzi) Wet{path: Plan 3, 2D-0511 Survey Gaka~tion Method: Minimum Curvature Db: Orade Survey MD Ind rizim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft' ft $ ft deg/100ft ft deg 8200.00 89.52 14.15 6007.94 4265.32 2172.23 5958640.55 531369.55 12.00 3823.32 270.01 MWD 8225.00 89.53 11.15 6008.15 4289.71 2177.71 5958664.95 531374.93 12.00 3846.39 270.03 MWD 8250.00 89.53 8.15 6008.35 4314.35 2181.90 5958689.61 531379.03 12.00 3869.93 270.06 MWD 8275.00 89.53 5.15 6008.56 4339.18 2184.80 5958714.45 531381.83 12.00 3893.87 270.08 MWD 8300.00 89.54 2.15 6008.76 4364.13 2186.39 5958739.39 531383.33 12.00 3918.16 270.11 MWD 8325.00 89.55 359.15 6008.96 4389.12 2186.68 5958764.39 531383.51 12.00 3942.73 270.13 MWD 8344.04 89.55 356.87 6009.11 4408.15 2186.02 5958783.41 531382.78 12.00 3961.59 270.15 MWD 8350.00 89.56 357.58 6009.15 4414.10 2185.73 5958789.36 531382.47 12.00 3967.49 89.30 MWD 8375.00 89.60 0.58 6009.34 4439.09 2185.33 5958814.35 531381.97 12.00 3992.18 89.29 MWD 8400.00 89.64 3.58 6009.50 4464.07 2186.24 5958839.33 531382.78 12.00 4016.62 89.27 MWD 8425.00 89.68 6.58 6009.65 4488.97 2188.45 5958864.24 531384.90 12.00 4040.75 89.25 MWD 8450.00 89.72 9.58 6009.78 4513.72 2191.97 5958889.00 531388.32 12.00 4064.52 89.23 MWD 8475.00 89.76 12.58 6009.90 4538.25 2196.77 5958913.54 531393.03 12.00 4087.84 89.22 MWD 8494.04 89.79 14.87 6009.97 4556.75 2201.29 5958932.06 531397.47 12.00 4105.27 89.21 MWD 8500.00 89.84 14.15 6009.99 4562.52 2202.78 5958937.83 531398.94 12.00 4110.69 274.00 MWD 8525.00 90.05 11.16 6010.01 4586.91 2208.26 5958962.24 531404.33 12.00 4133.76 274.00 MWD 8550.00 90.26 8.17 6009.95 4611.55 2212.46 5958986.89 531408.43 12.00 4157.30 274.01 MWD 8575.00 90.47 5.18 6009.79 4636.38 2215.36 5959011.73 531411.23 12.00 4181.25 274.00 MWD 8600.00 90.68 2.18 6009.54 4661.32 2216.96 5959036.68 531412.74 12.00 4205.53 273.98 MWD 8625.00 90.88 359.19 6009.20 4686.31 2217.26 5959061.67 531412.94 12.00 4230.09 273.95 MWD 8650.00 91.09 356.20 6008.77 4711.29 2216.26 5959086.63 531411.84 12.00 4254.86 273.91 MWD 8675.00 91.29 353.20 6008.25 4736.17 2213.95 5959111.51 531409.44 12.00 4279.77 273.86 MWD 8700.00 91.48 350.21 6007.65 4760.90 2210.34 5959136.22 531405.73 12.00 4304.75 273.79 MWD 8725.00 91.67 347.21 6006.96 4785.40 2205.45 5959160.70 531400.75 12.00 4329.73 273.72 MWD 8750.00 91.86 344.22 6006.19 4809.62 2199.29 5959184.89 531394.49 12.00 4354.65 273.64 MWD 8775.00 92.05 341.22 6005.33 4833.47 2191.87 5959208.71 531386.98 12.00 4379.43 273.55 MWD 8800.00 92.22 338.22 6004.40 4856.90 2183.21 5959232.11 531378.23 12.00 4404.01 273.44 MWD 8825.00 92.39 335.23 6003.40 4879.85 2173.34 5959255.01 531368.27 12.00 4428.32 273.33 MWD 8850.00 92.56 332.23 6002.31 4902.24 2162.29 5959277.36 531357.13 12.00 4452.29 273.21 MWD 8875.00 92.72 329.23 6001.16 4924.02 2150.08 5959299.09 531344.84 12.00 4475.86 273.08 MWD 8894.04 92.83 326.94 6000.24 4940.17 2140.02 5959315.20 531334.72 12.00 4493.51 272.94 MWD 8900.00 92.79 326.23 5999.95 4945.14 2136.75 5959320.15 531331.43 12.00 4498.97 267.00 MWD 8925.00 92.63 323.23 5998.77 4965.52 2122.33 5959340.48 531316.93 12.00 4521.55 266.96 MWD 8950.00 92.46 320.23 5997.65 4985.13 2106.86 5959360.02 531301.39 12.00 4543.54 266.82 MWD 8975.00 92.29 317.24 5996.62 5003.90 2090.39 5959378.73 531284.85 12.00 4564.89 266.69 MWD 9000.00 92.10 314.24 5995.66 5021.79 2072.96 5959396.55 531267.35 12.00 4585.53 266.57 MWD 9025.00 91.91 311.24 5994.79 5038.74 2054.61 5959413.43 531248.94 12.00 4605.42 266.45 MWD 9050.00 91.72 308.25 5993.99 5054.72 2035.40 5959429.33 531229.67 12.00 4624.48 266.35 MWD 9075.00 91.52 305.25 5993.29 5069.67 2015.38 5959444.20 531209.59 12.00 4642.68 266.25 MWD 9100.00 91.32 302.26 5992.67 5083.56 1994.60 5959458.00 531188.76 12.00 4659.97 266.17 MWD 9125.00 91.11 299.27 5992.13 5096.34 1973.13 5959470.70 531167.24 12.00 4676.28 266.09 MWD 9150.00 90.90 296.27 5991.69 5107.98 1951.01 5959482.26 531145.08 12.00 4691.59 266.03 MWD 9169.04 90.74 293.99 5991.42 5116.07 1933.77 5959490.28 531127.81 12.00 4702.55 265.98 MWD 9175.00 90.76 294.71 5991.34 5118.52 1928.35 5959492.71 531122.38 12.00 4705.91 89.00 MWD 9200.00 90.81 297.71 5891.00 5129.56 1905.92 5959503.66 531099.91 12.00 4720.67 89.01 MWD 9225.00 90.85 300.71 5990.64 5141.76 1884.11 5959515.77 531078.05 12.00 4736.47 89.05 MWD 9250.00 90.90 303.71 5990.26 5155.08 1862.96 5959529.01 531056.85 12.00 4753.26 89.09 MWD 9269.04 90.93 305.99 5989.95 5165.96 1847.33 5959539.83 531041.19 12.00 4766.69 89.14 MWD 9275.00 91.04 306.70 5989.85 5189.49 1842.54 5959543.34 531036.38 12.00 4771.00 81.50 MWD 9300.00 91.48 309.67 5989.30 5184.94 1822.89 5959558.71 531016.68 12.00 4789.63 81.51 MWD 9325.00 91.92 312.64 5988.58 5201.38 1804.08 5959575.08 530997.80 12.00 4809.09 81.58 MWD 9350.00 92.35 315.61 5987.63 5218.77 1786.15 5959592.39 530979.80 12.00 4829.33 81.67 MWD • • by BP Alaska S Baker Hughes INTEQ Planning Report >.~vTE Q Company: BP Amoco I)nte: 11/28/2006 Time: 10:18:24 Page: 5 Field: Kupatuk Co-ordi~ate(1VE) Reference: Well: 2D-05, True North Site: KR U 2D Pad Vertlca l (TVD) Reference: 2D-05 Orig Rig 126.0 WeU: 2D-05 Section (VS) Reference: WeN (O.OON,O.OOE,350.OOAzi) 'Wetlpath: Pla n 3, 2D-05L1 Survey Calenlatioa Method: Minimum Curva ture Db: Oracle Sorvey MD (ncl Azim SS TVD N/S F./1Y MapN1 ivtapE DLS VS TFO Tool tt deg deg ft tl ft tt ft deg/100ft ft deg 9375.00 92.78 318.58 5986.51 5237.06 1769.14 5959610.62 530962.73 12.00 4850.29 81.18 MWD 9400.00 93.19 321.55 5985.20 5256.21 1753.12 5959629.70 530946.64 12.00 4871.93 81.91 MWD 9419.04 93.51 323.82 5984.09 5271.33 1741.60 5959644.77 530935.06 12.00 4888.82 82.06 MWD 9425.00 93.35 324.52 5983.74 5276.15 1738.12 5959649.57 530931.56 12.00 4894.17 103.00 MWD 9450.00 92.67 327.45 5982.42 5296.84 1724.15 5959670.21 530917.51 12.00 4916.97 103.04 MWD 9475.00 91.98 330.37 5981.41 5318.22 1711.25 5859691.55 530904.53 12.00 4940.27 103.20 MWD 9500.00 91.28 333.29 5980.70 5340.25 1699.46 5959713.52 530892.65 12.00 4964.01 103.31 MWD 9525.00 90.59 336.21 5980.29 5362.86 1688.80 5959736.09 530881.90 12.00 4988.13 103.40 MWD 9544.04 90.06 338.43 5980.18 5380.43 1681.45 5959753.63 530874.49 12.00 5006.71 103.44 MWD 9550.00 89.93 339.13 5980.18 5385.98 1679.30 5959759.17 530872.32 12.00 5012.55 100.00 MWD 9575.00 89.41 342.09 5980.33 5409.56 1671.00 5959782.71 530863.93 12.00 5037.21 100.00 MWD 9600.00 88.89 345.04 5980.70 5433.53 1663.83 5959806.66 530856.76 12.00 5062.05 99.98 MWD 9625.00 88.38 348.00 5981.29 5457.83 1658.10 5959830.93 530850.84 12.00 5086.99 99.94 MWD 9644.04 87.99 350.25 5981.90 5476.52 1654.51 5959849.61 530847.18 12.00 5106.02 99.87 MWD 9650.00 87.99 349.54 5982.11 5482.38 1653.47 5959855.46 530846.11 12.00 5111.97 270.00 MWD 9675.00 87.99 346.53 5982.98 5506.82 1648.29 5959879.88 530840.84 12.00 5136.94 270.03 MWD 9700.00 88.00 343.53 5983.86 5530.96 1641.84 5959903.99 530834.30 12.00 5161.83 270.13 MWD 9725.00 88.02 340.53 5984.73 5554.72 1634.13 5959927.72 530826.50 12.00 5186.57 270.24 MWD 9750.00 88.04 337.53 5985.59 5578.05 1625.19 5959951.01 530817.47 12.00 5211.09 270.34 MWD 9775.00 88.06 334.53 5986.44 5600.88 1615.04 5959973.79 530807.23 12.00 5235.34 270.44 MWD 9800.00 88.09 331.53 5987.28 5623.14 1603.71 5959996.01 530795.81 12.00 5259.23 270.55 MWD 9825.00 88.13 328.53 5988.11 5644.78 1591.23 5960017.60 530783.25 12.00 5282.71 270.65 MWD 9850.00 88.17 325.52 5988.91 5665.74 1577.63 5960038.51 530769.57 12.00 5305.72 270.75 MWD 9875.00 88.22 322.52 5989.70 5685.96 1562.95 5960058.67 530754.82 12.00 5328.18 270.84 MWD 9894.04 88.26 320.24 5990.29 5700.83 1551.07 5960073.49 530742.88 12.00 5344.88 270.94 MWD 9900.00 88.21 319.52 5990.47 5705.39 1547.23 5960078.03 530739.03 12.00 5350.03 266.00 MWD 9925.00 88.00 316.53 5991.30 5723.96 1530.52 5960096.53 530722.25 12.00 5371.23 266.02 MWD 9950.00 87.80 313.53 5992.21 5741.63 1512.87 5960114.14 530704.53 12.00 5391.70 266.12 MWD 9975.00 87.61 310.54 5993.22 5758.36 1494.32 5960130.79 530685.91 12.00 5411.39 266.23 MWD 10000.00 87.42 307.54 5994.30 5774.09 1474.92 5960146.44 530666.45 12.00 5430.25 266.35 MWD 10019.04 87.28 305.26 5995.18 5785.37 1459.61 5960157.67 530651.10 12.00 5444.02 266.48 MWD 10025.00 87.28 305.97 5995.46 5788.84 1454.77 5960161.11 530646.25 12.00 5448.27 90.00 MWD 10050.00 87.29 308.98 5996.65 5804.03 1434.96 5960176.23 530626.38 12.00 5466.68 89.97 MWD 10075.00 87.30 311.98 5997.83 5820.24 1415.96 5960192.36 530607.32 12.00 5485.94 89.82 MWD 10100.00 87.32 314.98 5999.00 5837.42 1397.85 5960209.47 530589.14 12.00 5506.00 89.68 MWD 10125.00 87.35 317.99 6000.17 5855.53 1380.65 5960227.51 530571.88 12.00 5526.82 89.54 MWD 10150.00 87.38 320.99 6001.32 5874.51 1364.43 5960246.43 530555.59 12.00 5548.33 89.40 MWD 10175.00 87.42 323.99 6002.45 5894.32 1349.23 5960266.17 530540.31 12.00 5570.48 89.26 MWD 10200.00 87.47 326.99 6003.56 5914.90 1335.08 5960286.70 530526.08 12.00 5593.20 89.13 MWD 10225.00 87.53 330.00 6004.65 5936.19 1322.03 5960307.93 530512.95 12.00 5616.44 88.99 MWD 10250.00 87.59 333.00 6005.72 5958.14 1310.11 5960329.83 530500.95 12.00 5640.12 88.86 MWD 10275.00 87.66 336.00 6006.75 5980.68 1299.36 5960352.33 530490.11 12.00 5664.19 88.73 MWD 10300.00 87.74 339.00 6007.75 6003.76 1289.80 5960375.37 530480.46 12.00 5688.58 88.61 MWD 10325.00 87.82 342.00 6008.72 6027.30 1281.46 5960398.88 530472.03 12.00 5713.21 88.49 MWD 10350.00 87.91 345.00 6009.66 6051.25 1274.37 5960422.80 530464.85 12.00 5738.03 88.37 MWD 10369.04 87.98 347.29 6010.34 6069.73 1269.81 5960441.26 530460.22 12.00 5757.02 88.26 MWD 10375.00 88.06 348.00 6010.54 6075.55 1268.54 5960447.07 530458.92 12.00 5762.97 83.50 MWD 10400.00 88.40 350.98 6011.32 6100.11 1263.98 5960471.61 530454.27 12.00 5787.95 83.48 MWD 10425.00 88.75 353.96 6011.94 6124.89 1260.71 5960496.37 530450.90 12.00 5812.92 83.38 MWD 10450.00 89.10 356.94 6012.40 6149.80 1258.72 5960521.27 530448.82 12.00 5837.80 83.31 MWD 10475.00 89.46 359.92 6012.72 6174.79 1258.04 5960546.25 530448.04 12.00 5862.52 83.25 MWD 10494.04 89.73 2.19 6012.85 6193.83 1258.39 5960565.29 530448.32 12.00 5881.21 83.22 MWD 10500.00 89.73 1.48 6012.88 6199.78 1258.58 5960571.25 530448.48 12.00 5887.04 270.60 MWD n .. by BP Alaska sr Baker Hughes INTEQ Planning Report uvTE Q Company: BP AmOCO Dntt: 11!2812006 Time: 10:16:24 Page: 4 Field: Kuparuk Go•erdinate(NE) Reterence: WeII: 2D-05, True North Site: KR U 2D Pad Vertical (TVD) Reference: 2D-05 Orig Rig 1 26.0 V1'ell: 2D-OS Section (VS) Reference. Well (O.OON,O.OOE,350.OOAzi) Wellpath: Pla n 3, 2D-05L1 Sarvey Calculation Method: Minimum Curvature Db: Orade Survev MD Iucl Azim SS TVD N/S E/VV MapN MapE DlS VS TFO Tool ft deg deg ft ft ft ft ft degJ100ft ft deg 10525.00 89.77 358.48 6012.99 6224.77 1258.57 5960596.24 530448.38 12.00 5911.66 270.60 MWD 10550.00 89.80 355.48 6013.09 6249.74 1257.25 5960621.19 530446.96 12.00 5936.47 270.62 MWD 10575.00 89.83 352.48 6013.17 6274.60 1254.63 5960646.04 530444.24 12.00 5961.41 270.63 MWD 10600.00 89.87 349.48 6013.23 6299.28 1250.71 5960670.71 530440.23 12.00 5986.40 270.64 MWD 10625.00 89.90 346.48 6013.29 6323.73 1245.50 5960695.14 530434.92 12.00 6011.38 270.65 MWD 10650.00 89.93 343.48 6013.32 6347.87 1239.02 5960719.25 530428.35 12.00 6036.28 270.65 MWD 10675.00 89.97 340.48 6013.34 6371.65 1231.29 5960742.99 530420.53 12.00 6061.03 270.66 MWD 10700.00 90.00 337.48 6013.35 6394.98 1222.32 5960766.29 530411.47 12.00 6085.57 270.66 MWD 10719.04 90.03 335.19 6013.34 6412.42 1214.68 5960783.70 530403.76 12.00 6104.07 270.66 MWD 10725.00 90.06 334.48 6013.34 6417.81 1212.14 5960789.08 530401.20 12.00 6109.82 272.30 MWD 10750.00 90.18 331.48 6013.29 6440.08 1200.79 5960811.30 530389.76 12.00 6133.73 272.30 MWD 10775.00 90.30 328.48 6013.19 6461.72 1188.28 5960832.89 530377.17 12.00 6157.21 272.29 MWD 10800.00 90.42 325.48 6013.03 6482.68 1174.66 5960853.80 530363.47 12.00 6180.22 272.28 MWD 10825.00 90.53 322.49 6012.82 6502.80 1159.96 5960873.95 530348.70 12.00 6202.68 272.26 MWD 10850.00 90.65 319.49 6012.56 6522.32 1144.23 5960893.31 530332.89 12.00 6224.54 272.24 MWD 10875.00 90.76 316.49 6012.25 6540.90 1127.50 5960911.82 530316.09 12.00 6245.74 272.21 MWD 10900.00 90.88 313.49 6011.90 6558.57 1109.82 5960929.42 530298.35 12.00 6266.21 272.17 MWD 10925.00 90.99 310.49 6011.49 6575.29 1091.25 5860946.07 530279.71 12.00 6285.90 272.13 MWD • 10950.00 91.09 307.50 6011.04 6591.02 1071.82 5960961.72 530260.22 12.00 6304.77 272.08 2 3/8" • • a. ~ ~ ,i ~ ltl~ ~~l- ~~Eji tt i.{I+ III_i~+t+i}~1}'~IGI f{1}~ l-i} {f1{ }ti '~ I~ ~`~ ~~ 'i n ~ - ir~ t~lf 1. -t ~. 1(i iiA. +t + _~ r,r 'r r t - - Ir= ~ r: # ~ ~ _ ~ _ ~ : i .:i Lll {~ {~ I `f -1-~I-i ~ ~f { t~ l ~ ~. ~~ #t f~~ ~i-~! i K~ ~~ t."fi rat ~t " ~ ~ ' t i r oa _, r ,C { f. ,r,~ ',11'!11. .;1 , fl~,1t ~ f a ~ i~l~ j~~.-~!it + 1~ (I 1 , J ~~ X11 ~i ~ !~ ~ P i t h t 1. t r 1 11~r I tj l r l ~I 1 )-r l! ~I {: r It ~ I l r l l ~: j r l t ~ #~ ~ ~ ~ ~; E r It ! = Y s , g ill lift _111-r +l~t`irt~ li~~ fiN ~~ rr~irr1~. ~~ 1 ~"~ i#i r~t ~~~~ !; i f ~ I ~i 1 I ~ t j f I I ~ ~ ~ ~ - l~~l Ill-{-,~~~~~ --~~ kkt~ .}~f~ ~ta ~- Y#~~i~~~' ~~ l.~# ~i ,~~" ~+~~ }~ ' ~ ~ I } t i{ 1-II ~ 1 ~ t ~ ~' 11 i'. ~ { 1'`IC 1( t it 1 ~ ills rjil .flfrjli-t#. 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I ~ ~' +~~:. µ I~~f._ it t~ .t~ f I # I~~t: ', .~... ~~ y lit! tft u~1 .i~ilifl {lil i~l~ ~iil Iltt~~~~ {r~~ ~ k{ ~} f`t}~l~trt 1~tf-( ~~ ~ f_~ i ~ ~i ~II' E Ir '- '' ~ ~ I r .1 ri, l i ,~ 1 ~ ~~ '~ i I, '.1. ~ _ .. ~ ~ ~ l 3 [wiueotlLIWM1A•3iiPM - 1. j ' { 1: $ ~{ i ~r r rli ~ Ir L~i~ `~~ t ~ { ~ ~ ~ #j } It~i _ ,jc n .,# n ~ :ix ~ ~ h ~ ~ P ~fi $ = 3 x x xt 33 ~ "3 SSSS H r t 1 ~ s A ~ " x sc xxixx xxxxgix - ~..- - F - ~ 1 % .,o° : x , A ~ o , \ t 9~oY~ xisitxi;iiitttit[25t ~ -- ~' Q QS~ ... .._.. - ~' ~ ~-1 z ~., ~qg8 ~.oQ 0 ¢ t-F ~ ~~Aa~ i ~ a LL ,a,, : i t , r , I, M a~ ## ~ =k~ tf i33 t s3S ii f -{ tl 1 7 i ~ ~ - l W jF , ~~ ~~~e~ esi. ~. x 't at d~ ! li-" il"t ±': •l_~ ~: _ __ ~ ?~ ~ ~ ~p~~ x-si.. i x..~ii ~ ~ ei ~ r f I i ~ I -t- t s t xx ii ix 1 AaI3.....xcacx_xx:t ~ ~-_ ;-f '. I l [ Tk f _ F~ . °?.'!3. nt~i33 i {; P aaii3ii s aaiaaai i i l 4.. i I 1. `. 3 .........:.........[ • e ll;Fli~ i;iizz-x~s~ i .~ V /f I •.' I ~ .... ~ ~ -' 9 3 , ~R,~~.R 8 ~.S R. ...g.. S .,5. .~. ...t~p.N./x.. ~. ~. .8.. .g.. .a._ :$.. .~:. 88 A ~M d 9[+VWB f.3 PAN ;~NNM ~u 6 Kuparuk CTD BOP configuration 2" CT Well 2D-05 Rig Floor 3" 5000 psi HCR M Choke Line C Tree Size 3-1 /8", 5M SSV Master Valve Base Flan e I Lubricator ID = 6.375" with 6" Otis Unions 1 Kill Line t ~COrn~ 2 1/16" 5000 psi , RX-24 OT ombi JT 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee Page 1 PERM1~" T~ DRlLL 20 AAC 2.5.005 • {e) Each well Branch requires a separate Permit to Dri((. (f a previously driiled Weil is prop~ation for a redrilled bc~iow the structural ar conductor casing to a new Batton,-gale loc;atian, the app Pern7ii to C~rilf must be accompanied by aliconductarr.`rsurface, artproductian ca ~ ~'If concurrent ri~;lltiple weft: branches are proposed from a sir~g(e {~~ far each ether wail branch, the application far a Permit to Drill accomnian ~~ by tfte $1QQ feender {c) of this section that ~s unictue to that weli branch and need not be P ~ ~ ~~l/LL ~A.~rl/ ,C/2~ Zy ~05~/ PT®# 1/ ®evelopment Sers~ice E~ptoratory~ Stratigraphie Test lion-Conventional Well Circle Appropriate Letter /Paragraphs to be Ineluded in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER w'HAT (OPTIONS j APPLIES ~~ !MULTI LATERAL ~~ The permit is for a new wellbore segment of existing [f l well ~~ ZD"-U J~ ( ast two digits ;API number in ~ Permit No. - ?.G , <API No. 30- OZ~ Zl/$"7 -~. a between 60-69) re ,Production should continue to be reported as a function of the original AP[ number stated above. PLOT HOLE In accordance with 20 .~aC 2~.00~(t~, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number ! ~ X30- - -_~ from records, data and logs acquired for well I !SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION Z3.0». Approval to perforate and produce / infect is contingent ' 'upon issuance of a conservation order approving a spacing ;exception. assumes the, liability of any protest to the spacing exception that may occur. DRY D[TCH 'All drv ditch sample sets submitted to the Commission must be in SAMPLE ! no greater than 30' sample intervals from below the permafrost or i ;from where samples are first caught and 10' sample intervals I through target zones. Non-Conventional 'Please note the following special condition of this permit: ;production or production testing of coal bed methane is not allowedi 'Well 'for (name of we11~ until after jCompanv Name) has designed and ~, implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rey b25%06 C'~jody`transmittaf checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 _ , Well Name: KUPARUK RIV UNIT 2D-05L1 ....`Program DEV Well bore seg PTD#:2061740 Company CONOCOPNILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Permit_fee attached_ _ _ _ _ __ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ NA_ . . _ Multilateral, wellbore segment; fee waived. per 20 AAC 25.005(e). _ _ _ _ . _ _ ... _ _ _ 2 Lease number appropriate. Yes _ _ _ . _ . Multilateral_wellbore segment; top_productive interval an_d TD_in ADL 025653. _ _ _ _ _ . _ _ _ _ _ 3 Uniquewell_nameandnumbe[_,__. Yes_ ______________ 4 Well located in a.d_efined_pool_ Yes KUPARUK RIVER,_KUPARUK.RVOIL - 490100, governed by Conservation Order No. 4320. _ _ _ _ _ _ _ _ , . 5 Well located properdistance from drilling unitboundary . .. . .... . ... . .. . Yes _ _ _ . . Con_seryation Order No. 4320 contains no spacing restrictions with respect to drilling unit boundaries. _ 6 Well located proper distance from other wells. Yes Conservation Order No. 4320 has no in_tenyell_spacing_restrictions, _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in_drilling unit. _ . Yes . ..... Conservation Order No. 4320 has no in_tenyell_spacing_restrickions, Wellbore will be.more than. 500' from _ _ _ _ 8 If_deviated, is_we_Ilbore platincluded Yes ...... an external property line where_ownership or_lan_downershpchonges. 9 Operatoronlyaffectedparty______________________ _ Yes_ ___.____ 10 Operator has appropriate_bondinforce_________________________________ Yes_ ___________________________. 11 Permit_c_an be issued without conservation order ........ . ...... .. Yes - - - Appr Date 12 Permit_can be issued without administ[ative.approval _ Yes _ SFD 12!1312006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by.lnjection Order # (put1O# in_comments) (For, NA_ . _ 15 All wells_within 114_mile area_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 Nonconue_n, ga_s conforms to AS31,05,030(j. t.A),O.2.A-lJ) _ _ _ _ _ _ . _ _ _ _ _ __ NA_ ------------------------------- ------------------------------- Engineering 18 Conductor string.provided______ __________________________________ NA__ - --- ,__,__Conductorsetinoriginal_we112D-05_(1.84,126),__________________ -------------------- 19 Surface casingp_rotectsaltknownUSDWs_____________________.__ _____ NA._ __ Altaquifersexempted,40CFR.147.192_(p)j3).__________.__._____.__._.______ _______ 20 CMT_vot adequate.to circulate_on conducto[ & surf_csg ..... .. NA_ , . _ Surface casing set in 2D-05. _ 21 _C_MT_vol adequate_to tie-in long string to surf csg_ NA_ _ _ _ Production_casing set in 2A-05; _ _ _ _ _ _ _ - - 22 CMT_will cover all known_productiye horizons, No_ Slatted liner completion planned, _ _ . _ _ _ _ 23 Casing designs adequate for C,_T, B &_permafrost _ _ Yes Original well_met design specifcations.. NA for slotted liner.. 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Rig isequipped with steel_pits. _ No resenie_pitplanned, All waste to_approved disposalwells.. - _ 25 If_a_re-drill, hasa 1.0-403 for abandonment been approved ........... Yes . .. _ . 30.6-377, approved to plug A sandperforaiions. _ - - 26 Adequate wellbore separation.proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity analysis performed, Nearest segment is original wellbore and Rath_s diverge.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Ifdiverterrequired,doesitmeet_regulations____________________________ NA__ __.__ BOPStack_willalready_beinplace,___________________________. - - Appr Date 28 _D_ril_ling fluid_program schematic & equip listadequate_ Yes _ _ .. _ _ .BHP maximum at 14.6 EMW, Expe~ed SHP 11.7 EMW. Plan to use dynamic overbalance and 549 psi.. TEM 12/1812006 29 BOPEs,.do they meetregulation _ _ _ _ . _ ... Yes 2 well volumes of_kifl weght_fluid wdlmaintained_within the_Kuparuk Field for well control contingency ... . ~~ 30 BOPE_press rating appropriate; test to_(put prig in comments), . , _ ..... Yes . ..... MASP calculated at 3i392.psi: Planned BOP_test 4000_psi_ _ _ _ _ _ _ _ _ _ _ _ _ - - 31 Choke_manifoldcomplieswlAPtRP-53(May84)__._._.____________________ Yes_ ________ _______________ 32 Work will occur without operation shutdown. _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ Yes _ _ _ _ _ ---------------- 33 Is presence_of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ H2$ has been reported at_2D pad.. Mud should preclude on_rig, Rig has sensors and alarrns._ _ _ _ 34 Mecha_nical_condition of wells within AOR verified ~Fo[seruice well only) _ _ _ _ __ _ _ _ _ _ _ _ NA_ _ _ ... _ ----------------------------------------------- Geology 35 Permit_can be issued w/o hydrogen_sulfidemeosures _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ , _ _ _ _ _ Wellson 2p_pad are H2$ bearing..H2_S_measures required _ .. _ . --------------------------- 36 Data_presented on potential overpressure zgnes_ Yes Lateralwellbore_d_rilled_from_active_injector._ Expected reservoir_pressure is 368$ psi (11.7ppg EMW)._ _ _ _ _ _ _ Appr Date 37 Seismic_analysis of shallow gas_zones_ . NA_ _ _ _ _ , Max. expected pressure_is 4509 psi (14,2 ppg EMW), Well will be drilled with_10:0_ppg mud using coiled. SFD 1211312006 38 Seabed condition survey_(ifoff.-shore) . _ NA_ _ _ _ tubing & managed pressure drilling techniques. Two wellbore volumes of kill weight fluid will_be available. 39 Contact name/phone for weekly_progress reports [exploratory only] NA_ Geologic Commissioner: Engineering Public Date: Commissioner: Date loner Date ~s ~2~~~~~ ~z - Zo-o-6' • •