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Home My WebLink About210-036Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ©~j ~j Well History File Identifier Two-sided III II'III II III II III ^ Rescan Needed III II'lII II II III III Orgamz~ng (done) ^ RES AN DIGITAL DATA Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria ~_ Date: `' f Project Proofing BY: ,~ Maria Date: ~, OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: v~P Scanning Preparation x 30 = i BY: _ Maria Date: Production Scanning /s/ + =TOTAL PAGES (Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: ~ot (Count does include cover heel) Page Count Matches Number in Scanning Pre aration: YES NO BY: Maria Date: ~ ~ l ~ ~s~ 'Y r' Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ Scannin is com late at this point unless rescanning is required. II I II'I II I II II I I III 9 P ReScanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III II'lll III IIII III P 10/6/2005 Well History File Cover Page doc ~ ~ McMains, Stephen E (DOA) From: Allsup-Drake, Sharon K [Sharon.K.Allsup-Drake@conocophillips.com] Sent: Tuesday, April 20, 2010 3:01 PM To: McMains, Stephen E (DOA) Cc: Eller, J Gary Subject: cancel permit to drill #210-036 Steve - ConocoPhillips Alaska would like to cancel permit to drill # 210-036 for well # 1 E-15AL2-02. If you have questions, please call Gary Eller at 263-4172 or myself. Thank you, Sharon 263-4612 SEAN PARNELL, GOVERNOR Von Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 E-15AL2-02 ConocoPhillips Alaska, Inc. Permit No: 210-036 Surface Location: 443' FSL, 815' FEL, Sec. 16, T11N, R10E, UM Bottomhole Location: 182' FNL, 2019' FWL, Sec. 21, T11N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel . Seamount, Jr. Chair /c~ DATED thisd / day of April, 2010. cc: Department of Fish 8s Game, Habitat Section w/ o encl. (via e-mail) Department of Environmental Conservation w/ o encl. (via e-mail) ~J ConocoPhilli s p P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 1, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: L REC~~yEp fink ~ ~ 2pfO ~~. ConocoPhillips Alaska, Inc. hereby submits a permit to drill application for one additional lateral sidetracl~,s~out of Kuparuk Well 1 E-15 (PTD# 182-102) using the coiled tubing drilling rig, Nabors CDR2-AC. Four Kuparuk A- sand lateral sidetracks have previously been approved: 1 E-15A (210-013), 1 E-15AL1 (210-014), 1 E-15AL2 (210-015), and 1 E-15AL2-01 (210-016). This additional lateral, 1 E-15AL2-02, is being added due to the geology being different than expected. The formation objective is the same as the original AL2-01 lateral proposal. This additional AL2-02 lateral will not affect the quarter-mile review that was previously submitted. Attached to this application are the following documents that explain the proposed job operations: - Permit to Drill Application Form for 1 E-15AL2-02 - Proposed Wellbore Schematic (updated) - Detailed Summary of Operations (updated) - Directional Plans Proposed operations for the new 1 E-15AL2-02 lateral are shown in blue in the enclosed wellbore schematic and summary of operations. If you have any questions or require additional information please contact me at my office 907-263-4172. Sincerely, Gary Elle ConocoPhillips Alaska Coiled Tubing Drilling Engineer STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill ^ Redrill ^~ Re-entry ^ 1 b. Proposed Well Class: Development -Oil ^ Service - Winj ~ Single Zone Q Stratigraphic Test ^ Development -Gas ^ Service -Supply ^ Multiple Zone ^ Exploratory ^ Service - WAG ^ Service - Disp ^ 1 c. Specify if well is proposed for: Coalbed Gas ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: Blanket ~ Single Well ^ Bond No. 59-52-180 11. Well Name and Number: 1E-15AL2-02 , 3. Address: P.O. Box 100360, Anc rage, AK 99510-0360 6. Proposed Depth: MD: 9470' • ND: 6280' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Go mmental Section): Surtace: 443' FSL, 815' EL, Sec. 16, T11 N, R10E, UM 7. Property Designation (Lease Number): ADL 25651 Kuparuk River Oil Pool . Top of Productive Horizon: 1329' FSL, 1222' FWL, Sec. 1 T11 N, R10E, UM 8. Land Use Permit: 469 13. Approximate Spud Date: 4/2/2010 Total Depth: 182' FNL, 2019' FWL, Sec. 21, T1 , R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 26100' 4b. Location of Well (State Base Plane C rdinates - NAD 27): Surtace: x-549710 y- 596003 Zone- 4 10. KB Elevation above MSL: 102 feet GL Elevation above MSL: 41 feet 15. Distance to Nearest Well Open to Same Pool: 1 E-16 at 675' 16. Deviated wells: Kickoff d the 8200 feet Maximum Hole Ang .102 degree 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4895 psig Surface: 4264 psig 18. Casing Program: Specific 'ons Top -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade upling Length MD ND MD ND ) 3" 2.375" 4.7# L-80 ST-L 1920 7550 6245 9470 62 4 19. PRESENT WELL CONDITION SUMMA be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 8435' Total Depth ND (ft): 6936' Plugs (mead. Effect. Depth MD (ft): 8323' Effect. Depth ND (ft): 6848' Junk (measured): .7884' Casing Length Size Cement Volume MD ND Conductor/Structural 112' 16" 326 sv AS 1 112' 112' Surface 2155' 10.75" 25 sx AS-III, 250 sx AS-II 2193' 2193 Intermediate Production 8376' 7" 05 sx class G 8410' 6916 Liner Perforation Depth MD (ft): 7478'-7554', 7716'-7739', 7742'-7796' Perforation Dep ND (ft): 6190'-6249', 6375 393', 6396'-6438' 20. Attachments: Property Plat ^ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ^ Diverter Sketch ^ Seabed Report ^ g Fluid Program ^~ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date 4/1/2010 22. I hereby certify that the foregoing is true and correct. v Contact Gary Eller (263-4172) Printed Name Von Cawvey Title Alaska Wells Man ~ ( ~~~ Signature ~ Phone 265-6306 Date Commission Use Only Permit to Drill Number. ~~~ ~~ API Numbe . ,_ 50- C~~ ~-~7~~ Permit Ap al Date: See cover letter for other requirements. Conditions of a<pproval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, as hydra s, or gas contained in shales: Other: '~ /~' ~ SL ~~ P TS f Samples req'd: Yes ^ o [[v]~ ud log req'd: Yes ^ No [~ # ZS'oo ~s~ An n....~-~ cs~~ H2S measures: Yes [~No ^ Direction svy req'd: Yes []~No ^ -f Gl i~.ivn.v~ p~dv'~~o.. ~h ~w~Y~ wf f{/O ZB - M (~"-TA -~~ess~.cQ ~'~- ~~ APPROVED B THE COMMISSION DATE• OMMISSIONER / v.z i~ s~~~ `~ ~/ ~ /C~ Submit in Duplicate ~R1GINAL Form to-4o1 (Revised 7/loos) This permit is valid for 24 months from the date of approval (20 AAC 25.00518)) KRU 1 E-15A, AL1, AL2, AL2-01, AL2-02 -Coiled Tubing Drilling Summary of Operations: Well 1E-15 is a Kuparuk A-sand and C-sand injection well equipped with 3'/z" tubing x 7" casing. Five proposed A-sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling, the existing C-sand in 1E-15 will be squeezed with cement and the A-Sand perfs will be plugged with a bridge plug. After squeezing the existing C-sand perfs with cement, a mechanical whipstock will be placed in the 3'/z" tubing at the first kickoff point. The 1E-15A sidetrack will make a 2-string exit through the 3'/z" tubing and 7" casing at 7635' MD. It will target the A4/5 sand northwest of the existing well with an 1890' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 9525' MD with a liner top aluminum billet at 8400' MD. The 1E-15AL1 lateral will kick off from the aluminum billet at 8400' MD and will also target the A4/5 sand northwest of the existing well with a 430' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 8830' MD with the final liner top located just inside the 3'/s" tubing at 7630' MD. The 1E-15AL21ateral will make another 2-string exit through the 3'/z" tubing and 7" casing at 7557' MD via a second mechanical whipstock placed in the 3'/z" tubing. It will target the A4 sand southeast of the existing well with a 2593' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 10,150' MD with a liner top aluminum billet at 8500' MD. The 1E-15AL2-O1 lateral will kick off from the aluminum billet at 8500' MD and will target the A4/5 sand southeast of the existing well with a 1575' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 10,075' MD with an aluminum billet at 8200' MD. The 1E-15AL2-02 lateral will kick off from the aluminum billet at 8200' MD and will target the A4/5 sand southeast of the existing well with a 1270' lateral. The hole will. be completed with a 23/8" slotted liner to the TD of 9470' MD with the final liner top located just inside the 3'/z" tubing at 7550' MD. CTD Drill and Complete 1E-15: March/Apri12010 Pre-R1Q Work 1. Test packoffs - T & IC. 2. Positive pressure and drawdown tests on MV, SV, & SSSV. 3. DGLV's, load tbg & IA. MIT-IA. MIT-OA. 4. Obtain updated static BHP on A-sand & C-Sand 5. Pull tubing patch isolating injection mandrel at 7592' 6. Dummy injection mandrels at 7354' & 7452' 7. Set 3'/z" CIBP at 7679' MD to plug off A-sand perfs 8. Shoot squeeze perfs thru the 3'h" tubing and 7" casing at 7630' & 7552' ELM 9. Lay in cement on top of CIBP isolating A-sand. Squeeze the C-sand perfs with cement. 10. RU slickline. Tag cement top. Pressure test cement squeeze. 11. Drill out cement from the 3'/z" tubing to 7665' using special clearance bi-center bit 12. Run whipstock dummy 13. Set monobore whipstock at 7635' MD with high-side orientation. 14. Prep site for Nabors CDR2-AC. Page 2 of 6 UPDATED March 31, 2010 KRU 1 E-15A, AL1, AL2, AL2-01, AL2-02 -Coiled Tubing Drilling Rig Work L MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1E-15A Lateral (A4/5 sand, northwest) a. Mill 2.74" 2-string window with high-side orientation at 7635' MD. b. Drill 2.70" x 3" bi-center lateral to TD of 9525' MD. c. Run 23/8" slotted liner with an aluminum liner-top billet from TD up to 8400' 3. 1E-15AL1 Lateral (A4/5 sand, northwest) a. Kick off of the aluminum billet at 8400' MD b. Dri112.70" x 3" bi-center lateral to TD of 8830' MD. c. Run 23/8" slotted liner from TD up to 7630' MD, up inside the 7" casing 4. 1E-15AL2 Lateral (A4 sand, southeast) ' a. Set 3'/2" monobore whipstock in 3'/i" tubing at 7557' MD with low-side orientation. b. Mi112.74" 2-string window with low-side orientation at 7557' MD. c. Dri112.70" x 3" bi-center lateral to TD of 10,150' MD. d. Run 23/8" slotted liner with an aluminum liner-top billet from TD up to 8500' 5. 1E-15AL2-O1 Lateral (A4/5 sand, southeast) a. Kick off of the aluminum billet at 8500' MD b. Dri112.70" x 3" bi-center lateral to TD of 10,075' MD. c. Run 23/8" slotted liner with an aluminum billet from TD up to 8200' 6. 1E-15AL2-02 Lateral (A4/5 sand, southeast) a. Kick off of the aluminum billet at 8200' MD b. Dri112.70" x 3" bi-center lateral to TD of 9470' MD. c. Run 23/8" slotted liner from TD up to 7550' MD, up inside the 3'/z" tubing 7. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Obtain static BHP 2. Run GLVs 3. Flow back well to tanks or to the system for clean up prior to putting on injection 4. Conduct MIT-IA 5. Put well on injection Mud Program: • Will use chloride-based Biozan brine or used drilling mud (8.6 ppg) for milling operations, and chloride- based Flo-Pro mud 010.0 ppg)~for drilling operations. There is a SCSSV installed in 1E-15, so we should ~ not have to kill the well to deploy 23/8" slotted liner. 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. Casing Program: • 1E-15A: 23/8", 4.7#, L-80, ST-L slotted/solid liner from 8400' MD to 9525' MD • 1E-15AL1: 23/8", 4.7#, L-80, ST-L slotted/solid liner from 7630' MD to 8830' MD • 1E-15AL2: 23/8", 4.7#, L-80, ST-L slotted/solid liner from 8500' MD to 10,150' MD • 1E-15AL2-O1: 23/8", 4.7#, L-80, ST-L slotted/solid liner from 8200' MD to 10,075' MD • 1E-15AL2-02: 23/8", 4.7#, L-80, ST-L slotted/solid liner from 7550' MD to 9470' MD Existing Casing/Liner Information Page 3 of 6 UPDATED March 31, 2010 KRU 1 E-15A, AL1, AL2, AL2-01, AL2-02 -Coiled Tubing Drilling Surface: 103/4", K-55, 45.5 ppf Burst 3580 psi; Collapse 2090 psi Production: 7", K-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Well Control: • Two well bore volumes (180 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 5000 psi. Maximum potential surface pressure in 1E-15 is 4264 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity, which is 4895 ~s~ 7633' MD, 6310 TVD (i.e. 14.9 ppg) from 1E-15 itself in late November 2009. Since that time, the A-sand has been allowed to crossflow to the lower- pressure C-sand, so the formation pressure in the A-sand is now reduced. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 1 E-15A, plan #3 2. 1E-15AL1, plan #3 3. 1E-15AL2, plan #5 4. 1E-15AL2-O1, plan #5 5. 1E-15AL2-02, plan #1 •. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 1 E-15 CTD northwestern laterals (A & AL 1): 26,100' to property line, ~ 1015' to wells 1 E-11 & 1 E-13 • 1E-15 CTD southeastern laterals (AL2, AL2-Ol, &AL2-02): 24,400' to property line, 675' from well 1E-16 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 1E-15 was taken January 2010 after allowing the A-sand to cross flow to the lower pressure C-sand for a month. The 72-hour buildup measured reservoir pressure of 3719 psi at 6238' SSTVD, corresponding to 1 LS ppg EMW. We generally expect to encounter decreasing pressure as the laterals are drilled away from the mother well due to offset producing wells. Hazards • Lost circulation is usually not particularly troublesome in the A-sand, but it is a possibility in 1E-15 since we expect to encounter decreasing formation pressure as the laterals are drilled away from the mother well. • Over-pressured zones are a potential hazard in 1E-15. Even though cross flow to the C-sand has significantly reduced A-sand pressure in the 1E-15 wellbore to 11.5 ppg, there is opportunity to encounter high-pressure stringers (up to 15.0 ppg) while drilling. With 10.0 ppg mud and expected formation pressure, no choke pressure is needed to maintain well control If high pressure formations are encountered, a combination of mud weight and/or choke could be needed to maintain well control. Use of the SSSV to deploy slotted liner should eliminate the need to spot heavy kill weight fluid, but if the SSSV fails then completion fluids in excess of 13.0 ppg will be needed to kill the well. • Shale stability is a potential problem, particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70° hole angle, and by holding a constant pressure on the formation throughout drilling operations. Page 4 of 6 UPDATED March 31, 2010 Irk 1~.~ KRU 1 E-15A, AL1, AL2, AL2-01, AL2-02 -Coiled Tubing Drilling • Well 1E-15 has no measured HZS since it is an injection well. Well 1E-31 is located 105' to the right side and 1E-16 is 120' to the left side of the 1E-15 surface location. 1E-16 has no measured HZS since it also is an injection well. Well 1E-31 has 60 ppm HZS as measured on 8/6/09. The maximum HZS level on the pad is 130 ppm from well 1E-24A (8/6/09). All HZS monitoring equipment will be operational. - 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 is installed between the BOPS choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 23/8" BHA will be accomplished utilizing the 23/8" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 1E-15 has a SCSSV, so the well should not have to be killed prior to running 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: • Expected reservoir pressure is 3711~si at 7635' MD (6206' SSTVD), or 11.5 ppg EMW. • Expected annular friction losses while circulating: 763 psi (assuming annular friction of 100 psi/1000 ft due to the 3'/2" tubing) • Planned mud density of 10.0 ppg equates to 3227 psi hydrostatic bottom hole pressure at 6206' SSTVD • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 3990 psi or 12.4 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1E-15. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, 760 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Page 5 of 6 UPDATED March 31, 2010 KRU 1 E-15A, AL1, AL2, AL2-01, AL2-02 -Coiled Tubing Drilling Quarter-Mile Injection Review The following wells lie within one-quarter mile of the proposed 1E-15 CTD laterals. A detailed review will be made of each of these wells separately and subsequently to the submission of the drilling permits. 1E-15 motherbore (injector) 1E-15 CTD northwestern laterals (A & AL1): • 1E-11 (injector) • 1E-13 (injector) • 1F-19 (producer) 1E-15 CTD southeastern laterals (AL2, AL2-O1, &AL2-02): • 1E-06 (producer) • 1E-14 (producer) • 1E-16 (injector) • 1 E-17 (injector) • 1E-30 (injector) Page 6 of 6 UPDATED March 31, 2010 1 E-15 Proposed CTD Sidetrack Last Updated: 31-Mar-10 1 3-1/2" 9.3# K-55 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels @ 1948', 3690', 5218', 6256', 7271' 112' MD 10-3/4" 45.5# K-55 shoe @ 2193 MD C-sand perfs 7478' - 7554' MD Sqz perfs (2/14/10) -_ 7550' - 7554' CBL 7618' - 7638' CBL KOP #2 at 7557' MD KOP #1 at 7631' MD Baker flow-by monobore whipstocks A-sand perfs 7716' - 7796' MD (plugged) 7" 26# K-55 shoe @ 8410' MD Baker 3-1/2" PBR @ 7307' MD Baker FHL packer @ 7321' MD 3-1/2" Camco KBUG injection mandrels @ 7354', 7425', 7592' Carbide blast rings 7446' - 7552' (7452'-7538' CBL) Baker FB-1 packer @ 7663' MD w/ Baker SBE 3-1/2" Camco D landing nipple @ 7676' MD (2.75" min ID, No-Go) 3-1/2" tubing tail @ 7682' MD \\' AL2-02 Lateral (A5 sand, southeast) AL2-01 Lateral (A5 sand, so \ ~ TD = 9470', KO from 8200' TD = 10,000', KO from 8855' Liner top at 7550' BilleUliner at 8200' - - ~i - ~~ - - /~ AL2 Lateral, TD = 9835' ~ j / / ~. 2-3/8" liner 8864'-9835' ~ - / - - - - _-- - Billet at 8855' _ -_-_ _--- AL1 Lateral, TD = 8812' / / 2-3/8" liner 7623' - 8810' ~ - / / Liner top at 7623' ~ - - - - - A Sidetrack, TD = 9800' CIBP at 7656' ELM 2-3/8" liner 8326' - 9790' (7674' MD, 2/13/10) Billet at 8326' • ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 E Pad 1 E-15 1 E-15AL2-02 Plan: 1 E-15AL2-02 wp01 (Rev.1) Standard Planning Report 31 March, 2010 ri.~ BAKER NI~FIES • C~ocoPhllips A~Ica Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Weil: 1 E-15 Wellbore: 1 E-15AL2-02 Design: 1 E-15AL2-02_wp01 (Rev.1) ConocoPhillips ~~~~ Planning Report Local Co-ordinate Reference: Well 1 E-15 TVD Reference: Mean Sea Level MD Reference: 1 E-15 @ 105.70ft (1 E-15) . North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit Map System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 'Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70° 18' 3.022 N From: Map Easting: 549,889.51 ft Longitude: 149° 35' 45.358 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.38 ° Well 1 E-15 Well Position +N/-S 0.00 ft Northing: +E/-W 0.00 ft Easting: Position Uncertainty 0.00 ft Wellhead Elevation Wellbore 1 E-15AL2-02 Magnetics Model Nam® Sample Date BGGM2009 3/25/2010 --- __ Design 1E-15AL2-02_wp01 (Rev.1) Audit Notes: 5,960,029.95 ft Latitude: 549,710.04 ft Longitude: ft Ground Level: Declination (°) 17.33 Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/-S (ft) (ft) 0.00 0.00 Plan Sections Measured TVD Below Depth Inclination Azimuth System +N/-S +E/-W (ft) (°) (°) (ft) (ft) (ft) 8,200.00 89.79 152.38 6,306.78 412.74 -3,057.94 8,278.54 102.00 145.21 6,298.72 346.06 -3,017.62 8,376.54 102.34 127.16 6,277.89 277.23 -2,951.60 8,506.54 91.49 148.08 6,262.10 182.40 -2,865.44 8,706.54 91.21 184.09 6,257.23 -8.50 -2,818.16 8,786.54 90.17 169.73 6,256.27 -88.17 -2,813.86 9,006.54 89.18 130.14 6,257.56 -274.80 -2,705.83 9,086.54 90.20 115.78 6,258.00 -318.21 -2,638.88 9,256.54 92.97 146.27 6,253.20 -428.39 -2,512.17 9,406.54 79.60 169.83 6,263.04 -565.84 -2,456.51 9,470.00 68.17 169.83 6,280.62 -625.75 -2,445.76 70° 18' 5.686 N 149° 35' 50.538 W 0.00 ft Dip Angle Field Strength 79.80 57,371 Tie On Depth: 8,200.00 +El-W Direction (ft) (°) 0.00 149.00 J Dogleg Build Turn Rate Rate Rate TFO 0.00 0.00 0.00 0.00 18.00 15.55 -9.13 330.00 18.00 0.34 -18.41 273.00 18.00 -8.34 16.09 116.00 18.00 -0.14 18.00 90.00 18.00 -1.29 -17.96 266.00 18.00 -0.45 -17.99 268.50 18.00 1.27 -17.96 274.00 18.00 1.63 17.93 84.50 18.00 -8.91 15.71 120.00 18.00 -18.00 0.00 180.00 Target 3/31/2010 1:16:58PM Page 2 COMPASS 2003.16 Build 69 ConoeoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: 1E-15 Welibore: 1 E-15AL2-02 Design: 1E-15AL2-02_wp01 (Rev.1) Planned Survey ConocoPhillips E~1 Planning Report Local Co-ordinate Reference: Well 1 E-15 TVD Reference: Mean Sea Level MD Reference: 1 E-15 @ 105.70ft (1 E-15) North Reference: True Survey Calculation Method: Minimum Curvature Measured ND Below Vertical Dogleg Toolface Map Depth Inclination Azimuth System +wyr +~_W Section Rate Azimuth Northing (ft) l°) (°) (ft) (ftl lftl {ft) (°/100ft) (°) {ft) 8,200.00 89.79 152.38 6,306.78 412.74 -3,057.94 -1,928.74 0.00 0.00 5,960,422.41 TIP / KOP 8,278.54 102.00 145.21 6,298.72 346.06 -3,017.62 -1,850.81 18.00 -30.00 5,960,356.00 2 8,300.00 102.17 141.26 6,294.22 329.25 -3,005.06 -1,829.94 18.00 -87.00 5,960,339.28 8,376.54 102.34 127.16 6,277.89 277.23 -2,951.60 -1,757.82 18.00 -87.83 5,960,287.62 3 8,400.00 100.46 131.02 6,273.26 262.73 -2,933.76 -1,736.20 18.00 116.00 5,960,273.24 8,500.00 92.05 147.05 6,262.30 187.92 -2,868.95 -1,638.69 18.00 116.76 5,960,198.86 8,506.54 91.49 148.08 6,262.10 182.40 -2,865.44 -1,632.16 18.00 118.53 5,960,193.37 4 8,600.00 91.43 164.91 6,259.70 97.03 -2,828.32 -1,539.86 18.00 90.00 5,960,108.26 8,700.00 91.22 182.92 6,257.37 -1.97 -2,817.76 -1,449.56 18.00 90.43 5,960,009.34 8,706.54 91.21 184.09 6,257.23 -8.50 -2,818.16 -1,444.17 18.00 90.85 5,960,002.81 5 8,786.54 90.17 169.73 6,256.27 -88.17 -2,813.86 -1,373.67 18.00 6 8,800.00 90.11 167.31 6,256.23 -101.36 -2,811.18 -1,360.99 18.00 8,900.00 89.64 149.31 6,256.45 -193.89 -2,774.37 -1,262.71 18.00 9,000.00 89.20 131.32 6,257.47 -270.53 -2,710.78 -1,164.27 18.00 9,006.54 89.18 130.14 6,257.56 -274.80 -2,705.83 -1,158.06 18.00 7 9,086.54 90.20 115.78 6,258.00 -318.21 -2,638.88 -1,086.37 18.00 8 ~ i 9,100.00 90.43 118.19 6,257.93 -324.31 -2,626.89 -1,074.96 18.00 9,200.00 92.10 136.11 6,255.70 -384.44 -2,547.53 -982.55 18.00 9,256.54 92.97 146.27 6,253.20 -428.39 -2,512.17 -926.66 18.00 9 9,300.00 89.04 153.04 6,252.43 -465.86 -2,490.23 -883.24 18.00 9,400.00 80.16 168.78 6,261.89 -559.51 -2,457.71 -786.22 18.00 9,406.54 79.60 169.83 6,263.04 -565.84 -2,456.51 -780.18 18.00 '10 9,470.00 ~ 68.17 169.83 6,280.62 -625.75 -2,445.76 -723.29 18.00 TD Map Fasting (~) 546,649.73 546,690.49 546,703.16 546,756.96 546,774.90 546,840.19 546,843.73 546,881.42 546,892.63 546,892.27 -94.00 5,959,923.18 546,897.10 -91.50 5,959,910.01 546,899.86 -91.51 5,959,817.72 546,937.28 -91.47 5,959,741.52 547,001.37 -91.28 5,959,737.28 547,006.35 86.00 5,959,694.32 547,073.58 84.50 5,959,688.30 547,085.61 84.51 5,959,628.71 547,165.36 84.91 5,959,584.99 547,201.00 120.00 5,959,547.67 547,223.19 120.12 5,959,454.25 547,256.33 118.62 5,959,447.93 547,257.57 180.00 5,959,388.10 547,268.71 3/31/2010 1:16:58PM Page 3 COMPASS 2003.16 Build 69 ~--' ' ConocoPhillips CCN ~OCt3~11~~ipS .Alaska" Planning Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Company: ConocoPhillips(Alaska) Inc. ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1 E Pad North Reference: Well: 1 E-15 Survey Calculation Method: Weilbore: 1 E-15AL2-02 Design: 1E-15AL2-02_wp01 (Rev.1) Targets - - _ _ - Target Name - hitJmiss target Dip Angle Dip Dir, ND +N/S +E/-W Northing -Shape (°) (°) (ft) (fti (ft) (ft) 1 E-15AL2-02 t4 0.00 0.00 6,252.00 -505.09 -2,553.21 5,959,508.03 -plan misses target center by 74.23ft at 9316.35ft MD (6252.92 ND, -480.59 N, -2483.15 E) - Point 1 E-15AL2-02 t2 0.00 0.00 6,256.00 -58.82 -2,776.74 5,959,952.77 - plan misses target center by 40.91 ft at 8759.17ft MD (6256.43 ND, -61.06 N, -2817.58 E) - Point 1 E-15AL2-02 t3 0.00 0.00 6,258.00 -317.34 -2,645.98 5,959,695.14 - plan misses target center by 2.40ft at 9080.09ft MD (6258.02 ND, -315.34 N, -2644.66 E) - Point 1 E-15AL2, AL2-01 Po 0.00 0.00 0.00 984.94 -3,333.62 5,960,992.72 - plan misses target center by 6327.34ft at 8400.OOft MD (6273.26 ND, 262.73 N, -2933.76 E) - Polygon Point 1 0.00 984.94 -3,333.62 5,960,992.72 Point 2 0.00 633.99 -3,499.94 5,960,640.71 Point 3 0.00 256.88 -3,338.40 5,960,264.71 Point 4 0.00 -480.37 -2,703.16 5,959,531.75 Points 0.00 -1,411.22 -2,286.22 5,958,603.77 Point6 0.00 -1,348.61 -1,921.77 5,958,668.78 Point? 0.00 -359.56 -2,367.33 5,959,654.77 Point 8 0.00 413.35 -2,949.33 5,960,423.74 Point 9 0.00 660.79 -3,164.73 5,960,669.72 Point 10 0.00 942.12 -3,057.87 5,960,951.72 Point 11 0.00 984.94 -3,333.62 5,960,992.72 1 E-15AL2-02 t5 0.00 0.00 6,280.00 -638.97 -2,487.59 5,959,374.60 - plan misses target center by 43.87ft at 9470.OOft MD (6280.62 ND, -625.75 N, -2445.76 E) - Point 1 E-15AL2-01 fault 1 (r 0.00 0.00 0.00 -569.93 -2,622.84 5,959,442.74 - plan misses target center by 6254.70ft at 9300.OOft MD (6252.43 ND, -465 .86 N, -2490.23 E) - Polygon Point 1 0.00 -569.93 -2,622.84 5,959,442.74 Point 2 0.00 -658.07 -2,451.06 5,959,355.75 Point 3 0.00 -773.56 -2,225.13 5,959,241.76 Point 4 0.00 -658.07 -2,451.06 5,959,355.75 1 E-15AL2-02 t4.5 0.00 0.00 6,260.00 -589.72 -2,511.77 5,959,423.69 -plan misses target center by 60.28ft at 9406.54ft MD (6263.04 ND, -565.84 N, -2456.51 E) - Point 1 E-15AL2-02 t1 0.00 0.00 6,262.00 154.91 -2,905.56 5,960,165.62 - plan misses target center by 48.98ft at 8515.78ft MD (6261.86 ND, 174.49 N, -2860.67 E) - Point • ~~~ s Well 1 E-15 Mean Sea Level 1 E-15 @ 105.70ft (1 E-15) True Minimum Curvature -- - - Fasting (ft) Latitude Longitude 547,160.48 70° 18' 0.714 N 149° 37' 4.973 W 546,934.02 70° 18' 5.102 N 149° 37' 11.494 W 547.066.47 70° 18' 2.560 N 149° 37' 7.679 W 546,370.30 70° 18' 15.365 N 149° 37' 27.743 W I 546,370.30 546,206.32 546,370.34 547,010.38 547,433.43 547,797.42 547,345.37 546,758.33 546,541.32 546,646.30 546,370.30 547,226.98 70° 17' 59.398 N 149° 37' 3.058 W I 547,091.28 70° 18' 0.076 N 149° 3T 7.002 W 547,091.28 547,263.62 ', 547,490.29 547,263.62 547,202.47 70° 17' 59.882 N 149° 37' 3.764 W 546,803.80 70° 18' 7.204 N 149° 37' 15.252 W Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft1 (ft) Name ("- (") 2,193.00 2,087.10 10 3/4" 10-3/4 12-1/4 9,470.00 6,280.62 2 3/8" 2-3/8 3 3/31/2010 1:16:58PM Page 4 COMPASS 2003.16 Build 69 ' - Cvlnoeo~llps Aaaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: 1E-15 Welibore: 1 E-15AL2-02 Design: 1E-15AL2-02_wp01 (Rev.1) Plan Annotations Measured Vertical Depth Depth (ft) (ft) 8,200.00 6,306.78 8,278.54 6,298.72 8,376.54 6,277.89 8,506.54 6,262.10 8,706.54 6,257.23 8,786.54 6,256.27 9,006.54 6,257.56 9,086.54 6,258.00 9,256.54 6,253.20 9,406.54 6,263.04 9,470.00 6,280.62 ConocoPhillips Planning Report Local Co-ordinate Reference: Wetl 1 E-15 ND Reference: Mean Sea Level MD Reference: 1 E-15 @ 105.70ft (1 E-15) North Reference: True Survey Calculation Method: Minimum Curvature Local Coordinates +NI-S +E/-W (ft) (ft) Comment 412.74 -3,057.94 TIP / KOP 346.06 -3,017.62 2 277.23 -2,951.60 3 182.40 -2,865.44 4 -8.50 -2,818.16 5 -88.17 -2,813.86 6 -274.80 -2,705.83 7 -318.21 -2,638.88 8 -428.39 -2,512.17 9 -565.84 -2,456.51 10 -625.75 -2,445.76 TD ~'~_ 3/31/2010 1:16:58PM Page 5 COMPASS 2003.16 Build 69 COPiOCO~"tl~~IpS Project: Kuparuk River Unit M~ nbnn~z~i.rat• WELLBORE DETAILS: 1E-15AL2-02 REFERENCEINFORMATION S1te: KupaniklE Pad Magrretic Field Parent Wellbore: 1E-15AL2 Co-ordinate (N/E)Reference: We111E-15, True NOM Well: 1 E-15 ~~~~~~+~+ Tie on MD: 8200 00 Venical (ND) Reference: Mean Sea Level W@IlbOfe: 1E-15AL2.02 D'vAnSle-eo.e4° . SecAOn (VS)Reference: Slot-(O.OON, O.OOE) PIan:1E-15AL2-02 01 Re¢1 1E-15/1E-15AL2-02 _'~P ~ ~ ( ~ °ate~'~ Model: BGG Measured Depth Reference: 1E-15@105.708 (1E-t5) Calculafion Metlrod: Minimum Curvature 7 WELL DETAILS: 1E•15 600 Ground Level: 0.00 500 +N!-5 +E/_W Northing Easting Latittude Longitude Slot 0.00 0.00 5960029.95 549710.04 7D° 18' 5.686 N 149° 35' 50.538 W 4 SECTION DETAILS ANNOTATIONS 2 Sec MD Inc Azi NDSS +NI-S +FJ-W DLeg TFace VSec Target Annotation 3 1 8200.00 89.79 152.38 6306.78 412.74 -3057.94 0.00 0.00 -1928.74 TIP / KOP 2 3 8 8 2 20 2 8278.54 102.00 145.21 6298.72 346.06 -3017.6 1 8.00 30.00 -1 50. 1 3 8376.54 102.34 127.16 6277.89 277.23 -2951.60 18.00 273.00 -1757.82 3 ~ 4 8506.54 91.4 9 148.08 6262.10 182.40 -2865.44 1 8.00 116.00 -1632.16 4 ~ 100 5 8706.54 91.21 184.09 6257.23 -8.50 -2818.16 18.00 90.00 -1444.17 5 6 8786 54 90 17 169 73 6256 27 -88 17 -2813 86 18 00 266 00 -1373 67 6 ~ . . . . . . . . . ° o 7 9006.54 89.18 130.14 6257.56 -274.80 -2705.83 1 8.00 268.50 -1158.06 7 8 9086.54 90.20 115.78 6258.00 -318.21 -2638.88 18.00 274.00 -1086.37 8 9 9256.54 92.97 146.27 6253.20 -428.39 -2512.17 18.00 84.50 -926.66 9 ± 1~ 10 9406.54 79.60 169.83 6263.04 -565.84 -2456.51 18.00 120.00 -780.18 10 ^ ~ I 11 9470.00 68.17 169.83 6280.62 -625.75 -2445.76 18.00 180.00 -723.29 TD ° 200 300 ~ 7 y - O 400 f/]- 9 5 - 6 - 7 IE-IS IE-15 L2-0 _ -g i ~ ~ 1 -.-I5;1(~ -Ii1L ~-01 - _ _ 1G15/ 1': 15.A .,'. _ -36 00 -35 00 -34 00 -33 00 -32 00 -31 00 -30 00 -29 00 -28 00 -27 00 -26 00 -25 00 -24 00 -23 00 -22 00 -21 00 -20 00 -19 00 -18 00 i ~ i ~ i ~ ~ i i Ww t(-)/E ast( +) (1 00 W in) ~ i i 6os 612 i ~ 61 O 62 j ~ /KOP 4 6 7 10 IFrI /1E-15 L2A2 '~ 624 r r r i IE-I t/ E-I5A 2-01 GL 2 l i - , Q ~ 628 J r U N 632 ~ ' .~ ~ ~ ~ IE- 5/lE-I ~ AL2 63 d) H 644 i I 648 I I j I ~ i I i i j 682 I , -1960 -1920 -1880 -1840 -1800 -1760 -1720 -1680 -1640 -1600 -1560 -1520 -1480 -1440 -1400 -1360 -1320 -1280 -1240 -1200 -1160 -1120 -1080 -1040 -IlNJO -960 -920 -880 -840 -8W -760 -7ZU -680 -640 -6W -560 -5ZU -480 -440 -4UU Vertical Section at 149.00° (40 Win) ConocoPhillips C O O N + `. 7O 7 .-. .-. O Project: Kuparuk River Unk n~~mumsrortieraam Mae~no NOm,.r ar WELLBORE DETAILS: 1E-15AL2-02 REFERENCEINFOFUMTION Site: KuparuklE Pad M,y~~r;ey Parent Wellbore: 1E-15AL2 Coa~nate (NrE)Ralerence: We111E-15, True North Well: 1E-15 saer~n-s7cs7.tsn Te on MD: 8200.00 Vetlical (TVD)Reterence: tE-15@105.70tt (tE-15) Wellbore: 1E-15AL2-02 oiaArek. aO.en° Section (VS)Reterence: Slot-(O.OON, O.OOE) PIan:1E-15AL2-02 wp01(Rev.1)(1E-1511E-15AL2-02) ~he10 Measured Depth Reference: 1E-15@105.70ft(1E-15) Calculafion Melhod: Minimum Curvature 1 E-15 ~ 105.70ft (1 E-15) West(-)/East(+) (200 ft/in) i ConocoPhillips SURVEY PROGRAM Date: 2010-03-31700:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 200.00 7500.00 1E-15 (1E-15) FINDER-MS 7557.00 5200.00 1 E-15AL2 (1 E-15AL2) M WD 8200.00 9470.00 1E-15AL2-02_wp01 (Rev.1)(1E-15AL2-02) MWD WELLDETAILS: tE-15 Ground Level: 0.00 +NIS +FJaN Northing Easling Latitude Longitude Slot 0.00 0.00 5960029.95 549710.04 70° 18' 5.886 N 149° 35' 50.538 W SECTION DETAILS Sec MD Inc Aa TVD +N/S +E/-W DLeg TFace VSec Target 1 8200.00 89.79 152.38 6412.48 412.74 -3057.94 0.00 0.00 -1928.74 2 8276.54 102.00 145.21 6404.42 346.06 J017.62 18.00 330.00 -1850.81 3 8376.54 102.34 127.16 fi383.59 277.23 -2951.60 16.00 273.00 -1757.82 4 8506.54 91.49 148.08 6367.80 162.40 -2865.44 18.00 116.00 -1632.16 5 8706.54 91.21 164.09 6362.93 -8.50 -2818.16 18.00 90.00 -1444.17 6 8786.54 90.17 169.73 6361.97 -88.17 -2813.86 18.00 266.00 -1373.67 7 9006.54 89.16 130.14 6363.26 -274.80 -2705.83 18.00 268.50 -1158.06 6 9086.54 90.20 115.78 6363.70 -318.21 -2638.88 18.00 274.00 -1086.37 9 9256.54 92.97 146.27 fi358.90 -428.39 -2512.17 18.00 84.50 -926.66 10 9406.54 79.60 169.63 8368.74 -565.84 -2456.51 18.00 120.00 -780.18 11 9470.00 68.17 169.83 6386.32 X25.75 -2445.76 18.00 180.00 -723.29 LEGEND Project: Kuparuk RiverUnit ANTI-COLLISION SETTINGS COMPANY DETAILS: Conoco Phillips (Alaska)Inc.-Kupi Site: Kuparuk 1E Pad Well: 1 E-15 Interpolation Method: MD, interval: 25.00 Calculation Method: Minimum Curvature Depth Range From: 8200.00 To 9470.00 Error System: ISCWSA Results Limited By: Centre Distance: 1136 43 Scan Method: Trav. Cylinder North Wellbore: 1E-15AL2-02 Reference: Plan 1E-15AL2-02_wp011P,ev.1)(1 E-1511E-15AL2-02) Error Surface: EllipticalConic Plan:1E-15AL2-02_wp01(Rev.1)(1E-15/1E-15 WamingMethod: Rules Based 1 E-15,1 E-15,1 E-15 V2 -1 E-15,1 E-15A,1 E-15AV0 - 1E-15,1E-15AL1,1E-15AL1 VO -* 1 E-15,1 E-15AL2,1 E-15AL2 VO 1E-15,1E-15AL2-01,1E-15AL2-01_wp08 VO -1E-06, 1E-06,1E-06V1 ° 1 E-16,1 E-16,1 E-16 V1 180 Travelling CylinderAzimuth (TFO+AZI) [°] vs Centre to Centre Separation [8 ft/in] . -~ ~~ 19-~6~~ -?~v -09 ~~~ ~ID'a3G ~t'-~S~~Z~~~ :,. ;. n 7ncr~ 1 F-14 11831464 .. ~~ r KRU SFD 0 ~~ ;.:' TRANSMITTAL LETTER CHEC~KJ LIST WELL NAME ~~1~ ~ ~ ` ~ ~~ / ~- ~ _ ~ Development ~~Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~~~ ~ t= t ~~ ,--- POOL: .Lt ~ c..--~ z~~~ ~~ ~.~'~r ~ !/ ~t~>/ J Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore se ent of existing well ~'-~~-' ~ ~ ~ ~:~ ~ /~ f (If last two digits in permit No. 21 a ~'/ ~~~; API No. 50- ~~~} - 7~`7~, -~. API number are ~, ~,;~~,,, ~' should continue to be reported as a function of the between 60-69) ... original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of weld until after (Company 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 ro am. Rev: 1/11/2008 ~'2MI1'„CHECK~.IS~.~Fieltl & Pool KUPARUK RIVER - 49000D _ _ KUPARUK RIVER, KUPARUK f Well Name: KUPARUK RIV-UNIT 1E-15AL2-02 ____Program SER . _ _____ Well bore seg^ PTD#:2100360 Company CONOCOPHILLIPS ALASKA INC _ _ - _ Initial ClasslType _ _.SER I PEND GeoArea 89D ____ Unit 11160 OnfOff Shore On _ Annular Disposal ^ Administration '1 Permit fee attached NA 2 Lease number appropriate- - - - - - - - - - Yes - - - - Top_prod interval and TD i_n ADL 25651 - - - - - 3 Unique well name and number - - Yes ~I4 Well located in a defnedpool Yes - - - - - Kuparuk River Oil. Pool, governed by Conservation Order No. 4320 - - - - I!5 Well located proper distance from drilling unit_boundary- - Yes Conservation Order IJo. 432C contains no spacing restrictions with respect to drilling unit ',6 Well located properdistance from other wells- - - - - - Yes boundaries and no interwell spacing restrictions. Wellbore will be more than_5 miles '7 Sufficient acreage available n_drilling unit... Yes from an external property line where ownership orlan_downership_changes. 8 If deviated, is-we_Ilbore plat included - - - - Yes 9 Operator only affected party Yes 10 Operator has-appropriate-bond in force _ Yes _ - - - - ~!11 Permit can be issued without conservation order Yes - - - - - Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait- - Yes SFD 4/5/2010 !14 Well located within area and strata authorized by Injection Order # (put1O# i n_comments)-(For Yes Area I_njeclion Order No._2B '15 All wells-within 114 mile area of review identified (For service well only)- - Yes KRU 1E-01PB1, KRU 1E-06,_KRU-1E-15 & laterals, KRU 1E-16, KRU 1Er17 '16 Pre-produced injector: duration of pre production Less than 3 months (For service well only) No Well will be flowed back for cl_eanuponly. - '17 Nonconven, gas conforms to AS31,05,030Q.1.A),Q,2.A-D) NA 18 Conductor string provided NA --- - - - - Conductor set in 1 E 15 Engineering 19 Surface casing. protects all known ll$DWs NA - Surface casing set in-1_E-1.5 20 C_M_T vol adequate to circulate on conductor & surf. csg NA- Surface casing cemented to GL in-1 E-15 _ - ~!21 CMT vol adequateto tie-in long string to-surf csg NA_ - - Production casing set in_1E-15 - - - 22 CMT will cover-all known productive horizons No- - OH slotted_liner_planned_ - ',23 Casing designs adequate for C, T, B & permafrost Yes - - ~124 Adequate tankage-or reserve pit Yes Rig equipped with steel pits. 25 If a re-drill, has-a 10-4.03 for abandonment been approved Yes 31.0 023 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues. 27 If dverter required, does it _meet regulations- - - - - - - - NA BOP stack_in placealready. WH in place. Appr Date I,28 Drilling fluid-program schematic & equip list adequate_ Yes Max fm_p_ressure = 4895-psi (14,9 ppg EMW)-Will drill with-10ppg mud using MPD technique._ GLS 4/7/2010 29 BOPEs,_tlo they meet regulation Yes (_Expected formation pressure is_11,5-ppg EMW)_ 30 BOPE_press rating. appropriate; test to-(put prig in comments) Yes MASP= 42.64 psi..,will test BOP_ to 5000 psi - - - - - - - 31 Choke_manifold complies w1APl RP-53 (May 84)_ - - - Yes - - '32 Work will occur without operation shutdown- - - - - - Yes - 33 Is presence of H2S gas_probable Yes H2S on_ 1_E_ pad, Rig has sensors and alarms.- I,34 Mechanical condition of wells within AOR verified (For sernce well only) Yes _ AOR complete . no wells within 114 mde m zone. _ - -- - - JI _ 35 - - - Permit-can be issued w/o hydrogen-sulfide measures - --- No -- - -- Wells on 1E_pad are H2S-bearing._H2S measures required, Geology I~36 Data_presented on potential overpressure zones Yes Expected. reservoirpressure is 11.5 ppg EMW; however, l_E-1-5-was-an injector, so pressures ------ App 37 Seismic analysis-of shallow gas zones _ _ _ _ Nq en_countered_may_reach 15.1 ppg. _Will be drilled using-10,0_ppg mud and managed pre&sur_e_ - _ - SFD 4!5!2010 ~'~38 Seabed condition survey (ifoff-shore) - NA- - drilling technique to keep ECD at about 12,4_ppg. Hazards program-notes potential-for '39 Contact namelphone for weekly-progress reports [exploratory only] - NA- - encountering high-pressure_(15+_ppg)-stringers while drilling, Mitigation_measuresdtscussed. Geologic Date: Engineering Date Public Date An additional A5-sand spoke injector to improve sweep efficiency. Commissioner: Commissioner: Commissioner Q~~O~. ~°'l~'-~a ~'