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208-045
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a(~ S - ©!-~'~ Well History File Identifier Organizing (done) ^ Two-sided III 111111 II II I II III ^ Rescan Needed RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: p~, D /s/ Project Proofing II I II IIII I I III I I III BY: Maria Date: ~0 /s/ Scanning Preparation x 30 = + =TOTAL PAGES ~ ~ (Count does not include cover sheet) /s/ BY: Maria Date:. , ~ Production Scannin 9 III II'lll IIIII II III ~ ~ (Count does i Stage 1 Page Count from Scanned File: nclude cover sheet) ~ Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: a g /D /s/ ~, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked I II I I II II II I IIII II I 10/6/2005 Well History File Cover Page.doc by Terrie Hubble Drilling Technologist Drilling & Wells ~~ y ~. ~fi ~ ,~ Alaska ~, ai! r., ~_ t ~~; June 17, 2008 ~fi~ ,~,, ~~0~.~2ff}d,~~1~/~ ~v: Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-21502-62-00 Direct: (907) 564-4628 Terrie.hubble~bp.com i Permit # 208-045, Kuparuk 3F-16AL1-02 To Whom It May Concern: ~~~~~~, ~i2 S+~ i~%~lll~~~i I~1~1~~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-51 1 1 Please cancel approved Permit to Drill for Kuparuk 3F-16AL1-02, Permit Number 208-045 (50-029-21502-62-00). This particular Permit to Drill is no longer needed. Thank you very much for your assistance in this matter. Sincerely, Terrie Hubble xc: Well Files PDC Gary Eller, ConocoPhillips ALA-7~A ®TI/ CO1~T5ER~ATI011T CO1~II~IISSIOrT Gary Eller CT Drilling Engineer Conoco Phillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 ~` SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ,.I , } ~: ~~Y~r k~M'u~; Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 3F-16AL 1-02 Conoco Philli s Alaska> Inc. Permit No: 208-04 urface cation: 2' FSL, 227' FEL, SEC. 19, T12N, R09E, UM Bottomhole Location: 2949' FSL, 4053' FEL, SEC. 19> T12N, R09E, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 3F-16A, Permit No 196- 151, API 50-029-21502-O1. Injection 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 inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this ? day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of wort ^ Drill ^ Re-Entry 2. Operator Na Conoco Phil 3. Address: c/o P.O. B 4a. Location of Surface: 82' FSL 227' , Top of Proc 3971' FSL, 3 Total DeptF 2949' FSL, 4 4b. Location of Surface: 16. Deviated We t 8. asin 'P' r Hole Ca 4-1/8" 3-3/tE 19. Total Depth MC 8580 Casing`. Conductor / Struc Surface Intermediate Produ i n Liner Liner 3F-16AL1 Liner 3F-16AL1 Perforation Dep 20. Attachment 21. Verbal App 22. I hereby c Printed Na 17tl1y CIICI ~ ~j~g V 1 Vllllllly CIIy111CC1 Si nature Phone 263-4172 Date Prepared By Name/Number: Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill ~ Number: `~' ~ PI Number: 50-029-21502-62-00 Permit Approaval See cover letter for Date: / ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~~ '1.,~~5; ~~Y ~S~ Samples Req'd: axes ~No Mud Log Req'd: ^ Y,es Cr7No HZS Measures: Yes ^ No Directional Su y Req'd: es ^ No Other: ~ M lT ~ A S~v`~~ CC ~, C.~_ ~l.I ~t~~hC W~ `1 ~ t~'~ C'r `°~ S~'~V C~ , APPROVED BY THE COMMISSION Dat ,COMMISSIONER Form 10-401 Revised 12/005 ORIGINAL / ~~~'~~'~" Sub~n Duplicate ~f 3• ~~ '8 U KRU 3F-16A Triple laterals -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling rig will drill three laterals in well KRU 3F-16A using the managed pressure drilling technique. These horizontal laterals will target Kuparuk A2/3 sands to increase injection support in an under- performing fault block to the south. The perforations in the motherbore will remain open to injection. 1. The AL1 lateral will kick off from the motherbore the top of the existing A sand perfs at 8230' MD targeting the A2 Sand to the south. The lateral will be 2270' in length and will be completed with 2'/s" slotted liner to a TD of 10,500' MD. 2. The AL1-O1 lateral will kick off from the AL1 lateral at 10,025' MD and will target the A3 Sand. The AL1-O1 lateral will be 675' in length and will be completed with 2'/8" slotted liner to a TD of 10,700' MD. 3. The final lateral, AL1-02, will kick off from the AL1 lateral at 9600' MD and will also target the A3 Sands. The ALl-02 lateral will be 700' in length and will be completed with 2'18" and 3-3/16" slotted liner to a TD of 10,300' MD. Only this final drilled lateral will remain accessible through-tubing. CTD Drill and Complete 3F-16A program: Apri12008 Pre-Rig Work 1. Obtain updated static BHP on A sand. 2. Test Packoffs - T & IC. 3. Positive pressure and drawdown tests on MV and SV. 4. MIT-IA, MIT-OA. 5. Slickline tag fill and drift 4'/i" tubing. 6. Run caliper log from 8300' to surface 7. Drill out the 3.75" DB nipple at 7846' MD to 3.80" 8. Set aflow-through monobore whipstock for 4'/z" liner whipstock at 8230' MD with high-side orientation. Rig Work 1. 2. 4. 3F-16AL1-02 Lateral a. Dri113.75" x 4'/8" bi-center horizontal AL1-02 lateral in the A3 sand from 9600' to TD at 10,300' MD. °-~ b. Kill well. Run 2'/8" and 3-3/16" slotted liner from TD up inside the motherbore at 8200' 5. Freeze protect. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Obtain static BHP 2. Produce well to flowback tanks to clean up. 3. Return well to injection. MIlZU Nordic Rig #2 using 23/8" coil tubing. NU 7-1/16" BOPE, test. 3F-16AL1 Lateral a. Mill 3.80" window with high-side orientation. The planned KOP is at 8230' MD at the top of the A sand perfs. b. Dri113.75" x 4'/s" bi-center lateral turning south to 8650' MD. c. Continue drilling the horizontal lateral south in the A2 sand with a 3.70" conventional bit to TD of 10,500' MD. d. Kill well. Run 2'/s" slotted liner with aluminum billet from TD up to X10,025' MD. 3F-16AL1-O1 Lateral a. Dri113.75" x 4'/8" bi-center horizontal AL1-O1 lateral in the A3 sand from 10,025' to TD at 10,700' MD. b. Kill well. Run 2'/8" slotted liner with aluminum billet from TD un to t9600,'~p. Page 1 of 3 March 24, 2008, FINAL • KRU 3F-16A Triple Laterals -Coiled Tubing Drilling Mud Program: • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud 010.0 ppg) for drilling operations. Since there is no SCSSV installed in 3F-16A, we will have to kill the. well to deploy 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: • 3F-16AL1: 2'/8", 6.4#, L-80, STL slotted liner from 10,025' MD to 10,500' MD • 3F-16AL1-Ol: 2'/8", 6.4#, L-80, STL slotted liner from 9600' MD to 10,700' MD • 3F-16AL1-02: 2'/:", 6.4#, L-80, STL slotted liner from 8650' MD to 10,300' MD, and 3-3/16", 6.2#, L-80, TC-II pre-drilled liner from 8200' to 8650' MD. Existing Casing/Liner Information Surface: 95/8", J-55, 36 ppf Production: 7", J-55, 26 ppf Liner: 4%", L-80, 12.6 ppf Burst 3520 psi; Collapse 2020 psi. Burst 4980 psi; Collapse 4320 psi Burst 8430 psi; Collapse 7500 psi Well Control: • Two well bore volumes 0250 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 23/8" 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 3349 psi assuming a gas gradient to surface and the most recent measured pressure in 3F-16A (i.e. 3955 psi at 6065' TVD in Feb-08). • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3F-16AL1: 11,500' to property line, 1470' to well 3F-15 • 3F-16AL1-O1: 11,500' to property line, 1470' to we113F-15 • 3F-16AL1-02: 11,500' to property line, 1900' to well 3G-03 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static pressure measured in 3F-16A is 3955 psi on 2/18/08 (i.e. 12.5 ppg EMW at 6065' TVD). Prior to that, the survey taken in December 2007 showed that reservoir pressure was 4006 psi (i.e. 12.8 ppg EMW). Page 2 of 3 March 24, 2008, FINAL KRU 3f=-16A Triple Laterals -Coiled Tubing Drilling Hazards • The static formation pressure in 3F-16 is elevated. Expect to encounter decreasing pressure as the laterals are drilled away from the 3F-16A motherbore. 3F-16, 3F-15, and 3A-02 injectors have been shut in to de-pressure the area prior to drilling these laterals. Formate-base completion brine (13.1 ppg maximum) will likely be required to kill the well to run slotted liners. Some applied backpressure will be needed to balance formation pressure during drilling if 10.0 ppg solids-free mud is used. • There is some risk of collision with the original, abandoned 3F-16 wellbore. Plan #4 for the Ll lateral passes within 73' of 3F-16 at 9325' MD. A `Tolerable Collision Risk' worksheet has been completed. The only risk associated with colliding with this wellbore will be in lost time for sidetracking; there is no additional HSE risk associated with a collision of this abandoned well. • We113F-16A has been a miscible gas injector as recently as September 2007. Any kicks would be expected to contain a significant fraction of gas. • Well 3F-16A is an injection well so it has no HZS present. Wells 3F-17 and 3F-15 are adjacent to 3F-16A. 3F-17 has 115 ppm HZS as measured on 1/7/08, and 3F-15 another injection well with no HZS present. The maximum HZS level on the 3F pad is 280 ppm from we113F-10. 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 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 3" BHA will be accomplished utilizing the variable pipe rams and 3" slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. There is no SCSSV in we113F-16A, so the well will 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: • Estimated reservoir pressure: 3955 psi at 8265' MD (6065' TVD), or 12.5 ppg EMW. • Expected annular friction losses while circulating: 537 psi (assuming friction of 65 psi/1000 ft). • Planned mud density: 10.0 ppg equates to 3154 psi hydrostatic bottom hole pressure at 6065' TVD • While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 3691 psi or 11.7 ppg EMW without holding any additional surface pressure. Applied back-pressure of 300 psi will be required to overbalance formation pressure while circulating. • When circulation is stopped, it is anticipated that 800 psi of surface pressure shall have to be applied to balance reservoir pressure and maintain the same borehole pressure as during drilling operations. Page 3 of 3 March 24, 2008, FINAL • • ConocoPhillips Alaska, Inc. KRU 3F-16A 3F-16A API: 500292150201 Well T e: INJ An le TS: 40 d 7990 SSSV Type: NIPPLE Orig Com letion: 9/23/1996 Angle @ TD: 42 deg @ 8580 Annular Fluid: Last W/O: Rev Reason: TAG FILL NIP(s1o-511, Reference L Ref Lo Date: Last U ate: 8/7/2006 oD:a.SOO> Last Ta : 8299 TD: 8580 ftKB TUBING Last Ta Date: 7/28/2006 Max Hole An le: 54 d 3495 (0-6838, oD:a.SOO Casin Strin -CONDUCTO R , ID:3.933) ~ Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Casin Strin -SURFACE Descri lion Size To Bottom TVD Wt Grade Thread SUR. CASING 9.625 0 3884 3045 36.00 J-55 Casin Strin -PRODUCTIO N Nordic SIDETRACK 7015' Descri lion Size To Bottom ND Wt Grade Thread SLEEVE PROD. CASING 7.000 0 7015 5130 26.00 J-55 (6767-6768, oD:a SOO> Casin Strin -LINER . PROD. Descri lion Size To Bottom TVD Wt Grade Thread CASING LINER 4.500 6831 8580 8580 12.60 L-80 (o-7o1s, OD:7 000 Tubin Strin -TUBING . , wr.2s.oo> Size To Bottom ND Wt Grade Thread 4.500 0 6838 5005 12.75 L-80 ABM-EUE Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 8230 - 8246 6039 - 6051 A-3 16 4 11/12/199 6 I PERF HSD Perf Gun, 180 deg. phasing; Oriented (+!-) 90 PKR (sala-sa1s, de . F/ lowsid OD:6.151) _ i 8266 - 8300 6066 - 6092 A-2 34 4 11/12/199 6 IPERF HSD Perf Gun, 180 deg. phasing; Oriented (+/-) 90 d . F/ lowsid Other lu s e ui .etc. -JEWELRY De th ND T e Descri lion ID 510 510 NIP Camco'DB' Ni le 3.875 6767 4955 SLEEVE Baker CMU Slidin Sleeve; CLOSED 9/23/96 3.812 6814 4988 PKR Baker'SABL-3' 3.875 NIP seza saes 6828 4998 NIP Otis 'X' Ni le 3.813 - , ( oD:a.SOO> 6829 4999 SEAL Baker Locator SEAL ASSEMBLY 3.937 SEAL 6841 5007 HANGER BKER CMC MECHANICAL LINER HANGER 4.313 (sees-sa3o, 7846 5745 NIP Camco'DB' 3.750 OD:4.500) HANGER (6841-6842, OD:5.000) LINER (6831-8580, OD:4.500, W 1:12.60) NIP (7846-7847, OD:3.833) Perf (8230-8246) - Perf (8266-8300) _ - - - KRU 3F-16AL1 /L1-01 /L1-02 Injector Proposed CTD Completion G. 4-1/2" Camco DB nipple, 3.875" min ID at 510' MD 9-5/8" 36X JSS ~ 3884' F. 4-1/2" Baker CMU sliding sleeve @ 6767' MD w/ 3.812" min ID 7" 26ft J-55 ~ 7015' MD 3-3116" liner top +/-8200' MD Window in 4-1 /2" KOP at 8230' MD --•~ A3/A2 sand perfs 8230' - 8246' MD 8662' - 8808' MD 4-112" 12.6N L-80 ~ 8580 MD' ConocoPhilli s p Alaska, Inc. E. Baker `BABE-3' packer at 6814' MD D. 4-'/z" Otis "X" nipple, 3.812" min ID at 6828' MD C. Baker seal assembly at 6829' MD 2-7/8" slotted liner, 12 B. Baker CMC liner hanger at 6841' MD slots/ft, 1/8" slot width A. 4-'/z" Camco DB nipple, 3.75" min ID at 7846' MD i~~i~~~\ (milled out to 3.80" ID) ° 4-1/8" hole / ° ° All laterals ° ~ ° 3F-16AL1-02 A3 Lateral, ~ TD @ 10,300' MD ~ ~~ / / ° ° _ _~ - - - ° °~t ° --. , ~ ~, ~ , ~% 3-3/16" pre-drilled !bs ~~f liner to _ 8650' and ~0~, hr Fill ~ ~' Aluminum billet KOP @ .... 9600' MD •I 3F-16AL1-01 A3 Lateral, TD @ 10,700' MD --- - i - - - - -u~ 3F-16AL1 A2 Lateral, TD @ 10,500' MD Aluminum billet KOP @ 10025' MD March 20, 2008 • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3F Pad 3F-16 Plan 4, 3F-16AL1-02 Plan: Plan #4 Baker Hughes INTEQ Planning Repo 17 March, 2008 .~~~ BAKER FB~~~S INTEQ • ConocoPhillips sa~R ~ Baker Hughes INTEQ Planning Report ~~~ INTEQ Company: ConocoPhillips(Alaska) Ine. Local Co-ordinate Referents: Well 3F-16 Pro)ect: KuparukRiver Unit TVD Reference: 3F-16A @ 88.OOft (3F-16A) Site: Kuparuk 3F Pad MD Reference: 3F-16A Q 88.OOft (3F-16A) Well: 3F-16 North Reference: True Wellbore: Plan 4, 3F-16AC1-02 Survey Calculation Method: M(nimum Curvature Design: Plan #4 Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact 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 3F Pad Site Position: Northing: 5,985,734.46ft Latitude: 70° 22' 20.081 N From: Map Easting: 508,662.33ft Longitude: 149° 55' 46.550 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.07 ° Well 3F-16 Well Position +N/-S 0.00 ft Northing: 5,985,904.95 ft ~ Latitude: 70° 22' 21.762 N +EI-W 0.00 ft Easting: 508,272.74 ft ~ Longitude: 149° 55' 57.943 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore Plan 4, 3F-16AL1-02 Magnetics Model Name Sample Date Declination Dip Angle Fleld Strength BGGM2007 3/12/2008 17.70 79.75 57,268 Design Pian #4 Audit Notes: Version: Phase: PLAN Tle On Depth: 9,600.00 Vertical Section: Depth From (TVD) +NIS +EI-W Direction tft) (ft) lit) (°) 88.00 0.00 0.00 183.00 Survey Tool Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 95.00 7,000.00 3F-16 (3F-16) GCT-MS Schlumberger GCT multishot 7,020.00 8,147.53 3F-16A (3F-16A) MWD MWD -Standard 8,147.53 9,600.00 Plan #4 (Plan 4, 3F-16AL1) MWD MWD -Standard 9,600.00 10,300.00 Plan #4 (Plan 4, 3F-16AL1-02) MWD MWD -Standard Planned Survey MD Inc Azi NDSS NIS E/W Northing Easting (ft) (°) l°) (ft) (ft) (ft) fft) (ft) 9,600.00 98.43 198.84 5,914.98 3,530.72 -3,686.33 5,989,431.24 504,582.88 KOP -Build DLS 15 9,620.00 101.43 198.84 5,911.53 3,512.07 -3,692.69 5,989,412.59 504,576.54 Start DLS 15. TFO 315. 9,640.00 103.54 196.65 5,907.20 3,493.48 -3,698.64 5,989,393.99 504,570.61 Start DLS 15. TFO 240. 9,690.00 99.71 190.07 5,897.12 3,445.86 -3,709.93 5,989,346.37 504,559.37 Start DLS 15. TFO 274. 9,700.00 99.82 188.55 5,895.42 3,436.14 -3,711.53 5,989,336.64 504,557.79 3/17/2008 3:O1:lOPM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Baker Hughes INTEQ Planning Report Company: Protect: Site: Well: Wellbore: Design: ConocoPhiNips(AYaska) Ino. Local Co-ordinate Reference: Kuparuk River Unit TVD Reference: Kuparuk 3F Pad MD Reference: 3F-16 North Referent®: Plan 4, 3F-16AL1-02 Survey Calculation Method: Plan !f4 Database: • ~.. s~s INTEQ Web 3F-16 3F-16A ~ 88 OOft (3F-16A) 3F-16A'@ 88.OOFt (3F-16A) True Minimum Curvature EDMv16 Prod Planned Survey MD Inc Azf TVDSS NIS FJW Northing Fasting (ft) (°) (°) (ftl (ft) (ft) (ft) (ft) 9,800.00 100.45 173.33 5,877.73 3,338.02 -3,713.15 5,989,238.53 504,556.28 9,815.00 100.48 171.04 5,875.01 3,323.41 -3,711.14 5,989,223.92 504,558.30 Start DLS 15. TFO 90, 9,900.00 100.22 184.00 5,859.67 3,240.06 -3,707.53 5,989,140.58 504,562.00 9,940.00 99.92 190.08 5,852.68 3,200.99 -3,712.36 5,989,101.52 504,557.22 Start1)LS 15. TFO 105.8 10,000.00 97.36 198.81 5,843.65 3,143.61 -3,727.15 5,989,044.13 504,542.49 10,100.00 92.77 213.15 5,834.78 3,054.35 -3,770.70 5,988,954.83 504,499.04 10,105.00 92.53 213.86 5,834.54 3,050.19 -3,773.46 5,988,950.66 504,496.29 Start DLS 15. TFO 270. 10,200.00 92.45 199.60 5,830.40 2,965.64 -3,816.04 5,988,866.07 504,453.80 10,300.00 92.21 184.59 5,826.31 I 2,868.22 -3,836.92 5,988,768.64 504,433.04 TD at 10300. - 2 7l8" 3/17/2008 3:01: IOPM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips TYPe Taryal Idt Ongn TYPa !LS FiW FmmlVp User Na Target IFeeelarN) 183.00 Sk4 D00 0.00 0.00 3F1 W ~ 08.00013E-18F) RryeU: KOOaltk plaer urw SNe: IeYW ]f M ww: 3F-1fi WWpo9e: Mn43F-talLL1N P1 rva~w.l.w.. v,. ,. 11 Inn1.l nan:RnN13P-twin ~, 3c-tfilutezl r. ~n MU. wla u~ WELL OETILLS: 3F-10 H03 aEJ.W fi0r011rq GreurM LevN0.00 Eaatlrlp LatllWde 1m0109tls Slb 0.00 O.OR9fi8fi6fi.18 1N030190T0' TT ]O.fi91 Mt9' 58.9.10] W EOTIDN OETRIL6 MO Rzl " ND ~W-S ~EI~Yi Rp TFece V3ec Target .a ND MD Rmd ~ 9800.00 A0d3 tNW 914 BB 3530.)2 3880.33 000 0.00 ~]]Y2.B5 N 960000 KOP 4 01 t3 IN 89 591153 961000 103N 9685 590).20 8890.00 IB0.0] 589).12 369169 1500 0.00 331900 319318 1500 ]1500 3485 t2 -])09.93 1500 24000 J2989B 6 1 1.53 862000 San[ 061000 Sen[ 509] 12 9a]0.00 Su 9815.00 IOpaO 58)5.01 940.00 99.92 52.E8 J323 J 1 2)400 - 2463 310099 -3)1238 1500 58)5.01 981500 San[ 8990.00 San[ 82.53 21386 10300.00 91.11 IN 59 SBM 31 ~])13A8 1500 10600 - 208812 ]8]692 15.00 2]0.00 -2003 JB 834.54 10105.00 San[ 82831 10]00.00 iD al ~~~~~p~~ 3F-16. 3F-16, 3F-16 VO I.IA RJIK~~~~iP$ 3F~16. 3F-16A. 3F-164 V0 3F-16. Plan 4, 3F-16FL1. Plan N 3F-16. Plan 0. 3F~16K1-01, P6n - - - Contact Information: -- _ - Bill Michaelson : Cell: 907-301-3570 Email: bill.michaalson@intE Kuparuk CTD BOP Configuration for Managed Pressure Drilling 2'/s" CT Well I 3F-16A Floor I Lubricator ID = 6.375" with 6" Otis Unions 1 7 1/16" 5000 psi, RX-46 7 1/16" 5000 psi RX-46 Kill Line 1 L_ 6" 5000 psi , RX-24 Tree Size 4-1/16", 5M 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee SSV Master Valve Base Flan e Page 1 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ ~ /~~ L ~~ ~'~" PTD# ~~ O ~SI Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well // > ~'1'~ POOL: ~'r;~~ ~' ~c G~' ~~/G{~ FIELD: c,~.fc. - ~ -~-._._,._ _ ~, ~!~'' 0./~c~/ 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 segment of existing well 1(:i~li~. ~~ l~ ~ , di i i If l ^ g ts n ( ast two p 50-OL - 2/S7~Z -~ API No it N ~/ API number are between 60-69) . . erm o. , Production should continue to be reported as a function of the 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 well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comuany Name) must contact the Commission to obtain advance approval of such water wel! testing ro ram. Rev: 1 / 11 /2008 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 3F-16AL1-02 Program SER Weil bore sag ~ PTD#:2080450 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER I PEND GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached__---_-_________________________________ _N_It__ ______.-_ -_.-- -------------------------------------------------------- 2 lease number appropriate__--_--_-..____________________________ Yes-- -----Entirewellwill!ieJnAQL026635._-___-__________-___-_--__--__----_-_--_____-_-- 3 Uniquewell_nameandnumbe[________________________---_._-.-- Yes-- -------------_.-- 4 Wall locaked in-adefinadpopl- - _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . - KUPARUK RIyER,_KUPARUK RV Qlt. ~ 490.1QQ, governed by Conservation Order Ng. 4320.- _ - - - - - - _ - - _ - 5 !Neil located proper diatancefrom drilling unitboundary- - - - _ _ _ _ _ - - - Yes Conservation Order No. 4320 Contains nC spacing restrictions with respecttg drilling unit boundaries. - - _ - - _ _ 6 Nletl-Ipcated p[oper diatanGe from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conservation Orde[ NC. 4$2C has-na Jntarw@II_spaGinglestricfipns, - _ _ _ _ _ _ _ _ _ - - _ _ - _ _ _ - _ _ _ _ _ _ - _ - 7 Sufficient acreage available in drilling unit_ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ -Conservation Orde[ No. 4320 has-no Jntenvell-spacing-restrictions, Wellbor-s wilt ke_more than 500' from - _ _ _ _ _ 8 If deviated, is-wellbore plat_lncluded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - - - - an exkernal Rrgperty line:whete ownership or-landgwnsrship changes. _ - - - _ _ _ _ - _ - _ - - - - - _ _ _ - _ _ _ _ _ 9 OperatoroniyaffeCtedDar4'------ - -- ~- ----- -- ----- -- Yes-- ---- -- -- ----- --- ---------- ------------ --- -- --- -- --- ----- 10 Ope[atorbas_aPPropriatebondinforCa-- --- -- -- -- - Yes. ------ -- - ----------------- - -- -- - - - - -- 11 Pe[m+tcanbeisauedw~hauiconsarvationorder---------------------------- Yes-- ------------------.---------....-------------.------------------------- Appr Date 12 Pe[mitGanboissuedwlthouladminist[aliveapp[oval------------------------- Yes-- ---.-.-.-----.-------------------------.---.--------------------____-- SFD 3127!2008 13 CanpermiibeaAProvedbefore1fi•daywait-___------------------------- Yea-- -------------------------------------------------------------------____-- 14 VYeIIJocated within area and_atrata authorized by_ Injection Qrde[ # (putlQ# in-comments) (For_ Yes _ _ _ - _ _ _ Area Injection OrdarNo._2B - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - - . _ _ - - - 15 Allwails-within 114.roke_araa_of[eviewidentified{F9[servicewell 9nly)_______________ Yes__ _____3F•16, whi~hhast~eenPB,A'd.-.--._..--___-____-__--___._____--__-__-_____._.. 16 Pte•prgducedinjector,durationofpraproduGtionlessthan3months-(ForervicewellaNy)__ JVA__ ___________________.__-_--____-__-_______-__--..-________.-..--_-._-._ 17 NonCOnven.gas_conform®toAS31,05.03QQ,t.A),142.A•D} -- -- -------- -KA--- -------- ----- -- -- -- - - -- -- -- -- -- ----- -- Englnaering 18 Conduciorot[ing.Provided__________________________--__--______-_ _NA--- -----ConduCtorsetln3F-16(185.294).----------,------------------------------------- 19 Su[fececaaingRrotactsallknownUSRWa------------------------------ -NA--- -----AllaquifersexemPted,40CFR_147.1Q2(b)(3},----------------------------------------- 2D CMT-v_oladequate-tCS~rcutate_on-c~nduCtpr&s4rf_csg______________________ NA--- --_--SurfaCBCasingsetin3F-16,---_____._____-__________--__--__--__-__-________ 21 CMT_voladequate_totie-in long siring to surf cag_________________-.___-- .NA.-- -.--Production_Casingsei in-3F-18,-_---_---_---_.-_--_--_--__--_-___--_---_-- 22 CMT_wiilcoverallknown-praduCtivabarizons----------------------------- Yes-- ---._..---.----.---------------------------------.----..--------------- 23 Cesingdesgnsadequatefo[C,_T,B&pe-rmafroat_____---._________________ Yes-- -------------------..--------------------------------------------__ _-- 24 Adequate tankage_or reserve pit _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yea _ _ _ _ _ _ _ Rig equipped with ales! pits, Noreseroe pit planned._ All waste-to approved disposal well(s). _ _ _ _ - _ _ _ _ _ _ _ _ 25 If.are~d[ill,has-a10.403torabandonmentbeenaPRroved -- ------ --- - Ka - - -~ - - -- ---- -------------- ---- - -- -- -- - ----- - ~ 26 Adequate-wehkora aeparaUcn_propoaed_ _ _ _ _ _ _ _ _ _ _ ___ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ Proximityanalysis perfo[med, Nearestsegment is 3F•16AL1 and paths-diverge, - - - - - - _ _ _ _ _ - _ _ _ _ _ _ . _ 27 Jfdlverter_r@quUed,dQesit.atestregrllations------------------------------- -NA--- ---.-@QPstaCkwill already-be in place.--------,-------------------------------------- Appr Date 28 DdUingfluid-Program schematic.& aqulpJisi adequate- - - - - - - - - - - -- - - - - - - Yes _ _ _ _ _ - _ Maximum expected fo[maiton Rressu[e 12.6 EMW.-Well will bedrilled withmanaged-Pressure and 10,Q Rpg flpid,_ TE 41412008 29 BQPjs,_dotheymeetregulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - - _ - _ . _ 2 wellborevolumes-of KW flutd_will ke-available inKupar~k Field during drilling ope[ations.- - - - - - _ - - - - - - 30 BOPS-press racing approp[iate; test to-{put pace in ccmmenis)_ . - _ - . _ _ _ _ _ _ _ - _ _ Yes _ _ _ _ _ _ _ MASP calculated ai3349psi, 4000-psi_EOP testplanned_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ - _ 31 Choke.manifokicompJieswlAPt-RP•43(MaY$4}- --------- --- - ---- --- Yes --- - - -- -- -- -------------- --- -- -- - - - -- -------- 32 WorkwiiloCCU[withouioperationshutdown_----------------------------- Yes- ------------------------------.----.-------------------------------____-- 33 la presenCeof H2S gas Rrobabie_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - _ - _ H2S is repg[ted-at 3F pad. Mud should_preclude H2S cn [ig. ,Rig has sensors_andalarms, - - - _ - - - _ - - _ - - - 34 _Mechanicatc9ndftion of wells within AQR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ No known integrity issue fl 3F•16A. This segment departs in Kuparuk-reservoir._ No issues identified. _ .. _ - - _ Geology 35 Pe[mitcan be issued wlo hyd[ogen-sulfide measures _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ yVelis-on 3F,Pad p[oduce between 60 and 275 ppm H25. _H2S mQniiors will be used, - - _ _ _ _ _ - - _ _ _ _ _ - - _ 36 Datapreserled on potential overRressurezones - - - - - - - - - - - - - - - - - - - - ---- - - - - Yes . Expected resenroirpressure is 12.8 ppg EMIN, INih be drUled wish-10A_ppg usingmanaged-Pressure _ - - - _ - - _ Appr Date 37 Seismic analysisofshallowgaazonQS__________________________________ NA-- -___drillingtechniques.,_.-------._-___- --------------------------------------- SFD 3!27/2008 38 Beaked-r~gndition survey_(if off-shoe) - - - - - - - - - - - - - _ . _ - - _ _ - - _ _ - - _ _ _ _ _ _ _ NA_ _ _ _ - 39 ContaCtnamelphoneforweekly_progressrepcrts-(exploratoryonly]--_--_---_--_-. .NA- -_-_________________________________--__-__-_-_-._--______-- Geologic Engineering Public Date Date Daie: Spoke injector to be drilled from the KRU 3F•16AL1 lateral. Commissioner Commissioner Commissioner:
