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208-044
• 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. ©g - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III II~IIIII III II III ^ Rescan Needed RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: o !s/ Pro "ect Proofin II I II'I II I I III I I III I 9 BY: ~ Maria Date: ~~ /s/ Scanning Preparation BY: Maria Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cov sheet) Pa a Count Matches Number in Scannin Preparation: YES NO 9 g BY: Maria Date: ~ ~i/ J' O /s/ Y r 1 Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO 1 BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III x 30 = ~ ~ + I ~ =TOTAL PAGES (Count does not include cover sheet) Date: /s/ IIIIIIIIIIIIII IIIII ReScanned BY: Maria Date: /s/ Comments about this file: o~a„~~~k,a iuuiiiuiiimui 10/6/2005 WeII History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080440 Well Name/No. KUPARUK RIV UNIT 3F-16AL1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21502-61-00 MD 10608 TVD 5980 Completion Date 5/20/2008 Completi on Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Sampies No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, RES, GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Da Digital Dataset Log Log Run Interval OH / T e Med/Frmt umber Name Scale Media No Start Stop CH Received Comments ED- D Asc Di~r ctional Survey 0 10608 Open 6/30/2008 ~ D C Lis 18905vfnduction/Resistivity 7844 10608 Open 11/6/2009 EWR logs in PDF, CGM and EMF graphics og Induction/Resistivity 5 Col 8713 10608 Open 11/6/2009 MD MPR, GR og Induction/Resistivity 5 Col 8713 10608 Open 11/6/2009 TVD MPR, GR ~- - Well Cores/Samples Infonnation: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? Chi s Received? ~'~hfV~-~ Formation Tops ~ N p Analysis ~ Received? Comments: • DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080440 Well Name/No. KUPARUK RIV UNIT 3F-16AL1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21502-61-00 MD 10608 TVD 5980 Completion Date 5/20/2008 Completion Status WAGIN Current Status WAGIN r_ ~ UIC Y Compliance Reviewed By: _ Date: ~~% a~x.il ~ r +~ ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk"/ 333 West 7th Ave, Suite 100 in lieu of sepia"'" Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, M633 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia"* Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS ~~~~~~~~ ~~~~~ ~~ ~~ . ~ _s NOV ~ ~ 2000 ~tiC~i~r~C .. WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~4~~ a~ Cid ~ C~4~ ~ons~ COm~i~siora STATE OF ALASKA 1T ALASKA~L AND GAS CONSERVATION COMSION ~ , ~~ 1 3 2008 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: I1C~ pC~?°3t~~ 20AAC 25.,05 2oAAC zs.,,o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One ®Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Ab 12. Permit to Drill Number Conoco Phillips Alaska Inc. 5/20/2008 208-044 - 3. Address: 6. Date Spuddec/~ 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 5/52008 ~ 50-029-21502-61-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 5/19/2008' Kuparuk 3F-16AL1-01 FSL, 227 FEL, SEC. 19, T12N, R09E, UM 82 Top of Productive Horizon: 8. KB (ft above MSL): 88' 15. Field /Pool(s): , 4300' FSL, 3451' FEL, SEC. 19, T12N, R09E, UM Ground (ft MSL): Kuparuk River Unit /Kuparuk Total Depth: 9. Plug Back Depth (MD+TVD) River Pool 2851' FSL, 4034' FEL, SEC. 19, T12N, R09E, UM 10608' 5980' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 508273 y- 5985905 Zone- ASP4 10608' 5980' ADL 025632 TPI: x- 505029 y- 5990120 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 504453 y- 5988671 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL (Approx.) 1465 21. Logs Obtained (List all logs Here and submit electronic. anr} nrinf r• infnrma}inn ar 20 AAC 25.071): ' MWD DIR, RES, GR , h/~i/6oy ~p~~a~~o s~~~5ve~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 115' Surface 115' 24" 328 sx Arcticset II 9-5/8" 36# J-55 Surface 3884' Surface 3047' 12-1/4" 1125 sx PF'E' 425 sx Class'G' 7" 26# J-55 Surface 7015' Surface 5132' 8-1 /2" 250 sx Class 'G' 180 sx PF 'C' 4-112" 12.6# L-80 6832' 5002' 6064' 6-1/8" 250 sx Class 'G' 2-7l8" 6.16# L-80 8206' 10608' 6020' 5980' 4-1/8" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Slotted Section Note: 4-1/2", 12.75#, L-80 6838' 6814' MD TVD MD TVD 8525' - 10573' 6095' - 5982' Only Well Branch CEMENT SQUEEZE, ETC. ACID FRACTURE !25 3F-16AL1-01 , , . IS Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Accessible 2200' Freeze Protect w/ 50 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 3, 2008 Water Injection Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. _. ~ Ai~i.4`9~ION None S-o~ ,. ~~ ~u~, ~ ~ zoos 1 Form 10-407 Revised 02/2007 ;' S ~""~ ~ ~ ~ ~f C ~ TINUED ON REVERSE SIDE f~ r"~ /~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested . ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit P erm afrost Base detailed test information per 20 AAC 25.071. ' ~ ~ ~1Z Top Kuparuk A2 (Inverted) 8809' 6042' None Base Kuparuk A3 e B Kuparuk A3 / 9608' 6015' Top Kuparuk A2 Top Kuparuk A2 / 10062' 5989' `~ Base Kuparuk A3 Base Kuparuk A3 / 10372' 5980' j Top Kuparuk A2 Formation at Total Depth (Name): Top Kuparuk A2 10372' 5980' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Q Si ned ~ ~ O ~~ / ~ g Title Drilling Technologist Date Terrie Hubble O r Kuparuk 3F-16AL1-01 208-044 Prepared By Name/Number.~ Terrie Hubble, 564-4628 W211 Number Drilling Engineer: Gary Eller, 263-4172 (Office) Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • BP AMERICA Page 10 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours i Task Code I NPT ' Phase Description of Operations 5/12/2008 18:40 - 18:50 0.17 CASE P LNR1 Flow check well. 18:50 - 19:15 0.42 CASE P LNR1 Pop off well. PU on BHA to confirm liner is gone. Blow down BHA w/air. BHA is covered in heavy paraffin. Remove debris from inside agitator (2 large cement chunks) from last bit run, oil same. 19:15 - 21:45 2.50 STKOH P PROD2 LD BHI tools on catwalk. C/O o-rings on LOC. Reconfigure tool .~~ _ ~ C. ~~ ~` ~ ~ tj', .,_ ~/ ~ string for the addition of HOT, test same. MU 3.75" STR bit to ` motor & checks, scribe same. PJSM regarding MU BHA & _ i `_ ` /® 1'~ ~'~ ^ ~ ~~ ~~~~ swapping well over to flo-pro. MU BHI tools to motor. PU . injector, check CTC & replace grub screws oh CTC, pull test same to 35k. Stab coil onto tools. Power up & test tools. Set depths. 21:45 - 23:10 1.42 STKOH P PROD2 RIH. MU 40bb1 hi-vis flo-pro pill. 23:10 - 23:30 0.33 STKOH P PROD2 Open EDC, start pumping hi-vis flo-pro pill & log down for tie-in at 7900ft (-23ft corr. 23:30 - 23:40 0.17 STKOH P PROD2 RIH to 8200ft. 23:40 - 00:00 0.33 STKOH P PROD2 Swap well to 10ppg Flo-Pro & recover 13ppg K-Formate KW F. Start out at 1.Obpm/2060psi while maintain 4000 psi dhp to avoid excessive loss of Formate mud, displace CT volume at this rate. Increased rate and apply WHP to keep dhp at 4000 psi. 5/13/2008 00:00 - 00:35 0.58 STKOH P PROD2 Continue to swap well to 10ppg Flo-Pro holding 4000 dhp. Recovered 235bb1s. Close EDC. - 01:00 0.42 STKOH P PROD2 Wi er to TD. Li htl d to TOL at 8713ft. 01:00 - 02:00 1.00 STKOH P PROD2 Time drill HS sidetrack off billet from 8712ft. 3790 psi fs at 2.34 in/out. i ` ` ~ ~,'~ ~ 50-100 psi mtr wrk. O.10k DHWOB. 7k SWOB WHP/BHP/ECD: 280/4035/12.98 ppg. INClTF: 99.5/HS. Stalled at 8712.3ft Drill to 8712.6' PVT 141 Stacking out & no WOB. PU & start over. 02:00 - 04:40 2.67 STKOH P PROD2 Time drill HS sidetrack off billet from 8712.3ft. 3800 psi fs at 2.34 in/out. 50-100 psi mtr wrk. 0.8-1.5K DHWOB. 7k SWOB WHP/BHP/ECD: 370/4009/12.90 ppg. INClTF: 99.5/HS. PVT 116 Still stacking, yo-yo pumps to get WOB- worked. Time drill ahead keeping applied WOB. At 8714ft drill at constant 0.1ft/min. WOB dropped at 8716.4ft (off billet), increase ROP to 0.2fUmin to 8718ft. Increase ROP to 30ft/min from 8718ft to 8733ft. Drill to 8733ft. 04:40 - 05:50 1.17 STKOH P PROD2 Backream sidetrack area twice at 45 degrees L & R of drilled TF. Turn off pumps and RIH dry from 8700ft to 8732ft -clean. 05:50 - 06:20 0.50 STKOH P PROD2 W iper to window. Open EDC 06:20 - 07:45 1.42 STKOH P PROD2 POH circ thru EDC 2.43/3450 following pressure schedule 07:45 - 08:15 0.50 STKOH P PROD2 Work to clear Swaco choke of aluminum (won't close) 08:15 - 10:15 2.00 STKOH P PROD2 Pressure undeploy using MPD loop w/ 900 psi LD drilling BHA 10:15 - 13:00 2.75 DRILL P PROD2 Cut off CTC. Pump slack back w/ mud w/ pump #1. Pump #2 is on MPD loop. Cut CT back 90' and find wire. Cut off a total of 500' to move wear spot Install CTC. PT 43K 13:00 - 14:25 1.42 DRILL P PROD2 Head up BHI. PT 4000 Printed: 6/16/2008 2:07:41 PM BP AMERICA Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To 'Hours Task Code NPT 5/13/2008 14:25 - 14:35 0.17 DRILL P 14:35 - 17:50 3.25 DRILL P Start: 4/28/2008 Rig Release: 5/20/2008 Rig Number: Page 11 of 17 Spud Date: 4/1 /1988 End: 5/20/2008 Phase Description of Operations PROD2 PROD2 17:50 - 19:25 1.58 DRILL P PROD2 19:25 - 20:30 1.08 DRILL P PROD2 20:30 - 22:00 1.50 DRILL N DFAL PROD2 22:00 - 00:00 2.00 DRILL N DFAL PROD2 5/14/2008 00:00 - 01:45 1.75 DRILL N DFAL PROD2 01:45 - 03:10 1.42 DRILL N DFAL PROD2 03:10 - 03:30 0.33 DRILL N DFAL PROD2 03:30 - 04:10 0.67 DRILL P PROD2 04:10 - 07:00 2.83 DRILL P PROD2 07:00 - 07:50 0.83 DRILL P PROD2 07:50 - 08:10 0.33 DRILL P PROD2 08:10 - 08:15 0.08 DRILL P PROD2 08:15 - 08:55 0.67 DRILL P PROD2 08:55 - 09:15 0.33 DRILL P PROD2 09:15 - 09:55 0.67 DRILL P PROD2 09:55 - 10:40 0.75 DRILL P PROD2 10:40 - 12:20 1.67 DRILL P PROD2 PJSM regarding pressure deployment. Begin pressure deploying lateral BHA. C/O gripper blocks, replaced 1 bad gripper block. Open EDC. RIH following pressure schedule. Log down for tie-in from 7915ft (ft corr. Closed EDC and RIH to 8200 ft and found the HOT was not functiong coorrectly Amp'd out with very slow movement and low rpm's (10 deg/10 min). POOH to change out HOT. Held PJSM on undeploying 3" tools and diwscussed all of the hazards associated with same Pressure un-deployed BHA with 825 psi on wellhead PU BHA and confirmed AKO setting Pressure deploy BHA in the well at 825 psi WHP RIH Tied in at 7910 ft (Corrected -23 ft). Closed EDC RIH and tagged bottom at 8735 ft Drilling lateral from 8735 ft TF at 10L HS to 90LHS O p 2.35/2.35 bpm at 3850 psi off bottom psi Density = 10.00 / 10.10ppg Vp = 260 bbl BHP/WHP = 4092 / 469psi Drilled to 8900ft. Wiper to window -clean. Wiper to 8755ft -clean. Reduce rate & log MAD pass down from 8790ft to 8820ft. Wiper to TD -clean. Drilling lateral from 8900 ft TF at 90-140L O p 2.3/2.3 bpm at 3640 psi off bottom psi Density = 10.22 / 10.29ppg DHWOB = 1 k to 2k. Surface wt = 5K Vp = 268 bbl BHP/WHP = 4023 / 400psi Drilled to 8961ft. Slowly PUH & circulate sample out. Drilling lateral from 8961 ft TF at 110-140L O p 2.3/2.3 bpm at 3700 psi off bottom psi Density = 10.22 / 10.29ppg DHWOB = 2k to 4k. Surface wt = OK Vp = 241 bbl (divert to C/O upper shaker screen) BHP/WHP = 4060 / 500psi Drill to 8980ft. Slowly PUH & circulate sample out. Drilling lateral from 8980 ft TF at 120-140L O p 2.3/2.3 bpm at 3700 psi off bottom psi Density = 10.22 / 10.29ppg DHWOB = 2k to 4k. Surface wt = OK Vp = 238 bbl BHP/WHP = 4075 / 500psi Conduct mud swap, new mud at the bit at 9000ft. Printed: 6/16/2008 2:07:41 PM ~ ~ BP AMERICA Page 12 of 17 ~ Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date 'From - To Hours Task Code ~ NPT I Phase Description of Operations 5/14/2008 10:40 - 12:20 1.67 DRILL P PROD2 Drill to 9068ft. 12:20 - 13:35 1.25 DRILL P PROD2 Wiper to the window -clean. Wiper to TD -clean, reduce rate through sidetrack area. Partial mud swap complete & the new Flo-pro is already achocolate/brown color. 13:35 - 16:10 2.58 DRILL P PROD2 Drilling lateral from 9067 ft TF at 120-140L O p 2.3/2.3 bpm at 3760 psi off bottom psi Density = 10.06 / 10.06ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 137 bbl BHP/WHP = 4015 / 450psi Drill to 9200ft. 16:10 - 17:00 0.83 DRILL P PROD2 Wiper to the window -clean. 17:00 - 17:15 0.25 DRILL P PROD2 Log down for tie-in at RA marker (+2ft). 17:15 - 17:50 0.58 DRILL P PROD2 Wiper to TD -clean. 17:50 - 20:00 2.17 DRILL P PROD2 Drilling lateral from 9067 ft to 9302 ft TF at 120-140L O p 2.3/2.3 bpm at 3800 psi off bottom psi Density = 10.06 / 9.96ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 215 bbl BHP/WHP = 4025 / 450psi 20:00 - 20:20 0.33 DRILL P PROD2 Mini wiper during SLB change out 20:20 - 21:11 0.85 DRILL P PROD2 Drilling lateral from 9302 ft to 9350 ft TF at 90L Q p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.04 / 9.96ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 440 bbl BHP/WHP = 4107 / 520psi 21:11 - 22:05 0.90 DRILL P PROD2 Wiper trip to base of billet ST at 8713 ft Clean 22:05 - 00:00 1.92 DRILL P PROD2 Drilling lateral from 9350 ft to 9446 ft TF at 120E - 90 O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.05 / 9.97ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 441 bbl BHP/WHP = 4109 / 527psi 5/15/2008 00:00 - 00:50 0.83 DRILL P PROD2 Drilled to 9500 ft 00:50 - 01:55 1.08 DRILL P PROD2 Wiper trip 01:55 - 03:30 1.58 DRILL P PROD2 Drilling lateral from 9500 ft to 9569 ft TF at 90R O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.05 / 10.10 ppg DHWOB = 2k to 4k. Vp = 427 bbl BHP/WHP = 4105psi / 527psi Getting lots of negative CTW 03:30 - 03:40 0.17 DRILL P PROD2 200 ft mini wiper trip 03:40 - 08:15 4.58 DRILL P PROD2 Drilling lateral from 9,569 ft to 9650ft. TF at 90R to 90L O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.05 / 10.10 ppg Printed: 6/16/2008 2:07:41 PM BP AMERICA Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours : Task Code ~ NPT 5/15/2008 03:40 - 08:15 4.58 _- - _- - DRILL P Start: 4/28/2008 Rig Release: 5/20/2008 Rig Number: Page 13 of 17 ~ Spud Date: 4/1 /1988 End: 5/20/2008 Phase Description of Operations PROD2 08:15 - 09:25 1.17 DRILL P PROD2 09:25 - 09:40 0.25 DRILL P PROD2 09:40 - 10:25 0.75 DRILL P PROD2 10:25 - 13:45 3.33 DRILL P PROD2 13:45 - 15:50 2.08 DRILL P PROD2 15:50 - 17:10 1.33 DRILL P PROD2 17:10 - 18:10 1.00 DRILL N STUC PROD2 18:10 - 21:00 2.83 DRILL P PROD2 21:00 - 21:15 0.25 DRILL P PROD2 21:15 - 00:00 2.75 DRILL P PROD2 5/16/2008 100:00 - 00:15 I 0.251 DRILL I P I I PROD2 00:15 - 02:00 1.75 DRILL P PROD2 02:00 - 03:30 1.50 DRILL P PROD2 03:30 - 03:50 0.33 DRILL P PROD2 03:50 - 05:10 1.33 DRILL P PROD2 05:10 - 08:25 ~ 3.25 ~ DRILL ~ P ~ ~ PROD2 08:25 - 08:50 ~ 0.42 ~ DRILL ~ P ~ ~ PROD2 08:50 - 10:30 I 1.671 DRILL I P I I PROD2 10:30 - 10:45 0.25 DRILL P PROD2 10:45 - 12:20 1.58 DRILL P PROD2 DHWOB = 2k to 4k. Vp = 420 bbl BHP /ECD /WHP = 4,125psi / 13.48ppg / 527psi W iper to the window. Log down for tie-in from 8250ft (+2ft corr. W iper to TD -clean. Drilling lateral from 9,650 ft to 9800 TF at 90R to 90L O p 2.4/2.4 bpm at 3900 psi off bottom psi Density = 10.05 / 10.10 ppg DHWOB = 2k to 4k. Vp = 368 bbl BHP /ECD /WHP = 4,070psi / 13.22ppg / 480psi Wiper to the window, 3k overpull at 8490ft, otherwise clean. Drilling lateral from 9,800 ft to TF at 60L to 90L O p 2.4/2.4 bpm at 3870 psi off bottom psi Density = 10.14 / 10.19 ppg DHWOB = 2k to 4k. Vp = 364 bbl BHP /ECD /WHP = 4,077psi / 13.21 ppg / 470psi Lost motor work at 9839ft. Attempt to PU. Tight hole at 9,839ft. Pull to max of 43k on CTC, which is 70k. POOH to lay down URS and pick up agitator. OOH, PJSM on handling pressure undeploying BHA Pressure undeploy BHA with 900 psi on wellhead PU RB BC Bit, New motor with 1.1 AKO setting and agitator along with Coiltrac Held PJSM and discussed the Hazards associated with Pressure Deploying BHA in the well. Pressure deploying BHA in the well. Blanked off LOC check valves. PU injector and pull tested CTC to 40k Stabbed injector Open EDC Tagged up and set counters. RIH maintaining MPD Pressure schedule Tied in and corrected -21 ft, closed EDC and RIH RIH with drill TF. Op = 2.12 bpm CTP = 3,823 psi AV=186 fpm, WHP = 450 psi, BHP = 4076 psi Drilling Lateral from 9836 ft to 9,924 ft Op = 2.19 bpm at 3890 psi Density = 10.16 / 10.14 ppg. BHP = 4031 psi at 13ppg ECD Vp = 378 bbl Cleaning up this area up to 9,755 ft (TF change) Finish 50ft wiper trip. Tag bottom, lost motor work. PU & are stuck. Trap 825psi WHP & let coil relax. No change on WOB (stuck above DPS sub). Crossed afault - 9890ft. Call for new mud. Slowly wiper to the window to keep AV's above 150ft/min to rule out the possibility of hole cleaning issues & to help the formation relax. Log down for tie-in (+10ft corr. Wiper to TD -clean. Backream from TD to 9875ft. Printed: 6/16/2008 2:07:41 PM '~ • BP AMERICA Page 14 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: ' ' Date From - To Hours Task Code NPT Phase Description of Operations 5/16/2008 12:20 - 13:10 0.83 DRILL P PROD2 Drilling Lateral from 9,924 ft to 9,944 ft Op = 2.19 bpm at 4000 psi Density = 10.15 / 10.16 ppg. BHP = 4050 psi at 13.16ppg ECD Vp = 368 bbl Drill to 9,944ft. Sticky, 25k overpull off bottom. 13:10 - 13:45 0.58 DRILL P PROD2 Wiper trip. Conduct mud swap. HOT is acting up intermittently. 13:45 - 14:20 0.58 DRILL P PROD2 10bbls of new mud out the bit. Drilling Lateral from 9944 ft to 9,977 ft Op = 2.2 bpm at 3800 psi Density = 10.04 / 10.20 ppg. BHP = 4030 psi at 13.09ppg ECD Vp = 216 bbl (conducting mud swap) 14:20 - 17:45 3.42 DRILL N DFAL PROD2 HOT is unreliable. POH following pressure schedule. Open EDC in tubing, won't function & left it closed. Continue POH pumping through the bit. 17:45 - 19:00 1.25 DRILL N DFAL PROD2 Crew change and held PJSM on Pressure undeploy of BHA Circulating through MPD loop 19:00 - 20:30 1.50 DRILL N DFAL PROD2 Handle BHA using undeployment procedures 20:30 - 22:20 1.83 DRILL N DFAL PROD2 Change out entire Coiltrac BHA and RR motor and PU STC BC Bit 22:20 - 23:45 1.42 DRILL N DFAL PROD2 RIH 23:45 - 23:55 0.17 DRILL N DFAL PROD2 Log Tie-in Corrected -24 ft 23:55 - 00:00 0.08 DRILL N PROD2 Closed EDC and RIH 5/17/2008 00:00 - 01:30 1.50 DRILL N DFAL PROD2 RIH 01:30 - 03:10 1.67 DRILL P PROD2 Drilling lateral from 9978 ft to 10070 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4250 psi BHP/ECD/WHP=4021 psi/13.09 ppg/450 psi Density = 10.06 / 10.05 ppg Vp = 379 bbl.s ROP started off at 90-100 fph with 2k DHWOB 03:10 - 03:30 0.33 DRILL P PROD2 200 ft wiper trip, getting a little stick, don't want to have to call town and see what I'm allow to pull if it get tight. 03:30 - 04:00 0.50 DRILL P PROD2 Drilling lateral from 10,070 ft to 10,105 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4250 psi BHP /ECD /WHP = 4000 psi / 13.05 ppg / 420 psi Density = 10.06 / 10.05 ppg Vp = 388 bbl.s Faulted at 10052 ft, getting sticky 04:00 - 05:40 1.67 DRILL P PROD2 Make wiper trip to avoid calling town 05:40 - 08:15 2.58 DRILL P PROD2 Drilling lateral from 10,105 ft to 10,205 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4,250 psi BHP /ECD /WHP = 4,000 psi / 13.05 ppg / 420 psi Density = 10.06 / 10.05 ppg Vp = 382 bbls Stacking & sticky while PU - 10k overpulls. 08:15 - 10:30 2.25 DRILL P PROD2 Wiper trip -clean both ways. 10:30 - 12:10 1.67 DRILL P PROD2 Drilling lateral from 10,205 ft to 10,260 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4,250 psi BHP /ECD /WHP = 4,000 psi / 13.05 ppg / 420 psi Printed: 6/16/2008 2:07:41 PM ~ r BP AMERICA Page 15 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours ~ Task Code NPT ;I Phase Description of Operations ---_ 5/17/2008 10:30 - 12:10 1.67 _- _ _ DRILL P PROD2 12:10 - 12:45 0.581 DRILL N DFAL PROD2 12:45 - 15:30 2.751 DRILL N DFAL PROD2 15:30 - 19`.45 4.25 DRILL N SFAL PROD2 19:45 - 20:00 0.25 DRILL N SFAL PROD2 20:00 - 20:45 0.75 DRILL P PROD2 20:45 - 22:00 1.25 DRILL P PROD2 22:00 - 00:00 I 2.001 BOPSUR P I I PROD2 5/18/2008 03:05 - 04:15 1.00 BOPSU~ P PROD2 04:15 - 04:30 0.25 BOPSU P PROD2 04:30 - 06:15 1.75 BOPSU P PROD2 06:15 - 07:45 1.50 DRILL N DFAL PROD2 07:45 - 08:00 0.25 DRILL N DFAL PROD2 08:00 - 09:10 1.17 DRILL N DFAL PROD2 09:10 - 11:30 2.33 DRILL P PROD2 11:30 - 14:00 2.50 DRILL P PROD2 14:00 - 17:00 3.00 DRILL P PROD2 17:00 - 19:18 2.30 DRILL P PROD2 19:18 - 21:25 2.12 DRILL P PROD2 Density = 10.06 / 10.05 ppg Vp = 382 bbls HOT is not working. Slowly PUH. Appears to be a software problem. Only the DPS & EDC operate now & TF is stuck at 105R HS. POH following pressure schedule. 6k overpull at the OH billet & clean through the window. Pressure undeploy BHA. Slickline wire broke at the drum. Spool new wire onto drum & rehead. Held PJSM and discussed the hazard associated wit pressure deploying BHA. Pressure undeploy BHA after reheading wireline head Pressure undeploy BHA Clean floor and make ready to conduct BOP test Wavered witnessing by AOGCC Chuck Scheve BHI tested their BHA and found the HOT was non funtiohing. Travel to Nordic 1 to get the back up HOT tool Open doors on VBR and inspect for debis. Re-building 2 accumulator bottles BOP test Chuck Scheve wavered witnessing BOP test BOP Test PT the injector stripper and inner reel valve to 250 / 4000 psi. Test OKrelease P and set back injector. PJSM on PU BHA and pressure deployment Confirm valve aligment following BOP test PU BHA and pressure deploy as per SOP's RIH following pressure schedule. Log down for tie-in from 7890ft (-27ft corr. Wiper to TD -clean. HOT is acting up again Drilling lateral from 10,260 ft to 10,350 ft Op = 2.23 / 2.23 bpm at 3,815 psi off bottom CTP = 4,250 psi BHP /ECD /WHP = 4,000 psi / 13.08 ppg / 420 psi Density = 10.12 / 10.04 ppg Vp = 352 bbls Acting sticky again. Wiper to billet at 8713ft clean. Wiper to TD -clean. Drilling lateral from 10,350 ft to 10,500 ft Op = 2.23 / 2.23 bpm at 3,830 psi off bottom CTP = 4,400 psi BHP /ECD /WHP = 4,065 psi / 13.30 ppg / 475 psi Density = 10.11 / 10.09 ppg Vp = 360 bbls Wiper to 8730 ft, Clean trip out Drilling lateral from 10,500 ft with HS TF. Need to build up quickly to compensate for the 4 deg dip. Op = 2.23 / 2.23 bpm at 3,830 psi off bottom CTP = 4,400 psi BHP /ECD /WHP = 4,065 psi / 13.37 ppg / 475 psi Density = 10 / 10 ppg Vp = 310 bbls Printed: 6/16/2008 2:07:41 PM • • BP AMERICA Page 16 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours ', Task Code NPT ~ Phase Description of Operations ~ 5/18/2008 ~ 21:25 - 21:26 0.021 DRILL P PROD2 21:26 - 21:55 I 0.481 DRILL I N I STUC I PROD2 21:55 - 00:00 I 2.081 DRILL I P I I PROD2 5/19/2008 00:00 - 01:45 1.75 DRILL P PROD2 01:45 - 02:38 0.88 DRILL P PROD2 02:38 - 05:30 2.871 DRILL P PROD2 05:30 - 07:15 1.75 DRILL P PROD2 07:15 - 08:40 1.42 DRILL P PROD2 08:40 - 09:15 0.58 DRILL P PROD2 09:15 - 10:00 0.75 DRILL P PROD2 10:00 - 10:15 0.25 DRILL P PROD2 10:15 - 11:40 1.42 DRILL P PROD2 11:40 - 12:15 0.58 DRILL P PROD2 12:15 - 13:00 0.75 DRILL P PROD2 13:00 - 13:45 0.75 DRILL P PROD2 13:45 - 19:30 5.75 CASE P LNR2 19:30 - 22:05 2.58 CASE P LNR2 22:05 - 23:35 1.50 CASE P LNR2 23:35 - 0.00 CASE P LNR2 5/20/2008 00:00 - 00:22 0.37 CASE P LNR2 00:22 - 01:55 1.55 WHSUR P CLEAN 01:55 - 03:00 1.08 WHSUR P CLEAN 03:00 - 05:40 2.67 WHSUR P CLEAN PU to conduct wiper trip and pulling tight off bottom Pulled to 50k max 6 times and tool still won't work String Wt at 24k, pulling 30k over. Waiting on SLB and BP approval for pulling on CT. Worked CT down to compare the string wt between the Martin decker and SLB's computer and finally got free. PU hole Wiper trip to window and tie in Motor work at 8,430 ft Tied in and corrected +6 ft Wiper trip back in the hole Drilling lateral from 10,578 ft to Op = 2.15 / 2.13 bpm at 3,830 psi off bottom CTP = 4000-4,400 psi BHP/ECD/WHP=4,065psi/13.37ppg/475 psi Density = 10 / 10 ppg Vp = 286 bbls Having trouble getting to drill in the shale/silstone stacking and over pulls Wiper trip to tie at 7,910 ft. Open EDC at 8,195 ft and inc Op to 2.75 bpm at 3,700 psi Tied in and corrected +1 ft. RIH. Start pumping 100k LSRV liner pill w/ 2ppb Alpine beads while RIH ~ 10,000ft. Tag TD at 10,608ft. POH to the window laying in liner pill in the OH section. Pump 16bb1 hi-vis spacer pill while PUH to the the window. Slowly reciprocate coil & circulate 12.99ppg (MM density) K-Formate KW F down coil. K-Formate at bit 2.0/3600 w/ 400 psi whp 4000 psi dhp=13.07 ECD. Let 2 bbls get above BHA & slowly PUH while circ in rest of K-formate maintaining dhp at 4000-4020 psi (13.0-13.1 ECD). KW F at surface. Flow check well. POH filling across the top. PJSM regarding handling BHA. Flow check well. LD BHI tool string. Wear pads, CTC & LOC connection are covered in asphaltines?, recovered 1/4 cup for people to look at. RU Farr tongs. MU 2-3/8" safety jt. PJSM regarding MU liner. MU 2-7/8" liner per program. RIH with liner tagged bottom at 10608 ft, PU string wt at 30k ~ RBIH and set down at 10,608 ft. Line up down the CT and Op = 1.62 bpm to release from the liner at 8,206 ft PU and lost 4k of liner wt in 13.1 ppg mud POOH OOH, flow check LD Liner running BHA and PU Nozzle BHA for displacing the KW F in the well RIH Pumped 15 bbl of 10ppg 100 k LSRV flowpro follow by 2% KCL Pumped 2% KCL around and back to surface while holding 1250 psi on well. POOH to 2500 to FB the top 2500 ft with diesel. Held PJSM and PT LRS to 3000 psi. Pump 50 bbl diesel down CT and Printed: 6/16/2008 2:07:41 PM ~ r BP AMERICA Page 17 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date I! From - To Hours ~ Task Code NPT I Phase Description of Operations 5/20/2008 03:00 - 05:40 2.67 WHSUR P CLEAN displaced with 2% KCL. RD LRS and POOH chasing diesel to surface. OOH, closed SV and MV with 1300 psi on well. 05:40 - 06:00 0.33 WHSUR P POST Pickle CT and make ready to blow down. 06:00 - 10:35 4.58 RIGD N WAIT POST Wait on nitrogen from GPB. 10:35 - 10:55 0.33 RIGD P POST Spot N2 unit. RU hardline to existing rig hardline. 10:55 - 11:05 0.17 RIGD P POST PJSM regarding pumping nitrogen. 11:05 - 12:45 1.67 RIGD P POST P.T. N2 lines to 4000psi. Pump 10bbls of methanol & 2 bbls from pits to clean rig pump lines. 12:45 - 15:00 2.25 RIGD P POST RD nozzle BHA. Install pull back grapple & cable inside coil. Tail coil to reel and secure. Lower reel to trailer. 15:00 - 00:00 9.00 RIGD P POST Install BPV, Clean pits. ND BOP stack. Install tree cap and PT to 4000 psi. RDMO. Rig released at midnight Printed: 6/16/2008 2:07:41 PM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. ~ Kuparuk River Unit Kuparuk 3F Pad 3F-16 3F-16AL1-01 Design: 3F-16AL1-01 Baker .Hughes INTEQ Survey Report 17 June, 2008 r~~r BAKER FI~I~NES 1NTEQ ConocoPhillips Alaska Company: ConocoPhiilips(Alaska) Inc. Project: Kuparok RiverUnft Site: Kuparuk 3F Pad Well: 3F-16 Wellbore: 3F-16AL1-01 Design: 3F-16AL1-01 ConocoPhillips ~R r Ba Baker Hughes INTEQ Survey Report ~~~ INTEQ Local Co-ordinate Reference: Well 3F-16 ND Reference: Mean Sea Level MD Reference: 3F-16A ~ SS:OOft (3F-16A) North Reference: True Survey Calculatlon Method: Minimum Curvature Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum• NAD 1927 (NADCON CONUS) Using WeII Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor - _ _--- Site Kuparuk 3F Pad Site Position: Northing: 5,985,734.46 ft Latitude: 70° 22' 20.081 N From: Map Easting: 508,662.33 ft Longitude: 149° 55' 46.550 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.07 ° Wag 3F-16 Well Position +W.S 0.00 ft Northing: 5,985,904.95 ft Latitude: 70° 22' 21.762 N +E/.yy 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 •I WeHborQ 3F-16AL1-01 Magnetics Model Name Sample Date Declination Dlp Angle Field Strength l°) I°I InT1 BGGM2007 3/12/2008 17.70 79.75 57,268 __ ____ Destgn 3F-16AL4-01 Audk Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,690.13 Vertical Suction: Deptb From (ND) +N/.g +FJ-W Direction Iftl l~) IftI 1°) 0.00 0.00 0.00 183.00 •i 6/17/2008 3:33:29PM Page 2 COMPASS 2003.16 Build 42F / h ll ConocoPhillips ConocoP i ips Baker Hughes INTEQ Survey Report Alaska Company: ConocoPhillips(Aiaska) Inc. Local Co-ordinate Reference: Well 3F-16 Project: KuparukRiver Unit TVD Reference: Mean Sea Level Site: Kuperuk 3F Pad MD Reference: 3F-16A ~ 88:OOft (3F-16A) Well: 3F-18 North Reference: True Weilbore: 3F-16AL1-01 Survey Calculation Method: Minimum Curvature Design: 3F-16AL1-01 Database: EDMv16 Prod />/ar , B N 8R1~8 INTEQ Survey Program Date From To Ift! Ift) Survey (Vllellbore) 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 8,226.00 8,690.13 3F-16AL1P81 (3F-AL1P81 TD) MWD MWD-Standard 8,713.00 10,608.00 3F-16AL1-01 (3F-16AL1-01) MWD MWD -Standard Survey i MD Inc Azi TVDSS WS E!W Northing Fasting DLS Vertical Section TFO l~l 1°- 1°) Ifq (ftl Iftl IfU lR! 1°110! lft1 1°! 8,690.13 99.94 270.55 5,979.68 4,227.27 -3,126.14 5,990,128.34 505,142.24 16.84 -4,057.87 -82.72 8,713.00 99.68 267.69 5,975.78 4,226.93 -3,148.67 5,990,127.97 505,119.71 12.37 -4,056.35 -95.03 8,747.96 103.32 265.73 5,968.81 4,224.97 -3,182.87 5,990,125.97 505,085.52 11.77 -4,052.60 -27.63 8,778.72 104.08 263.99 5,961.53 4,222.29 -3,212.63 5,990,123.26 505,055.77 6.03 -4,048.37 -65.59 8,812.75 104.90 262.04 5,953.01 4,218.28 -3,245.33 5,990,119.22 505,023.07 6.05 -4,042.66 -66.28 8,847.76 103.32 258.88 5,944.48 4,212.65 -3,278.81 5,990,113.56 504,989.60 9.85 -4,035.28 -116.88 8,878.53 101.59 256.97 5,937.84 4,206.37 -3,308.19 5,990,107.24 504,960.24 8.27 -4,027.47 -132.64 8,909.59 99.81 254.83 5,932.07 4,198.93 -3,337.79 5,990,099.77 504,930.65 8.87 -4,018.49 -130.04 8,940.37 97.58 251.94 5,927.42 4,190.23 -3,366.94 5,990,091.04 504,901.51 11.77 -4,008.28 -127.75 8,970.05 95.60 249.49 5,924.01 4,180.49 -3,394.76 5,990,081.27 504,873.70 10.57 -3,997.10 -128.98 9,000.12 93.44 247.23 5,921.64 4,169.44 -3,422.62 5,990,070.19 504,845.86 10.38 -3,984.60 -133.70 9,029.75 91.90 244.39 5,920.26 4,157.31 -3,449.62 5,990,058.03 504,818.88 10.89 -3,971.08 -118.42 9,061.16 90.43 242.06 5,919.62 4,143.17 -3,477.65 5,990,043.86 504,790.86 8.77 -3,955.48 -122.23 9,090.51 90.03 238.66 5,919.51 4,128.65 -3,503.16 5,990,029.32 504,765.37 11.66 -3,939.66 -96.70 9,119.75 91.20 236.76 5,919.19 4,113.04 -3,527.87 5,990,013.67 504,740.68 7.63 -3,922.77 -58.37 9,150.03 93.72 233.91 5,917.89 4,095.83 -3,552.75 5,989,996.44 504,715.82 12.56 -3,904.28 -48.44 9,179.42 92.58 231.74 5,916.28 4,078.10 -3,576.13 5,989,978.69 504,692.46 8.33 -3,885.35 -117.69 9,210.56 91.35 228.84 5,915.21 4,058.22 -3,600.07 5,989,958.78 504,668.55 10.11 -3,864.25 -112.94 9,238.97 89.29 227.15 5,915.05 4,039.21 -3,621.18 5,989,939.75 504,647.46 9.38 -3,844.16 -140.63 9,268.06 88.86 224.40 5,915.52 4,018.93 -3,642.02 5,989,919.45 504,626.65 9.57 -3,822.81 -98.91 ., 6/17/2008 3:33:29PM Page 3 COMPASS 2003.16 Build 42F '-~' ConocoPhillips N.ar Philli C s~~ onoco s p Baker Hughes INTEQ Survey Report $ Alaska INTEQ Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: Welt 3F-16 Project: Kuparuk River. UnR ND Reference: Mean Sea Level Site: Kuparuk 3F Pad. MD Reference: 3F-16A (~ 88.OOft (3F-16A) Weil: 3F-16 North Reference: True Wellbore: 3F-16AL1-01 Survey Calculation Method: Minimum Curvature Design: 3F-16AL1-01 Database: EDMv16 Prod Survey MD Inc Azi TVDSS NIS EMI Northing Easting DLS Vertical Sectlon TFO (ff) (°1 1°) (ft1 (ft) (ft1 (tU Iff! (°woort) Ift) t°) 9,298.98 88.71 221.37 5,916.18 3,996.28 -3,663.05 5,989,896.78 504,605.64 9.81 -3,799.09 -92.87 9,333.58 88.96 218.45 5,916.88 3,969.75 -3,685.24 5,989,870.22 504,583.48 8.47 -3,771.44 -85.14 9,368.47 88.65 214.96 5,917.61 3,941.78 -3,706.09 5,989,842.24 504,562.67 10.04 -3,742.42 -95.11 9,397.73 88.06 212.24 5,918.45 3,917.43 -3,722.27 5,989,817.87 504,546.51 9.51 -3,717.25 -102.28 9,426.22 87.82 209.89 5,919.47 3,893.04 -3,736.96 5,989,793.47 504,531.85 8.29 -3,692.13 -95.88 9,457.54 87.58 206.95 5,920.73 3,865.52 -3,751.86 5,989,765.93 504,516.99 9.41 -3,663.86 -94.73 9,485.03 88.40 206.03 5,921.69 3,840.93 -3,764.11 5,989,741.33 504,504.76 4.48 -3,638.67 -48.29 9,511.61 87.54 209.05 5,922.63 3,817.38 -3,776.39 5,989,717.77 504,492.51 11.81 -3,614.51 105.95 9,543.87 86.71 210.52 5,924.25 3,789.42 -3,792.40 5,989,689.80 504,476.54 5.23 -3,585.75 119.52 9,569.94 87.94 208.13 5,925.47 3,766.72 -3,805.15 5,989,667.08 504,463.81 10.30 -3,562.41 -62.80 9,600.18 88.46 204.17 5,926.42 3,739.59 -3,818.47 5,989,639.94 504,450.52 13.20 -3,534.62 -82.58 9,630.95 88.68 201.72 5,927.19 3,711.27 -3,830.46 5,989,611.61 504,438.57 7.99 -3,505.71 -84.90 9,660.34 87.88 199.35 5,928.07 3,683.76 -3,840.76 5,989,584.09 504,428.29 8.51 -3,477.70 -108.69 9,690.89 87.26 196.81 5,929.37 3,654.74 -3,850.23 5,989;555.07 504,418.85 8.55 -3,448.23 -103.78 9,721.86 88.34 193.92 5,930.55 3,624.91 -3,858.43 5,989,525.23 504,410.69 9.96 -3,418.00 -69.56 9,751.19 89.36 191.33 5,931.14 3,596.29 -3,864.84 5,989,496.61 504,404.31 9.49 -3,389.10 -68.53 9,780.76 92.24 189.87 5,930.73 3,567.24 -3,870.28 5,989,467.55 504,398.91 10.92 -3,359.79 -26.87 9,808.93 94.18 188.08 5,929.15 3,539.46 -3,874.67 5,989,439.77 504,394.55 9.36 -3,331.82 -42.61 9,841.41 95.66 185.97 5,926.37 3,507.34 -3,878.62 5,989,407.65 504,390.63 7.92 -3,299.54 -54.77 9,871.55 96.46 182.01 5,923.18 3,477.45 -3,880.71 5,989,377.76 504,388.58 13.33 -3,269.58 -78.31 9,898.42 95.71 179.27 5,920.34 3,450.74 -3,881.01 5,989,351.05 504,388.31 10.52 -3,242.89 -105.24 9,931.43 94.82 173.42 5,917.30 3,417.95 -3,878.91 5,989,318.27 504,390.44 17.85 -3,210.26 -98.41 9,961.61 95.10 171.30 5,914.69 3,388.15 -3,874.92 5,989,288.48 504,394.47 7.06 -3,180.71 -82.36 9,994.42 96.12 167.60 5,911.49 3,356.05 -3,868.94 5,989,256.39 504,400.48 11.65 -3,148.97 -74.34 10,028.28 98.37 162.58 5,907.21 3,323.61 -3,860.30 5,989,223.96 504,409.15 16.14 -3,117.02 -65.38 10,060.24 101.30 158.27 5,901.75 3,293.95 -3,849.76 5,989,194.31 504,419.73 16.14 -3,087.95 -55.04 10,100.86 98.78 155.05 5,894.67 3,257.23 -3,833.91 5,989,157.62 504,435.61 9.97 -3,052.11 -128.19 6/17/2008 3:33:29PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: CorwcoPhUlips(Alaska) Ina Project: Kuparuk River Lnit Site: Kuparuk 3F Pad WeU: 3F-16 Wellbore: 3F-16AL1-01 Design: 3F-16AL1-01 Survey MD Inc Azi tft1 1°I 1°) 10,130.75 95.16 156.39 10,160.45 92.76 156.36 10,187.76 91.26 158.38 10,225.93 89.60 161.60 10,253.73 90.15 165.31 10, 280.51 89.63 170.87 10,310.65 87.88 173.52 10,337.89 86.71 176.27 10,366.92 85.15 180.59 10,402.58 85.67 185.66 10,430.59 86.56 187.91 10,460.19 87.94 192.14 10,487.13 90.21 196.44 10,519.86 92.61 196.94 10,549.10 94.15 196.53 10,570.08 94.08 198.75 10,608.00 94.08 198.75 ConocoPhillips I~~r Bye Baker Hughes INTEQ Survey Report INTEQ Local Coordinate Reference: Weli 3F-16 TVD Reference: Mean Sea Level. MD Reference: 3F-16A C~ 88.OOft (3F-16A) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod" NDSS NIS EIW Northing Easting DLS Vertical Section TFO j (ft) tft) tft1 lft) tft) 1°nooftl tft) r) 5,891.04 3,230.19 -3,821.72 5,989,130.59 504,447.84 12.90 -3,025.75 158.74 5,888.99 3,203.05 -3,809.85 5,989,103.46 504,459.74 8.08 -2,999.26 -179.28 5,888.03 3,177.86 -3,799.34 5,989,078.29 504,470.27 9.21 -2,974.66 126.57 5,887.75 3,142.00 -3,786.29 5,989,042.45 504,483.36 9.49 -2,939.53 117.25 5,887.81 3,115.35 -3,778.37 5,989,015.81 504,491.31 13.49 -2,913.34 81.57 5,887.86 3,089.16 -3,772.85 5,988,989.63 504,496.86 20.85 -2,887.47 95.34 5,888.51 3,059.31 -3,768.75 5,988,959.79 504,500.98 10.53 -2,857.88 123.47 5,889.80 3,032.21 -3,766.33 5,988,932.69 504,503.43 10.96 -2,830.94 113.13 5,891.86 3,003.27 -3,765.54 5,988,903.76 504,504.26 15.79 -2,802.08 110.05 5,894.72 2,967.79 -3,767.48 5,988,868.28 504,502.36 14.25 -2,766.55 84.33 5,896.62 2,940.05 -3,770.78 5,988,840.53 504,499.09 8.62 -2,738.67 68.45 5,898.04 2,910.94 -3,775.92 5,988,811.42 504,493.98 15.02 -2,709.33 72.02 5,898.47 2,884.84 -3,782.57 5,988,785.32 504,487.36 18.05 -2,682.92 62.21 5,897.67 2,853.50 -3,791.97 5,988,753.98 504,478.00 7.49 -2,651.14 11.76 5,895.94 2,825.55 -3,800.37 5,988,726.02 504,469.63 5.45 -2,622.78 -14.87 5,894.44 2,805.61 -3,806.71 5,988,706.07 504,463.31 10.56 -2,602.54 91.73 5,891.74 2,769.79 -3,818.87 5,988,670.25 504,451.19 0.00 -2,566.13 0.00 6/17/2008 3:33:29PM Page 5 COMPASS 2003.16 Build 42F 11/ ConocoPhillips Conoc oPhillips Baker Hughes INTEQ Survey Report Alaska Company: ConocoPhAlips(Alaska) Ina Local Co-ordinate Reference: Project: Kuparuk RiverUnit TVD Reference: Site: Kuparuk 3F Pad MD Reference: Well: 3F-16 North Reference: Wellbore: 3F-16AL1-01 Survey Calculation Method: Oeslgn: 3F-16AL1-01 Database: rc.r BaKSR e VVell3F-16 ' Mean Sea Level 3F-16A ~ 88.OOft (3F-16A) True Minimum Curvature EDMv16 Prod Targets Target Nama • hif/miss target Dlp Angle DIp Dk. TVD +N/-S +E/•W Northing Easting - Shspe 1°1 l°) Ift) Ift) Ift) Ift! Iftl Latitude Longitude 3F-16AL1 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual wellpath misses by 5922.12ft at 9029.75ft MD (5920.26 TVD, 4157.31 N, -3449.62 E) -Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 Point2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point 6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point 9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,878.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1-01 Target 2 0.00 0.00 5,828.00 2,836.40 -3,849.12 5,988,736.81 504,420.87 70° 22' 49.648 N 149° 57' 50.598 W - actual wellpath misses by 83.87ft at 10558.40ft MD (5895.27 TVD, 2816.68 N, -3803.09 E) - Point 3F-16AL1-01 Target 3 0.00 0.00 5,798.00 2,469.36 -3,844.54 5,988,369.81 504,425.86 70° 22' 46.038 N 149° 57' 50.459 W - actual wellpath misses by 315.76ft at 10608.OOft MD (5891.74 TVD, 2769.79 N, -3818.87 E) -Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual wellpath misses by 5898.57ft at 10283.27ft MD (5887.88 TVD, 3086.44 N, -3772.41 E) - Polygon Point 1 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point 4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16AL1-Ot Target 1 0.00 0.00 5,882.00 3,048.35 -3,794.88 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual wellpath misses by 27.998 at 10318.92ft MD (5888.85 TVD, 3051.09 N, -3767.88 E) - Point 6/17/2008 3:33:29PM Page 6 COMPASS 2003.16 Build 42F / ConocoPhillips I/.~r Philli C s~~ onoco s p Baker Hughes INTEQ Survey Report ~$ Alaska INTEQ Company: ConocoPhdiips(Alaska) Ina Local Co-ordinate Reference: Well 3F-16 Project Kuparuk River Unk TVD Reference: Mean Sea Level Site: Kuparuk 3F Pad MD Reference: 3F-16A ~ 88.OOft (3F-16A) Well: 3F-t6 North Reference: True. Wellbore: 3F-16AL1-01 Survey Calculation Method: Minimum Curvature Design: 3F-16AL1-01 Database: EDMv16 Prod Targets Target Name • hitlmiss target Dlp Angle Dip Dir. ND +NI-S +EI-W Northing Easting -Shape (°) (°) Ift1 lftl (ft) (ft) (ft) Latitude Longitude 3F-16AL1 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual wellpath misses by 5922.12ft at 9029.75ft MD (5920.26 TVD, 4157.31 N, -3449.62 E) -Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 Point2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point 4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point 6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,878.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1-01 Target 2 0.00 0.00 5,828.00 2,836.40 -3,849.12 5,988,736.81 504,420.87 70° 22' 49.648 N 149° 57' 50.598 W - actual wetlpath misses by 83.87ft at 10558.40ft MD (5895.27 TVD, 2816.68 N, -3803.09 E) - Point 3F-16AL1-01 Target 3 0.00 0.00 5,798.00 2,469.36 -3,844.54 5,988,369.81 504,425.86 70° 22' 46.038 N 149° 57' 50.459 W - actual wellpath misses by 315.76ft at 10608.OOft MD (5891.74 TVD, 2769.79 N, -3818.87 E) - Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual weilpath misses by 5898.57ft at 10283.27ft MD (5887.88 TVD, 3086.44 N, -3772.41 E) -Polygon Point 1 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point 4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16ALt-01 Target 1 0.00 0.00 5,882.00 3,048.35 -3,794.88 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual weilpath misses by 27.99ft at 10318.92ft MD (5888.85 TVD, 3051.09 N, -3767.88 E) - Point u 6/17/2008 3:33:29PM Page 7 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhNlips(Alaska) Ina Pro}ect Kuparuk RivecUnit Site: Kuparuk 3F Pad Well: 3F-16 Welibore: 3F-7 6AL 1-01 Design: 3F-16AL1-01 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-oMinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.r B W~~ We11 3F-16 Mean Sea Level 3F-16A ~ 88.OOft (3F-16A) True Minimum Curvature EDMv16 Prod Targets Target Name - hitlmiss target Dip Angle Dip Dfr. ND +W-S +E/-W Northing EasBng - Shape (°) (°) Iftl Ift) (ft) (ftl lft) Latitude Longitude 3F-16AL1 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual wellpath misses by 5922.12ft at 9029.75ft MD (5920.26 ND, 4157.31 N, -3449.62 E) - Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 Point 2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point 6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,878.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1-01 Target 2 0.00 0.00 5,828.00 2,836.40 -3,849.12 5,988,736.81 504,420.87 70° 22' 49.648 N 149° 57' 50.598 W - actual wellpath misses by 83.87ft at 10558.40ft MD (5895.27 ND, 2816.68 N, -3803.09 E) - Point 3F-16AL1-01 Target 3 0.00 0.00 5,798.00 2,469.36 -3,844.54 5,988,369.81 504,425.86 70° 22' 46.038 N 149° 57' 50.459 W - actual wellpath misses by 315.76ft at 10608.OOft MD (5891.74 ND, 2769.79 N, -3818.87 E) -Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual welipath misses by 5898.57ft at 10283.27ft MD (5887.88 ND, 3086.44 N, -3772.41 E) - Polygon Point 1 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16AL7-01 Target 1 0.00 0.00 5,882.00 3,048.35 -3,794.88 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual wellpath misses by 27.99ft at 10318.92ft MD (5888.85 ND, 3051.09 N, -3767.88 E) - Point I~ i 6/17/2008 3:33:29PM Page 8 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Protect Kuparuk$iverUnit Site: Kuparuk 3FPad Well: 3F-16 WsBtwre: 3F-16AL1-01 Des~n: 3F-16AL1-01 ConocoPhillips Baker Hughes INTEQ Survey Report Local Coordinate Reference: Weli 3F-16 ND Reference: Mean Sea Level MD Reference: 3F-16A ~ 88.OOft (3F-16A) North Reference: True Survey Caiculadon Method: Minimum Curvature Database: EDMv16 Prod ri.r sn~c~~ ~4 Targets Target Name - hiNmlas target Dlp Angle Dip Dir. ND +W-S +E/-W Northing Easting -Shape (°- 1°) (ft) lftl (ftl (ft1 Ift1 LatlWde Longitude 3F-16AL1 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual weilpath misses by 5922.12ft at 9029.75ft MD (5920.26 ND, 4157.31 N, -3449.62 E) -Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.76 504,898.90 Point2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point 4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,876.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1-01 Target 2 0.00 0.00 5,828.00 2,836.40 -3,849.12 5,988,736.81 504,420.87 70° 22' 49.648 N 149° 57' 50.598 W - actual weilpath misses by 83.87ft at 10558.40ft MD (5895.27 ND, 2816.68 N, -3803.09 E) - Point 3F-16AL1-01 Target 3 0.00 0.00 5,798.00 2,469.36 -3,844.54 5,988,369.81 504,425.86 70° 22' 46.038 N 149° 57' 50.459 W - actual weilpath misses by 315.76ft at 10608.OOft MD (5891.74 ND, 2769.79 N, -3818.87 E) - Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual weilpath misses by 5898.57ft at 10283.27ft MD (5887.88 ND, 3086.44 N, -3772.41 E) - Polygon Point 1 0.00 2,914.66 -4,083:06 5,988,814.81 504,186.87 Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point 4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16AL7-01 Target 1 0.00 0.00 5,882.00 3,048.35 -3,794.88 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual weilpath misses by 27.99ft at 10318.92ft MD (5888.85 ND, 3051.09 N, -3767.88 E) -Point ~~ 6/17/2008 3:33:29PM Page 9 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 3F Pad We0: 3F-16 Wellbore: 3F-16AL7-01 Design: 3F-16AL1-01 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.-r s ~i~s INTEQ Weil 3F-16 MeamSea Level 3F-16A ~ 88:OOft (3F-16A) True Minimum Curvature EDMv16 Prod Targets Targot Name - htUmlas target Dip Angle Dip Dir. ND +WS +E!-W Northing Easting -Shape (°) (°- lft1 Iftl (ft) Ift1 lft1 Latitude LonglWde 3F-16AL1 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual wellpath misses by 5922.12ft at 9029.75ft MD (5920.26 ND, 4157.31 N, -3449.62 E) - Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 Point2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point 4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point 6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point 9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,878.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1-01 Target 2 0.00 0.00 5,826.00 2,836.40 -3,849.12 5,988,736.81 504,420.87 70° 22' 49.648 N 149° 57' 50.598 W - actual wellpath misses by 83.87ft at 10558.40ft MD (5895.27 ND, 2816.68 N, -3803.09 E) - Point 3F-16AL1-01 Target 3 0.00 0.00 5,798.00 2,469.36 -3,844.54 5,988,369.81 504,425.86 70° 22' 46.038 N 149° 57' 50.459 W - actual wellpath misses by 315.76ft at 10608.OOft MD (5891.74 ND, 2769.79 N, -3818.87 E) - Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual wellpath misses by 5898.57ft at 10283.27ft MD (5887.88 ND, 3086.44 N, -3772.41 E) - Polygon Point 1 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point 4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16AL1-01 Target 1 0.00 0.00 5,882.00 3,048.35 -3,794.86 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual wellpath misses by 27.99ft at 10318.92ft MD (5888.85 ND, 3051.09 N, -3767.88 E) -Point • 6/17/2008 3:33:29PM Page 10 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 3F Pad. Well: 3F-16 Wellbore: 3F-t6AL1-01 Design: 3F-16AL1-01 ConocoPhillips Baker Hughes INTEQ Survey Report Local CooMinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: r~.lr Ig WRYR4 We11 3F-16' Mean Sea Level 3F-1SA (~ 88:OOft (3F-16A) True Minimum Curvature EDMv16 Prod Targets Target Name - hitlmiss target Dlp Angle Dip Dlr. ND +N!-S +E/-W Northing Easting ~~ -Shape 1°- (°I lft1 (ft1 (ft1 Iftl Ift1 Latitude Longitude 3F-16AL7 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual wellpath misses by 5922.12ft at 9029.75ft MD (5920.26 ND, 4157.31 N, -3449.62 E) -Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 Point2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point 4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point 6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,878.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1-01 Target 2 0.00 0.00 5,828.00 2,836.40 -3,849.12 5,988,736.81 504,420.87 70° 22' 49.648 N 149° 57' 50.598 W - actual wellpath misses by 83.87ft at 10558.40ft MD (5895.27 ND, 2816.68 N, -3803.09 E) - Point 3F-16AL1-01 Target 3 0.00 0.00 5,798.00 2,469.36 -3,844.54 5,988,369.81 504,425.86 70° 22' 46.038 N 149° 57' 50.459 W - actual wellpath misses by 315.76ft at 10608.OOft MD (5891.74 ND, 2769.79 N, -3818.87 E) - Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual wellpath misses by 5898.57ft at 10283.27ft MD (5887.88 ND, 3086.44 N, -3772.41 E) - Polygon Point 1 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16AL1-01 Target 1 0.00 0.00 5,882.00 3,048.35 -3,794.88 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual wellpath misses by 27.99ft at 10318.92ft MD (5888.85 ND, 3051.09 N, -3767.88 E) -Point u • 6/17/2008 3:33:29PM Page 11 COMPASS 2003.16 Build 42F P ConocoPhillips a ~~ Conoco hilli S p spII R ~UOMlS Baker Hughes INTEQ Survey Report Alaska INTEQ Company: ConoooPhillipa(Alaska)lnc. Local Co-ordinate Reference: Well 3F-18 Protect: Kuparuk RivecUnft ND Reference: Mean Sea Level Slte: Kuparuk 3F Pad MD Reference: 3F-16A (6~ 88:OOft (3F-16A) Well: 3F-16 North Reference: True Wellbore: 3F-16AL1-01 Survey Calcutatlon Method: Minimum Curvature Deaign: 3F-16AL1-01 Database: EDMv16 Prod Checked By: Approved By: Date: C~ J • 8/17/2008 3:33:29PM Page 12 COMPASS 2003.18 Build 42F KRU 3F-16A Injector with L1, L1-01 Laterals COI'IOCOP~"11~~1 S p Alaska, Inc. H. 4%z" Camco DB nipple, 3.875" min ID at 510' MD 9-S/8" 36f~ J55 ~ 3884' 0~~~ 7" 26# J-55 ~ 7015' MD 2-7/8" liner top 8206' MD Window in 4-1/2" KOP at 8226' MD via flow-thru whipstock A3/AZ sand perfs 8230' - 8246' MD 8662' - 8808' MD 4-1/2" 12.6# L-80 . 'Fill ~ 8580 MD' G. 4'/" Baker CMU sliding sleeve @ 6767' MD w/ 3.812" min ID F. Baker `BABE-3' packer at 6814' MD E. 4'/" Otis "X" nipple, 3.812" min ID at 6828' MD D. Baker seal assembly at 6829' MD C. 4'/z" muleshoe at 6831' MD B. Baker CMC liner hanger at 6841' MD 2-7/8" slotted liner, A. 4'/z" Camco DB nipple at 7846' MD all laterals 3F-16AL1-01 (Note: Milled out to 3.80" ID on 4/12/08.) TD @ 10 608' MD 41 /8" hole All laterals ~ ~~~~ - _ ~- ~/I - - - - - - - - / ~ / 3F-16AL1-P61 9775' -10,054' MD ~~ _.._ ...._ ~~ ..._ 3F-16AL1 TD @ 10,626' MD Aluminum billet KOP @ 8712' MD •I • June 4, 2008 BAKER I~I~IIE~ INTEQ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: June 26, 2008 Please find enclosed directional survey data for wells: 3F-16AL1 PB 1 3F-16AL1 3F-16AL1-O1~ ~~ak~~< <,~ ~ c 2D-06BL 1 ~, ~ " 0 ~t 3 - ~ v~c~.u IS ~~'S.r.1 ~`~ 4.. Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken o`~' 0 ~ _ p ~t y M Maunder, Thomas E (DOA) Page 1 of 1 From: Regg, James B (DOA) Sent: Wednesday, Apri130, 2008 4:39 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: KRU 3F-16A Redrills Martin -Regarding your question about flowing back wells to clean up prior to commencing injection... I confirmed our phone conversation with Tom Maunder since he handles the well permitting. Me indicated that it is usual far wells to flow back for a short period of time far clean-up prior to initiating injection. In the past we have used up to 30 days of flow back as a general guide before classifying the well as a producer, although we really do not have a specific time frame that we use. Really gets to intent -are you cleaning up to improve infectivity or are you producing the well. If the flow back resulted in classifying the well as a producer, CPAI would be required to submit paperwork to change the well to an injector before commencing injection. Based on what you explained for 3F-16A redrills, i.e., flow back was included in work procedure attached to the PTD application, and duration is estimated to be about 1 week, I don't forsee anything additional that we would need. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 7/29/2008 r ~ ALAS~iA OIL A1~TD GAS COI~TSER~ATIOI~T CODIl~IISSIOlOT 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 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 3F-16AL1-01 Conoco Phillips Alaska, Inc. Permit No: 208-044 Surface Location: 82' FSL, 227' FEL, SEC. 19, T12N, R09E, UM Bottomhole Location: 2556' FSL, 4054' 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 50-029-21502-01. 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. STATE OF ALASKA ~ ~~ 2 ~ ZOOS ALAS~IL AND GAS CONSERVATION COMMI~N (~ PERMIT TO DRILL Alaska Oil & Gas Cons. C~mmisn 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed or: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 • 11. Well Name and Number: Kuparuk 3F-16AL1-01 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10700 TVD 5797ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: ' FS ' S C 0 7. Property Designation: ADL 025632 River Pool 82 L, 227 FEL, E . 19, T12N, R 9E, UM Top of Productive Horizon: 3971' FSL, 3150' FEL, SEC. 19, T12N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2008 Total Depth: 2556' FSL, 4054' FEL, SEC. 19, T12N, R09E, UM 9. Acres in Property: s~ ?-~6 ~y•Z7•~$ 14. Distance to Nearest Property: 11,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-508273 • y-5985905 ~ Zone-ASP4 10. KB Elevation (Height above GL): 88 feet 15. Distance to Nearest Well Within Pool: 1,470' 16. Deviated Wells: Kickoff Depth: 10025 feet Maximum Hole An le: 102 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3955 Surface: 3349 18. Casin Pro ram: 5 ifi bo ns To - Settin ' De ttt - E3o ttom uantit of m nt c.f. or sacdcs Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1l8" 2-7/8" 6.4# L-80 STL 1100' 9600' 5915'ss 10700' 5797'ss Uncemented Slotted Liner 19. PRESE NT' WELL CONDITION SUMMARY (To be completed for'Redtill and Re-entry Operations) Total Depth MD (ft): 8580 Total Depth TVD (ft): 6301 Plugs (measured): None Effective Depth MD (ft): 8484 Effective Depth TVD (ft): 6230 Junk (measured): None asing Length ize Cement Volume MD D Conductor /Structural 115' 16" 328 sx Arcticset II 115' 115' Surface 3884' 9-518" 1125 sx Permafrost'E' 425 sx Class 'G' 3884' 3047' Intermediate 7015' 7" 250 sx Class 'G' 180 sx Permafrost'C' 7015' 5132' Produ i n Liner 1748' 4-1 /2" 250 sx Class 'G' 6832' - 8580' 5002' - 6301' Liner 3F-16AL1 475' 2-718" Uncemented Slotted Liner 10025' - 10500' 5884' - 5835'ss Perforation Depth MD (ft): 8230' - 8300' Perforation Depth TVD (ft): 6040' - 6093' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby ce that the fore oing is true and correct. Contact Gary Eller, 529-1979 (Cell) Printed Na Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date ~ ~ Terrie Hubble, 564-4628 - Commission Use Onl Permit To Drill ~ ,..~~ API Number: Number: ~~-%"~%~ 50-029-21502-61-00 Permit Approv I See cover letter for Date: 9 ~ 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: ~~ ~~~ ~ . ~O~ ;~ ~~ Samples Req'd: ^ yes LJ No Mud Log Req'd: ^ es l~No ~ ~ H S Measures: dyes ^ No Dir Tonal Survey Req'd: Yes ^ No Other: psi M i~ ~ ~ S~~l~ U ~ rc. C~~C~ ~IN~'~~iJe: , ~ i~ LTC ~~ C`~ .~ ~~(-~:, t APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 ~tevised (2/2005 j'~ ~ Submit In Du IiCate 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'/8" slotted liner to a TD of 10,500' MD. 2. The ALl-O1 lateral will kick off from the ALl 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'/s" slotted liner to a TD of 10,700' MD. 3. The final lateral, ALl-02, will kick off from the ALl lateral at 9600' MD and will also target the A3 Sands. The AL1-021ateral will be 700' in length and will be completed with 2'/s" 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: April 2008 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'/z" 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%" liner whipstock at 8230' MD with high-side orientation. RiE Work 1. MIRU Nordic Rig #2 using 2'/8" coil tubing. NU 7-1/16" BOPE, test. 2. 3F-16AL1 Lateral a. Mi113.80" 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'/a" slotted liner with aluminum billet from TD up to f 10,025' MD. 3. 3F-16AL1-O1 Latera ~~,~~ hag--~,,;y~.. a. Dri113.75" x 4'/8" bi-center horizontal AL1-O1 lateral in the A3 sand from 10,025' to TD at r 10,700' MD. b. Kill well. Run 2'/s" slotted liner with aluminum billet from TD up to (9600' MD. 4. 3F-16AL1-02 Latera a. Drill 3.75" x 4'/s" bi-center horizontal AL1-021ateral in the A3 sand from 9600' to TD at 10,300' MD. b. Kill well. Run 2'/g" and 3-3/16" slotted liner from TD up inside the motherbore at 8200' MD. 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. 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-O1: 2'/8', 6.4#, L-80, STL slotted liner from 9600' MD to 10,700' MD ' • 3F-16AL1-02: 2'/s", 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/s", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi. Production: 7", J-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Liner: 4'/z", L-80, 12.6 ppf 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 2'/e" 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 we113F-15 • 3F-16AL1-O1: 11,500' to property line, 1470' to we113F-15 - • 3F-16AL1-02: 11,500' to property line, 1900' to we113G-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 L1 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 well 3F-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 i 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 (510-511, Reference L Ref Lo Date: Last U ate: 8/7/2006 OD:4.500) Last Ta : 8299 TD: 8580 ftKB TUBING 0 6838 Last Ta Date: 7/28/2006 Max Hole An le: 54 d 3495 ( - , oD:a.SOO, Casin Strin -CONDUCTOR 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 -PRODUCTION Nordic SIDETRACK 7015' Descri lion Size To Bottom TVD Wt Grade Thread SLEEVE 7 PROD. CASING 7.000 0 7015 5130 26.00 J-55 (67x7-s sa, 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 (oao15• oD:7 aoo ' Tubin Strin -TUBING . , wt:zs.oo) Size To Bottom TVD Wt Grade Thread 4.500 0 6838 5005 12.75 L-80 ABM-EUE Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment P R 8230 - 8246 6039 - 6051 A-3 16 4 11/12/199 6 IPERF HSD Perf Gun, 180 deg. phasing; Oriented (+/-) 90 K (sala-sa1s, de . F/lowsid oo:s.151) 8266 - 8300 6066 - 6092 A-2 34 4 11/12/199 6 IPERF HSD Perf Gun, 180 deg. phasing; Oriented (+/-) 90 de . F/ lowsid Other lu s e ui .etc. -JEWELRY De th TVD T e Descri lion ID 510 510 NIP Camco'DB' Ni le 3.875 6767 4955 SLEEVE Baker CMU Slidin Sleeve; CLOSED 9123/96 3.812 6814 4988 PKR Baker'SABL-3' 3.875 NIP (saza-sazs 6828 4998 NIP Otis'X' Ni le 3.813 , OD:4.500) 6829 4999 SEAL Baker Locator SEAL ASSEMBLY 3.937 SEAL 6841 5007 HANGER BKER CMC MECHANICAL LINER HANGER 4.313 (sazs-sa3o, OD:4 500 7846 5745 NIP Camco'DB' 3.750 . ) 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) ----- i - KRU 3F-16AL1/L1-01/L1-02 Injector Proposed CTD Completion 3884' 7" 26# J-55 7015' MD G. 4-1/2" Camco DB nipple, 3.875" min ID at 510' MD F. 4-1/2" Baker CMU sliding sleeve @ 6767' MD w/ 3.812" min ID 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 B. Baker CMC liner hanger at 6841' MD A. 4-'/z" Camco DB nipple, 3.75" min ID at 7846' MD (milled out to 3.80" ID) • 3F-16AL1-01 A3 Lateral, TD @ 10,700' MD - - - ConocoPhilli s p Alaska, Inc. 2-7/8" slotted liner, 12 slots/ft, 1 /8" slot width .~ - - /~ - - - 3-3/16" liner top @ / ~ 3F-16AL1-02 A3 Lateral, +/-8200' MD 4-1/8" hole ~ / TD @ 10,300' MD ° o All laterals Window in 4-1/2" / ~ / KOP at 8230' MD ° °R ° - ~ ~ - - - - A3/A2 sand perfs 8230' - 8246' MD 8662' - 8808' MD 4-1/2" 12.6M L-80 I F~II (p3 8580 MD' ~ ._ ~ -, 5 • ~O 3-3/16" pre-drilled :OS ~L~~ liner to - 8650' and r°c~ h'4 Aluminum billet KOP @ 10025' MD Aluminum billet KOP @ 9600' MD 3F-16AL1 A2 Lateral, TD @ 10,500' MD March 20, 2008 • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3F Pad 3F-16 Plan 4, 3F-16AL1-01 Plan: Plan #4 Baker Hughes INTEQ Planning Repo 17 March, 2008 ~~~~ BAKER FI~I~MES INTEQ • ConocoPhillips sn ~R ~ Baker Hughes INTEQ Planning Report ~ INTEQ Company: ConocoPhillips(Alaska) inc. Local Co-ortlinate Reference: Well 3F-16 Project: Kuparuk River Unit TVD Reference: 3F-16A ~ 88:OOft (3F-16A) Site: Kuparuk 3F Pad MD Reference: 3F-16A @ 88.OOft (3F-16A) Weli: 3F-16 North Reference: True Wellbore: Plan 4, 3F-16AL1-01 Survey Calculation Method: Minimum 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 +NI-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 Ilbore Plan 4, 3F-16AL1-01 gnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 3/12/2008 17.70 79.75 57,268 Design Plan #4 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,025.00 Vertical Section: Depth From (TVD) +N/•S +Ef-W Direction (ft) (ft) (ft) (°) 88.00 0.00 0.00 183.00 Survey Tool Program Date 3/17/2008 From To (ft) (ft) Survey (Weltbore) 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 10,025.00 Plan #4 (Plan 4, 3F-16AL1) MWD MWD -Standard 10,025.00 10,700.00 Plan #4 (Plan 4, 3F-16AL1-01) MWD MWD -Standard Planned Survey i MD Inc Azi NDSS NIS E/W Northing Easting (ft) l°I (°) (ft) lft) (ft) (ft) (ftl 10,025.00 91.77 178.56 5,884.55 3,128.19 -3,790.10 5,989,028.64 504,479.56 - fCOP -Build DLS 15 10,087.00 101.07 178.56 5,877.63 3,066.67 -3,788.56 5,988,967.12 504,481.17 Start DLS 15 TFO 290 10,100.00 101.73 176.69 5,875.06 3,053.93 -3,788.03 5,988,954.39 504,481.71 10,107.00 102.08 175.68 5,873.61 3,047.10 -3,787.58 5,988,947.56 504,482.18 Start DLS 15 TFO 270 10,182.00 101.84 164.18 5,858.02 2,974.99 -3,774.77 5,988,875.47 504,495.06 Start DLS 15 TFO 80 3/17/2008 2:54:17PM Paga 2 COMPASS 2003.16 Build 42F C~ Company: ConocoPhiNips(Alaska) Inca Project: Kuparuk River Unit Site: Kuparuk3F-Pad Well: 3F-16 Wellbore: Plan 4, 3F-16AL1-01 Design: Plan #4 ConocoPhillips Baker Hughes INTEQ Planning Report Locat Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: r~ LJ 1~ia~ ss INTEQ We113F-16 3F-16A @ 88:OOft(3F-16A) 3F-16A (~ 88.OOft (3F-16A) True Minimum Curvature EDMv16 Prod Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting (tt) (°) (°) (ft) (ft) (ft) (ftl (ft) 10,200.00 101.83 166.94 5,854.33 2,957.93 -3,770.38 5,988,858.42 504,499.47 10,300.00 101.27 182.24 5,834.19 2,860.70 -3,761.19 5,988,761.21 504,508.77 10,332.00 100.93 187.12 5,828.03 2,829.42 -3,763.75 5,988,729.92 504,506.24 Start DLS 15 TFO 110 10,400.00 97.30 196.78 5,817.23 2,763.83 -3,777.67 5,988,664.33 504,492.40 10,467.00 93.53 206.14 5,810.89 2,701.84 -3,802.05 5,988,602.32 504,468.08 Start DL515 TFO270 10,500.00 93.52 201.18 5,808.86 2,671.68 -3,815.27 5,988,572.15 504,454.90 10,600.00 93.32 186.16 5,802.86 2,574.97 -3,838.79 5,988,475.42 504,431.50 10,700.00 92.90 171.14 5,797.40 2,475.43 -3,836.43 5,988,375.89 504,433.96 TD at 10700 - 2 7l8" 3/17/2008 2:54:17PM Page 3 COMPASS 2003.18 Build 42F emKm s..w~ m iiu.m= izo mm~ Kuparuk~D BOP Configuration for Managed Pressu"~ Drilling 2'/s" CT Well I 3F-16A Floor Lubricator ID = 6.375" with 6" Otis Unions 1 f-- 7 1/16" 5000 psi, RX-46 7 1/16" 5000 psi RX-46 Tree Size 4-1/16", 5M SSV Master Valve Base Flan e Page 1 C7 TRANSMITTAL LETTER CHECKLIST WELL NAME I~~u .X ' ~~~~/ '"'~ PTD# __ ~ U y ~ (~ ~~ Development y Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Q~-u ~ K !~-~''~ r __.~~ POOL: _ '~.~ - .._ ~ oc.lG. Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter ~~6:~ ~a,/ CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore se ent of existing well 1~i~~ .~F~'~~ (If last two digits in permit No. ~9t'o - ~S~ ,API No. 50-!SZ - ~~ a API number are - ~ ___, between 60-69~ P ~ n should continue to be reported as a function of the . ~,JG original API number stated above. ~1 PILOT HO LE 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 Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Comnany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/1 l/2008 ALL PERMIT CNECKLISfi Field & Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 3F-16AL1-01 Program SfR Well bore see 0 PTD#:2080440 Company CDNOCOPHILLIPS ALASKA INC Initial Class/Type SER I PEND GeoArea 890 Unit 11160 OnlOff Shore ~_ Annular Disposal ^ Administratioa 1 P®rmhfeeattached- ------ ----- --- ------ - -- --- -- NA-- - ------------- -- --- -- 2 Lease numberappropriate_______-_____-__-_______--_____.__--- 1`_es- ------Erttirav~+flllwilllis irtARL025635•------------------.--------.. 3 Uniquswellrlameandnumber_.___--___.------------------------- Yes- --.---.----------__-_-- --------------------------------------------------- 4 WBiI located in_a-definedpool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ . _ KUPARUK RIVER,_KUPARUK_RV Qil. r 420144, governed by Conservation Order No. 432C._ - - - - - _ _ _ _ _ _ - 5 VYell_located proper distance from Bailing unit_boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - . _ _ Cortsarvaiion Order No. 4320 contains no spac~g restrictions with respect_to drilling unit boundaries. - _ _ _ _ - - _ 6 VyslUocated Proper distance. from other wslls_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ Conservation Order No. 432C has no interwell-spacing-restrictions, _ - - _ _ - - _ _ - - _ - - _ - - - _ - _ _ . _ _ _ - . 7 Sufficient acreage ayailabls in_dtilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - - - _ _ _ _ _ Yes _ - _ _ - - _ Conservation Order No. 432C hasng interweli-spacing.restrictions, Wellbore-wil[ be_more than 540' from _ - _ _ _ _ 8 If deviated, iawelibors platincJuded _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ - - an exterrral property lin®whete_own8rship or landownership changes. - - .. - _ . - _ _ _ _ _ _ - - _ _ _ _ _ - - _ _ _ 9 O~+eratoronlyaffectadpgrb- ------...-~-----~ --- -- -- -- --- Yes- ---- --- --~ ----- ------ ------- ----- ---- -- - - -- ---------- 10 Opsratorbas.aADropriatebondiniores- ---- ---- -- ---- -- ------ Yes. -- -- - --- -- --- -- - ------ ------- --- -- ----- --- ----- 11 PermitcanbsissuedwithcutCOnssrvationordsr---------------------------- Yes- ----------......--------------.---------------------------.-.------_----- Appr Date 12 Permitcanbs'tssuedwithoutadmipl~t[atnce_approval------------------------- Yes- -------.-----------------..--.--.----.---._.--..----------------_----- SFD 312712008 13 CanpermiibeapP--roved beforel5•daywait------------------------------- Yes- -----------.--.----------.-----------------------------.------------__---- 14 Wflll Iccated within area and strata authored by_ Injection 9rder # (put 14# jn_comments)-(FOr_ Yes _ . _ . _ _ -Area injection Order No.-2B _ _ __ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 Allwelis_within1f4mi~arka.ofreviawidentifisd(Forservicewei!only)--------------- Yas- ------3F•16,whictlhes_bssnPBsA'd•-----------------------------------.------------. 16 Pre•producsdinle~or;durationofpreproduolionlesathan3months(Forserv(cawalianlY)-- -~ _ ------------------------------------------------------------------------ 17 Noncomen,gas_confomrslaAS31.05A3Q(j,1.A)a4.2,A-i)) -- -- - -- -~-- ------- -~ -- -- --- -- --- ---------- ------------- - -------- - Engineedng 18 Conductor 6t[irtg_plovidgd----------------------------------------- -NA- ------Conductors5tin 3F•15(1$5.2@4)•----------------------------------------------- 19 SuCface_casingprotsctsallknownUSDWs_____________________--------- -NA-- -----Aliaqurfers exempted44CFR147.102-(b)(3),------------_-------------------------- 20 CMTvoladequat®tocitcu(ate_onconductori'tsurfcsg----.-_--------------- -NA-- ------Surfaoecasingsstin3F-18---------------------------------------------------- 21 CMTvoladequaietotis•inlQngstringtosu[fs„tg.-_________________________ NA._ ___Produciioncasingsetin3f-16,--__-__-__-..____-.____,--_-______--__-__-___-___ 22 CMT-will cover-ail known_productiveharizona-__--_----------------------- Yes. ------------------------------------------------.-------------------_----- 23 Casing designs adequate forC,TB&-permafrost--------------------------- Yes- ---------------.---.----.--------------------------------------- _-._-- 24 Adequate_tartkage_ or teserve Dh - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ Rig equipped with steel pits, No_resenre pit pianned,_ Ali waste_io apRroved disposal well(s), _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Ifare~dri5,has_a10.403farabandonmentkaenaPRroved---------------------- -NA- -----------------------------------------..-...-------------------------- 26 Adequate_wellbore separaUonproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - Pr9ximity anaisyai performed, Nearest segment is 3F•16A11 and patties divergs,_ . - . - - _ _ _ - _ _ _ _ . _ _ - _ - 27 I(dive[ter-required,Bees)tmestrsgulationa----------------------------- -NA-- ------QOPStaokwillalready-heir!place-------------------------------.-.------------- Appr Date 26 Arilling fluid program sohematlc_& equip list sdsquaks__ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - _ . _ _ Maximum a>4pectsd totmation pressure 12:6 EMW._ Wsll will bedrilled with_managed-pressure and 10.Q ppg fluid - TEM 41412008 29 BOPIS,.do theymeet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ . . _ 2 wellbore volumas_of i(yV fluid_w~i be_available inKuparuk Eield during drilling operakions._ - - _ _ _ _ _ _ - _ _ _ 30 BOPE-press rating appropriats;.test to_(puf pale (n comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ _ _ _ MASP calculated at 3349 psi, 4000_psi_BOP teatplanned, _ _ _ _ _ _ - - _ _ - _ _ - _ _ _ - - _ _ - - _ _ - _ . _ - _ _ _ 31 Choke.manifoldcomplisswlAPiRP•;i3(MayB4)-- - - ---- -- -- ----- Yes- ---- -- --- -- -- -- ---------- -- - - - - -- -- ---- - 32 _V11Qrkwiii9ccurwith9utop6rationshutdown----------.----------------- Yes- ---------------------------------------------------------.--------------. 33 IB Rresencs of ii2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - - _ - - _ M2$ is rsp9Rsd_at 3F pad. _Mud shqukl_prsclude N2S on [ig, _ Rig has sensors_and alarms, _ _ _ - _ - - _ _ _ _ _ _ _ 34 _Meshanicalcondition ofwells within AQR veafied (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ . No known integrity issue fl 3F•16A, This segment departs in Kuparuk-resenroir._ No issues identifred. _ _ . - . _ - _ Geology 35 Pe[mitc,an be issued w/o hyslrogertauhiderneasures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ . _ _ _ _ _ _ Wel~s_on 3F-Pad produce between 50 and275 ppm H2S. _H2S_monitors will b8 used. _ _ _ - . - _ . _ _ - _ _ - - 36 Datapresented on potential overprsssurezones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ . _ - _ _ Expected resenroirpiessure is 12.6 ppg EMW. Wih be drUlsdwiih_19,0_ppg usingmanagsd_pressure _ _ - - _ _ _ _ Appr Date 37 Seismicanalyeisofshaiiowgaszones__________-____________________ _NA_ .__.------------.-.- ------------------------------------------------------ SFD 3127/2008 38 Seabed-co~itionsurvey.(if off-share)--------------------------------- -NA__ __--__-- 39 Contaotnamslphoneforweek%r-Rrogressreporis_[exploratoryonl~-______________ NA__ _________________________________-----..-------.------.----------___-- Geologic Data: Engineering Date Public Date Spoke injection weNbore to be drilled from the KRU 3F-16AL1 lateral. Commissioner. Commssioner: Commissioner
