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210-026
DATA SUBMITTAL COMPLIANCE REPORT 10/25/2011 Permit to Drill 2100260 Well Name /No. KUPARUK RIV UNIT 1Q -03A Operator CONOCOPHILLIPS ALASKA INC API No. 50 -029- 21249 -01 -00 MD 12560 TVD 6738 Completion Date 5/13/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments "r ED C Lis 19876 n-1 duction /Resistivity 9728 12560 Open 7/15/2010 OH LIS EWR logs in TIFF, CGM, and PDF graphics g Induction /Resistivity 2 Col 10299 12560 Open 7/15/2010 MD MPR, GR i{og Induction /Resistivity 5 Col 10299 12560 Open 7/15/2010 MD MPR, GR g Induction /Resistivity 5 Col 10299 12560 Open 7/15/2010 TVD MPR, GR C Asc Directional Survey 10275 12560 Open pt Directional Survey 10275 12560 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments III ADDITIONAL INFORMATION /l Well Cored? Y Daily History Received? N Chips Received? -Y"rfl Formation Tops -8 / N Analysis Received? Comments: Date: .- J O O W Compliance Reviewed By: —_— - RE(,,,,,ENIE c 2/0 - C34:9 Co ..„ i ii 3 . 9 - 6 Company BAKER ConocoPhillips, Alaska, Inc. Well Name 1Q-03A 1 JUL 5 ?(I1(i HUGHES ,. ,•,.., Ott & r4;us CultiN_ (,:, iiN T E (:-.) At iftlit,4 7/13/2010 Date ;;,• , l' - ''. ConocoPhillips Alaska Greater Kuparuk Area*** Data D Data i ; , ' ! '''',. ';‘ ,, ' ' ' ' ' ' ' .' ! , . 1`.4.‘',:'''.J't ■i):,iti,1!".1,1,,,,I,itt,S-0; OH FINAL OH FINAL , ,, ,, , ,,, • contact: Lisa Wright, 907 263-4823 prints ,, , ,, , ,, ,, ,.! .!!, ; '...!',, ;,...,,,, ,,,-,;,•i,,,,,N;`,".i';',;‘,"„c:',',t4'. ,,,, ,,, , ; -„ ! ,, ; Image files and/or Digital Data r , ,,,,0,1,1,,, !,=, '' ,' !::::: ' f ", ''' I '', „ No other distribution is allowed without O written approval from ConocoPhillips , hardcopY ! ,. ,,!;.t. " ,r. " , ' 4 _ , I , r!qc , II . ,f ) .kii , ,,,,k,i0.`" ..".,; • , ConocoPhillips Alaska, Inc. '. . Sharon Allsup-Drake ...' Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. ' 1 Hardcopy Print , , ,t, r)-filr,,:74t,1‘4(14,4,.,e'°?4,1))-q NSK Wells Aide, NSK 69 ATTN: MAIL ROOM , 700 G Street, i Anchorage, AK 99501 ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk*/ File**/*** Electronic CGM / TIFF LIS : 7.04:)-G Street, . , Ausher ■ , - . *.* , ftp://b2bftp.conocophillips.com * , 1 Hardcopy Print, . Christine Mahnken AOGCC ., 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 I Print, ' Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ • ** Electronic sepi David Douglas in lieu of sep i CGM/TIFF P.O. Box 196612 Anchorage, Alaska 99519-6612 1 Hardcopy Print, CHEVRON/KRU REP ' Glenn Fredrick image . 1 D' I*/ , 1 Graphic P.O.Box 196247 : in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS 13i'andoil 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 DS Engineer / Rig Foreman TOTAL , Hardcopy Prints 4 Page 1 of 4 • • Page 1 of 1 Maunder, Thomas E (DOA) 2( -014- From: Eller, J Gary [ J.Gary.Eller@conocophillips.com] Sent: Monday, July 12, 2010 10:43 AM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay; Gantt, Lamar L; Venhaus, Dan E; Nabors CDR2 Company Man; Ohlinger, James J; Long, Jill W Subject: RE: 1Q-03A (210 -026) Tom In answer to your questions on the 1Q -03, this well did get bounced between engineers a little because of work schedules. James Ohlinger was originally the primary, but he had to leave town and it subsequently got bounced between Jill and I. I also apologize for the tardy reply to your message, which was also due to changing work /vacation schedules. -Gary Eller CPAI CTD -Wells Engineer From: Maunder, Thomas E (DOA) jmailto:tom.maunder@alaska.gov] Sent: Friday, July 02, 2010 3:03 PM To: Eller, 3 Gary; Ohlinger, James 3 Cc: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: 1Q -03A (210 -026) Gentlemen, Not sure who did this well. I have reviewed the completion report recently submitted and have a couple of questions. 1. During operations late on April 23, it is stated "...chic for BPV..." Was a BPV in the well? [Eller, J Gary] There was not a BPV in the well. During pre -rig operations the perforations were cement squeezed to 2000 psi and subsequently passed a no -flow test prior to rig move. 2. About dinner on 4/24, it is noted that the spaceout was incorrect for the BOP test joint for the testing conducted late on 4/23 and that the 2 -3/8" slip rams may have been damaged. This was later confirmed. Was there any indication of problems when the BOP test was conducted? What was different about the spaceout on this well versus others recently drilled? What process change has been implemented to insure a similar problem is not encountered in the future? [Eller, J Gary] There was no difference in the ram configuration or spacing on this well. This problem was caused by a deviation from the detailed BOP test procedure and failure to adjust back to the procedure after the deviation. After the tree valves were pressure tested, the swab was opened to check for a BPV because there was confusion whether one had been set. But the swab was not closed back which put them off their procedure — this was the deviation I mentioned. Because of this the spaceout of the test joint was deeper than normal, so that the slips closed upon an upset in the test joint and broke apart. The rig crew discovered that the test joint was off depth but did not realize that the slips had already been damaged. The ram was then successfully pressure tested despite having broken slips. To make sure we don't have a repeat of this error, a hard copy of the checklist is prepared and each step is initialed by the Driller and Tool Pusher as they are completed. The checklists are then preserved for audit purposes to confirm they have been followed correctly. Thanks in advance, Tom Maunder, PE AOGCC 7/12/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 15, 2010 210 - 0260 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 29, 2010 50 029 - 21249 - 01 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1216' FNL, 1116' FEL, Sec. 26, T12N, R9E, UM May 3, 2010 1Q - 03A Top of Productive Horizon: 8. KB (ft above MSL): 90' RKB 15. Field /Pool(s): 1016' FNL, 1025' FEL, Sec. 24, T12N, R9E, UM GL (ft above MSL): 47.5' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 46' FSL, 992' FEL, Sec. 13, T12N, R9E, UM 12487' MD / 6746' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 528507 y - 5984657 Zone 4 12560' MD / 6738' TVD ADL 25641, 25634 TPI: x - 533852 y - 5990159 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x - 533881 y - 5991220 Zone 4 1763' MD / 1681' TVD 2572, 2567 18. Directional Survey: Yes Q No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1400' MD / 1400' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/Res 10297' MD / 6575' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H -40 Surf. 101' Surf. 101' 24" 240 sx CS II 9.625" 36# J -55 Surf. 5224' Surf. 3636' 12.25" 1300 sx CS III, 550 sx CS 1, 89 sx CS1 1 7" 26# J -55 Surf. 10910' Surf. 6916' 8.5" 470 sx Class G, 250 sc CS 1 2 -3/8" 4.7# L -80 11512' 12487' 6737' 6746' 3" slotted liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 10421' 10008' MD / 6399' TVD slotted liner from 11512'- 12487' MD 6737-6746' TVD 10348' MD / 6598' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. C011PLEnCiti DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ` T6 ` one 1 t "' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 22, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 5/25/2010 18 hours Test Period - -> 598 1096 289 209 Bean 2040 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 171 psi 1307 24 -Hour Rate -> 738 1507 381 24 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q 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 25.071. RECEIVED NONE JUN 1 1 2010 Alaska Oil & Gas Coen. Commission Form 10 -407 Revised 12/2009 RBDMS JUN Z ' 1 LO I C N I U D ON REVERSE AdadhOtaltial only h e . q i .. ?t 7,.‘,//d 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1400' 1400' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk A4 10661' 6728' Kuparuk A4 invert 12450' 6752' Kuparuk A3 10690' 6738' Kuparuk A5 12480' 6748' N/A Formation at total depth: Kuparuk A6 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263 - 4093 0(0110iLD Printed Na C, , . e Title: Alaska Wells Manager r /0 ` Signature , '11 ". 0111 +{ r Phone 265 - 6306 Date TL_�c(4 i Ucy Sharon Allsup -Drake INSTRUCTIONS General: 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. Item 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. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 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). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 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. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • ConacoPhitlips Time Log & Summary Wellvlew Web Reporting Report Well Name: 1Q -03 Rig Name: NABORS CDR2 - AC Job Type: DRILLING SIDETRACK Rig Accept: 4/23/2010 11:00:00 AM Rig Release: 5/15/2010 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/20/2010 24 hr summary Rig released from 1E-15 at 18:00. Waiting on trucks for rig move 18:00 00:00 6.00 MIRU MOVE MOB T Waiting on peak trucks to move rig 04/21/2010 Waiting on trucks for rig move 00:00 00:00 24.00 MIRU MOVE MOB T Waiting on peak trucks to move rig 04/22/2010 Waiting on trucks for rig move until 1930, then continue with RDMO 00:00 19:30 19.50 MIRU MOVE MOB T Waiting on trucks for rig move 19:30 00 :00 4.50 MIRU MOVE MOB P Peak trucks arrived on location. Continue with RDMO 04/23/2010 Travel To 1Q -03, MIRU, Test BOP 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Arrive on 1 Q pad, PJSM to spot rig on well and pits sub to drilling sub 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Spot Drilling sub, Spot mud sub, Unload shop 09:00 11:00 2.00 0 0 MIRU MOVE RURD P Rig up inter -tie, steam, comms, high line power, stairs, cellar 11:00 12:00 1.00 0 0 MIRU MOVE SFTY P Pre Spud meeting / TransOcean Deep water Horizon Safety stand up ** *Rig accept at 11:00 * ** 12:00 15:00 3.00 0 0 MIRU WHDBO BOPE P Pull BHI check valves and fill coil, check for BPV, test tree valves 15:00 00:00 9.00 0 0 MIRU WHDBO BOPE P BOPE Test. Witness of test waived by Bob Noble, AOGCC 04/24/2010 Ran dummy WS to 3455' running into junk. Discovered that the deployment rams had been damaged during BOP testing and pieces had fallen down hole, recovered with magnet runs on coil. Repaired and tested deployment rams. 00:00 01:00 1.00 0 MIRU WHDBO BOPE P Continue with BOP testing 01:00 02:48 1.80 0 MIRU WHDBO PRTS P PT PDL's and TT line, 02:48 03:00 0.20 0 PROD1 RPEQP1 SFTY P PJSM for PU BHA 03:00 04:30 1.50 0 71 PROD1 RPEQP1 PULD P PU BHA #1, SSV was partially shut, call DSO to open. 04:30 05:30 1.00 71 3,455 PROD1 RPEQP1TRIP P RIH with BHA #1, circulating SW, returns to TT Page 1 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 3,455 3,455 PROD1 RPEQP1TRIP P Set down with dummy whipstock © 3455', PUH 100' RBI and set down @ 3390 multiple times at different speeds and pump rates. No packing off obseved from out rates. Solid setdowns with clean pick ups. POOH to inspect BHA. 06:00 07:00 1.00 3,390 0 PROD1 RPEQP1 TRIP T Set down with dummy whipstock © 3455', PUH 100' RBI and set down © 3390 multiple times at different speeds and pump rates. No packing off obseved from out rates. Solid setdowns with clean pick ups. POOH to inspect BHA. ** *Start Nabors Down Time * ** 07:00 08:15 1.25 0 0 PROD1 RPEQP1PULD T At surface, PJSM while observing the well for flow. Pull BHA #1 Dummy whipstock. M/U BHA #2 straight motor with 2.79 parabolic mill 08:15 09:00 0.75 0 3,389 PROD1 RPEQP1TRIP T RIH to investigate down hole obstruction 09:00 11:00 2.00 3,389 3,490 PROD1 RPEQP1TRIP T Dry tag @ 3389, 5K WOB, Pick up, Pump online 1.15 BPM @ 1670, run through 3390 area saw 2K WOB. Picked up speed RIH to 3454, Tagged. worked area. Stalled once 5K wob. Lost WOB after milling 3 minutes RIH to see if it obstruction would hang up in next tool joint. Get to 3490. POOH for magnet 11:00 12:30 1.50 0 0 PROD1 RPEQP1PULD T At surface, PJSM while flow checking well, Shorten Coil trak, M/U magnet run BHA #3 12:30 14:45 2.25 0 3,550 PROD1 RPEQP1TRIP T Trip in hole with Magnet, Run to 3550 POOH 50FPM. POOH 14:45 15:45 1.00 3,550 0 PROD1 RPEQPI PULD T At surface, PJSM while flow checking. Pull BHA. Nothing but metal shavings. rerun magnet. 15:45 18:45 3.00 0 3,904 PROD1 RPEQP1TRIP T RIH with 2.60 Magnet, take weight @3699 continue in to 3904. POOH @50 FPM 18:45 19:15 0.50 3,904 0 PROD1 RPEQP1PULD T At changeout time the night driller brought to our attention that they had 0 . an improper spaceout with the BOP test joint and that may have damaged the 2 3/8" slip rams. Recovered three pieces of fish on the magnet. Also found damage on the test joint indicating spacing was two feet off and lower rams were closed on the no -go section of the test joint. Page 2 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 23:30 4.25 0 0 PROD1 RPEQP1 EQRP T Pulled all 2 3/8" ram inserts and found lower set damaged with missing pieces from slips. Replaced lower rams and resealed upper rams. After clsing doors and functioning all rams found another piece of broken ram on top of the swab valve. This accounts for all of the slip pieces. 23:30 00:00 0.50 0 0 PROD1 RPEQP1 EQRP T Tested upper and lower 2 3/8" slip rams to 250 /3000psi. Charted tests. 04/25/2010 Ran dummy WS to 10337', set WS at 10297', started window milling, pinch point at 10299.3' 00:00 00:30 0.50 0 0 PROD1 RPEQP1 EQRP T Testing 2 3/8" deployment rams. 00:30 01:12 0.70 0 0 PROD1 RPEQP1PULD T PU Dummy WS and Jars, BHA # 5 01:12 02:00 0.80 0 3,390 PROD1 RPEQP1TRIP T RIH ** *Nabors down time ends at 0200, 20 Hours total * ** 02:00 03:24 1.40 3,390 9,760 PROD1 RPEQP1TRIP P Continue RIH, no issues or weight problems going through 5440' area. 03:24 03:48 0.40 9,760 9,811 PROD1 RPEQP1DLOG P Tie into formation, +14' 03:48 04:06 0.30 9,811 10,337 PROD1 RPEQP1TRIP P Continue RIH, 14K RIW 04:06 06:15 2.15 10,337 0 PROD1 RPEQP1TRIP P Tao bottom at 10337', 36K PUW, POOH 06:15 07:30 1.25 0 0 PROD1 RPEQP1PULD P At surface, PJSM while flow checking well. Pull Dummy whipstock M/U Whipstock with 4 degree kick plate removed, Surface test tool Tag up on stripper, Set depth, confirm EDC open 07:30 10:00 2.50 0 9,750 PROD1 WHPST TRIP P RIH with Whipstock 10:00 10:15 0.25 9,750 9,781 PROD1 WHPST DLOG P 9750', perform Gamma Tie in. +15' correction 10:15 10:30 0.25 9,781 10,315 PROD1 WHPST TRIP P 9781 RIH to 10315', PUH to set depth @10306.9, TOW =10297 Pumps to .5 BPM. good indication of set @2935 PSI PUH 20', roll hole to milling fluid, Continue out of hole 10:30 13:15 2.75 10,315 0 PROD1 WHPST TRIP P Stop 200' from surface, Shut edc. Tag up and monitor well for flow while conducting PJSM 13:15 14:00 0.75 0 0 PROD1 WHPST PULD P Lay down BHA #6 whipstock setting run, M/U BHA #7 straight motor for first window milling stage Function Test Upper and Lower 2 3/8 deployment Rams 14:00 14:45 0.75 0 0 PROD1 WHPST PULD P P/U BHA # 7, Window milling BHA, test tool 14:45 16:30 1.75 0 9,735 PROD1 WHPST TRIP P Trip in with window mill on straight motor 16:30 16:45 0.25 9,735 9,752 PROD1 WHPST DLOG P Gamma tie In, +15' correction Page 3 of 23 "- Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 17:00 0.25 9,752 10,279 PROD1 WHPST TRIP P RIH to dry tag whipstock @ 10297, PUH, kick on pumps, Mill 11:00 1 f:b4 LT. 10,2/9 10,299 PROD1 OD1 WFIPST P 10297, Mill Window 1.3 BPM @ 4000 PSI FS Having some trouble getting a pattern IQ -(0 3 , #41 - - 11)14h l a started, reconfirm dry tag, 10299.3 is the pinch point 17:54 00:00 6.10 10,299 10,303 PROD1 WHPST MILL P Start time milling window from 10299.3', 9K RIW, 1.3 BPM, 3900 CTP, 100 motor work with .5 to 1K WOB 04/26/2010 Completed first window milling run, tripped for BHA, milled window and 10' formation. 00:00 02:30 2.50 10,303 10,305 PROD1 WHPST MILL P Continue milling window in 3 1/2" tubing at 10303.4. 1.3 BPM, 3700 CTP, 1 - 2K WOB, 100 -150 motor work. 02:30 03:30 1.00 10,305 10,305 PROD1 WHPST REAM P Motor work and WOB dropped off at 5.7', start reaming window area, three times up and down 03:30 06:00 2.50 10,305 0 PROD1 WHPST TRIP P POOH 06:00 08:45 2.75 0 0 PROD1 WHPST PULD P At Surface, crew change, PJSM while flow checking well, UD BHA #7 Mill 2.79 No -Go M/U BHA #8 with Weatherford 2.5 degree fixed bend motor and 2.8 fat radius mill. Very difficult getting BHA through tree and tubing hanger. Stop to discuss option / change of scope 08:45 11:00 2.25 0 9,745 PROD1 WHPST TRIP P RIH with edc shut to slowly roll bit to keep from finding tubing joints 11:00 11:15 0.25 9,745 9,781 PROD1 WHPST DLOG P 9745' Gamma tie in for a +15' correction 11:15 11:30 0.25 9,781 10,305 PROD1 WHPST TRIP P Dry Tag @ 10305, 11:30 17:00 5.50 10,305 10,308 PROD1 WHPST MILL P Start time milling per program 1.3 BPM @ 3900 PSI FS 17:00 19:36 2.60 10,308 10,311 PROD1 WHPST MILL P WOB and motor work dropped off, most likely exited casing, continue at 1 FPH 19:36 21:00 1.40 10,311 10,318 PROD1 WHPST DRLG P Milling formation, 4K RIW, 3900 CTP, 1.3 BPM, 4 -6 ROP 21:00 22:12 1.20 10,318 10,306 PROD1 WHPST REAM P Back ream at 30L, RIH 15R, Back ream 45R, RIH 15R with pump down, tag up in window at 10306', back ream out and tag again with pump at 1.3 BPM. tagged at about 10306 -7' 22:12 00:00 1.80 10,306 0 PROD1 WHPST TRIP P POOH, Follow MPD tripping schedule 04/27/2010 Deploy BHA 9, (1.6 deg AKO with bald nose 2.8" Crayola mill), RIH Dressing window from 10300' to 10316' with multiple passes, POOH, Unde loy BHA 9. Repair injector head replacin skates. 00:00 00:18 0.30 0 �0 PROD1 WHPST SFTY P PJSM for undeploy /deploy Page 4 of 23 S lime Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:18 02:30 2.20 0 0 PROD1 WHPST PULD P Undeploy BHA #8, Deploy BHA #9, maintain injector Fat radius mill came out at 2.80 go/ 2.79 no -go 02:30 04:45 2.25 0 9,745 PROD1 WHPST TRIP P RIH with 1.6 deg. motor and a 2.80" _ bald faced cravola mill following MPD tripping schedule 04:45 05:00 0.25 9,745 9,784 PROD1 WHPST DLOG P Gamma tie in for a Plus 13' correction, Shut EDC, RIH to dress window 05:00 05:30 0.50 9,784 10,308 PROD1 WHPST TRIP P Continue trip in to dress window Took weight @ 10306 went through and set down 4K @ 10309 Dry 05:30 05:54 0.40 10,308 10,315 PROD1 WHPST REAM P Reamed down from 10300 ream down to 10316, Upreamed to 10305 stalled and bit stuck. Relaxed pump, Worked and down got to neutral weight. Kicked on pumps came free. PUH and started down ream pass @ 1 FPM 05:54 06:54 1.00 10,315 10,295 PROD1 WHPST REAM P Continue reaming, RIH at as drilled, PUH as driller 15R, Ream down 15R Up @60R 06:54 07:24 0.50 10,295 10,295 PROD1 WHPST REAM P Reaming in @ 15R stalled @10303 Restart pass 07:24 10:30 3.10 10,295 10,318 PROD1 WHPST REAM P Continue reaming, total of 8 up passes at 75L to 105R. Shut down pump and ran down clean, pulled up clean. Swap to new mud 10:30 12:30 2.00 10,318 0 PROD1 WHPST TRIP P Open EDC and POOH following MPD tripping schedule 12:30 12:42 0.20 0 0 PROD1 WHPST SFTY P PJSM for undeploy 12:42 14:00 1.30 0 0 PROD1 WHPST PULD P Undeploy BHA # 9. Maintain injector, found thrust bearing pieces in sump. 14 :00 00:00 10.00 0 0 PROD1 DRILL RGRP T Start Injector Skate Replacement * **Start Nabors Downtime * ** 04/28/2010 Complete Injector skate repair. Diassemble Injector inspecting skates for proper installation of skates 00:00 04:30 4.50 0 0 PROD1 DRILL RGRP T Repair skates in injector head 04:30 04:45 0.25 0 0 PROD1 DRILL RGRP T PJSM for stabbing CT 04:45 10:45 6.00 0 0 PROD1 DRILL RGRP T Stab CT, MU CTC, Drilling Pull test Psi test, Install depth counter 10:45 11:00 0.25 0 0 PROD1 DRILL RGRP T PJSM unstab CT 11:00 17:30 6.50 0 0 PROD1 DRILL RGRP T Unstab CT, remove skates on injector head, install tephlon bushings correctly onto skates. Install skates into injector head 17:30 18:15 0.75 0 0 PROD1 DRILL RGRP T Crew change, PJSM 18:15 22:15 4.00 0 0 PROD1 DRILL RGRP T Continue working on injector head 22:15 22:30 0.25 0 0 PROD1 DRILL RGRP T PJSM Stabbing CT Page 5 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 PROD1 DRILL RGRP T Stab CT, MU CTC and Pull test 04/29/2010 Complete Installation of injector Skates. Deploy BHA 10, Drill "A" Lateral 10318 to 11068'. 00:00 02:00 2.00 0 0 PROD1 DRILL RGRP T MU BHI drilling head, PSI test CTC 4000psi, Install stripper and CTES counter 02:00 05:00 3.00 0 0 PROD1 DRILL PULD P PJSM Deploy BHA 10 ** *Nabors on Billable time * * * * ** 05:00 08:06 3.10 0 9,740 PROD1 DRILL TRIP P RIH, stopping to check pipe and injector. 08:06 08:18 0.20 9,740 9,740 PROD1 DRILL DLOG P Tie in to formation at 9740', +15' 08:18 08:30 0.20 9,740 10,318 PROD1 DRILL TRIP P Close EDC and continue RIH 08:30 11:30 3.00 10,318 10,470 PROD1 DRILL DRLG P Drilling ahead, 30K PUW, 7K RIW, 1.4 BPM, 3200 CTP, 4045 BHP with open choke. 1 - 2K WOB, 100 -250 psi motor work 11:30 11:42 0.20 10,470 10,470 PROD1 DRILL WPRT P Wiper to window 11:42 14:12 2.50 10,470 10,620 PROD1 DRILL TRIP P Drilling ahead, 7K RIW, 1.4 BPM, 3200 CTP, 4045 BHP with open choke. 1 - 2K WOB, 100 -250 psi motor work 14:12 14:36 0.40 10,620 10,620 PROD1 DRILL WPRT P Wiper to window, 33K PUW 14:36 16:51 2.25 10,620 10,640 PROD1 DRILL DRLG P Drilling ahead, 7K RIW, 1.4 BPM, 3300 CTP, 4060 BHP with open choke. 1 - 2K WOB, 100 -250 psi motor work 16:51 17:03 0.20 10,640 10,640 PROD1 DRILL WPRT P BHA wiper 35K PUW 17:03 18:33 1.50 10,640 10,770 PROD1 DRILL DRLG P Drilling ahead, 7K RIW, 1.4 BPM, 3300 CTP, 4220 BHP with open choke. 1 - 2K WOB, 100 -250 psi motor work 18:33 19:24 0.85 10,770 10,770 PROD1 DRILL WPRT P Wiper trip back to window 34K PUW, 7K RIW, Tie in depth to RA marker, No correction 19:24 21:03 1.65 10,770 10,920 PROD1 DRILL DRLG P Drilling ahead, 7K RIW, 1.35 BPM, 3600 CTP, 4260 BHP with open choke. 1 - 3K WOB, 100 -250 psi motor work 21:03 21:57 0.90 10,920 10,920 PROD1 DRILL WPRT P Wiper trip back to window 35K PUW, 7K RIW 21:57 00:00 2.05 10,920 11,070 PROD1 DRILL DRLG P Drilling ahead, 7K RIW, 1.35 BPM, 3700 CTP, 4250 BHP with open choke. 1 - 3K WOB, 100 -300 psi motor work 04/30/2010 Drill 1Q -03A Lateral, 11070 - 11510'. 00:00 01:00 1.00 11,070 11,070 PROD1 DRILL WPRT P Wiper trip to window 34K PUW, 5 -6K RIW 01:00 02:30 1.50 11,070 11,220 PROD1 DRILL DRLG P Drill Ahead 80 -100 FPH, 1.38 BPM in 1.38 BPM out, 1.5 -3K WOB, 4290 BHP, 3850 CTP, 4K CTW, 12.3 ECD, wide open choke Page 6 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:54 1.40 11,220 11,220 PROD1 DRILL WPRT P Wiper trip to window, 33K PUW, Tie in depth to RA marker. -3' correction, RIHW 5K 03:54 06:24 2.50 11,220 11,357 PROD1 DRILL DRLG P Drill Ahead 60 -100 FPH, 1.35 BPM in 1.35 BPM out, 2 -3K WOB, 4290 BHP, 3850 CTP, 4K CTW, 12.4 ECD, wide open choke 06:24 07:48 1.40 11,357 11,357 PROD1 DRILL WPRT P Wiper to the window, PUW 32K, ROP has dropped off to <5 FPH 07:48 20:33 12.75 11,357 11,430 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM, 2 -3K WOB, 4300 BHP, 3700 CTP, 4K RIW, 12.3 ECD, wide open choke 20:33 22:42 2.15 11,430 11,510 PROD1 DRILL DRLG P Break through Ankerite. Drill Ahead 30-40 FPH, 3750 CTP, 4320 BHP, 1 -2 K CTW, 2 -3K WOB. 22:42 00:00 1.30 11,510 11,510 PROD1 DRILL WPRT P Wiper trip back to window, 34K PUW 05/01/2010 Drill 1Q -03A Lateral, 11510 - 12075' 00:00 02:12 2.20 11,510 11,571 PROD1 DRILL DRLG P Drill Ahead 30 -50 FPH, 2 -3K WOB, 3800 CTP, 4350 BHP, -3 -4K CTW, 12.5 ECD, 02:12 02:15 0.05 11,571 11,571 PROD1 DRILL DRLG P Pump 5bbrl low, 5bbrl high vis sweep 02:15 02:54 0.65 11,571 11,608 PROD1 DRILL WPRT P Stacking -10K CTW, PUH 200', for wiper 02:54 03:42 0.80 11,608 11,625 PROD1 DRILL DRLG P Drill Ahead 20 -30 FPH, 2 -3K WOB, 3800 CTP, 4350 BHP, -10K CTW, 12.5 ECD, 03:42 04:42 1.00 11,625 10,350 PROD1 DRILL WPRT P Wiper trip back to window. 33K. Order trucks for mud swap 04:42 04:54 0.20 10,350 10,350 PROD1 DRILL DLOG P Tie in depth -2.5' correction 04:54 05:48 0.90 10,350 11,625 PROD1 DRILL WPRT P Wiper back in hole, swap mud 05:48 11:00 5.20 11,625 11,775 PROD1 DRILL DRLG P h with new mud, 4K RIW, Drill Ahead , 2 -3K WOB, 1.4 BPM, 3190 CTP, 4170 BHP with 120 WHP. Ran into ankerite again and adjusted polygon to get a better angle of attack. 11:00 12:48 1.80 11,775 11,775 PROD1 DRILL WPRT P Wiper to window, 33k PUW 12:48 15:12 2.40 11,775 11,925 PROD1 DRILL DRLG P Drill Ahead, 7K RIW, 2 -3K WOB, 3200 CTP, 1.4 BPM , 4170 BHP with 90 WHP 15:12 17:12 2.00 11,925 11,925 PROD1 DRILL WPRT P Wiper to window, 33k PUW, clean trip both ways 17:12 17:21 0.15 11,925 11,933 PROD1 DRILL DRLG P Drill Ahead, 6K RIW, 2 -3K WOB, 1.4 BPM, 3180 CTP, 4200 BHP with 100 WHP 17:21 19:06 1.75 11,933 11,933 PROD1 DRILL WPRT T BHI computer locked up, PUH wiper trip to repair. 19:06 21:45 2.65 11,933 12,075 PROD1 DRILL DRLG P Drill Ahead, 6K RIW, 1 -3K WOB, 1.4 BPM, 3460 CTP, 4170 BHP with 100psi on MP choke 21:45 23:45 2.00 12,075 12,075 PROD1 DRILL WPRT P Wiper trip back to window 32K PUW, 6K RIW, +2' Correction. 23:45 00:00 0.25 11,750 11,630 PROD1 DRILL DLOG P MAD pass, Geo. 7 FPM up Page 7 of 23 • Time Logs 9 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/02/2010 24 hr summary Drill 1Q-03A Lateral, 12075 - 12342'. POOH for bit swap and Agitator. Unable to pass through window with Hughes bit, POOH swap bits to H calog, RIH 00:00 00:12 0.20 11,750 11,630 PROD1 DRILL DLOG P Continue MAD pass 00:12 00:36 0.40 11,960 11,904 PROD1 DRILL DLOG P RIH to 11960', MAD pass up 5 FPM to 11904'. RIH 00:36 03:06 2.50 12,075 12,225 PROD1 DRILL DRLG P Drill Ahead 50 -80 FPH, 1.4 BPM in, 1.4 BPM out, 1 -2K CTW, 2 -3 WOB, 4180 BHP, 12.08 ECD, wide open choke 03:06 05:36 2.50 12,225 12,225 PROD1 DRILL WPRT P Wiper trip to window 35K PUW 05:36 08:24 2.80 12,225 12,342 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM, 3530 CTP, 2K RIW, 2 -3 WOB, 4180 BHP, wide open choke 08:24 11:48 3.40 12,342 0 PROD1 DRILL TRIP P POOH, poor weight transfer and low ROP. 11:48 12:48 1.00 0 0 PROD1 DRILL PULD P Undeploy BHA #10 12:48 13:18 0.50 0 0 PROD1 DRILL BOPE P Function test BOP 13:18 14:18 1.00 0 0 PROD1 DRILL PULD P Deploy BHA #11 with new bit and agitator 14:18 15:54 1.60 0 9,750 PROD1 DRILL TRIP P RIH 15:54 16:06 0.20 9,750 9,784 PROD1 DRILL DLOG P Tie in to formation, +15', Close EDC and continue RIH 16:06 17:06 1.00 9,784 10,307 PROD1 DRILL TRIP T RIH to window. Tagging up in window at 10306.7'. Try multiple tool faces with no success. Roll pump at <0.1 BPM. 17:06 19:21 2.25 10,307 0 PROD1 DRILL TRIP T POOH 19:21 19:36 0.25 0 0 PROD1 DRILL TRIP T At surface, PJSM, 19:36 21:42 2.10 0 0 PROD1 DRILL PULD T Undeploy BHA #11, Deploy BHA #12, Check stripper rubber. 21:42 23:51 2.15 0 9,750 PROD1 DRILL TRIP T RIH 23:51 00:00 0.15 9,750 PROD1 DRILL DLOG T Tie in depth, correct +15'. RIH to window 05/03/2010 Drill 1Q-03A Lateral 12342 to TD- 12585'. POOH drift window with drilling BHA. Unable to drift. POOH, PU Crayola mill, RIH lay in liner running pill in OH. Dress window backreaming only. Drift window, Kill Well, POOH for liner 00:00 00:12 0.20 9,750 10,300 PROD1 DRILL TRIP T RIH to window, Close EDC 00:12 01:12 1.00 10,300 10,300 PROD1 DRILL TRIP P RIH through window HS, first time. RIH to TD 01:12 03:54 2.70 12,342 12,342 PROD1 DRILL DRLG P Drill Ahead 1.35 BPM in, 1.35 BPM out, 1 -2K WOB, 3 -5K CTW, 3550 off bottom CTP, 4000 on bottom, 4270 BHP wide open choke. 03:54 06:24 2.50 12,342 12,342 PROD1 DRILL WPRT P Wiper Trip to window 32K PUW 06:24 07:24 1.00 12,532 12,565 PROD1 DRILL DRLG P Pump low /high sweeps, continue drilling. 07:24 08:36 1.20 12,565 9,750 PROD1 DRILL WPRT P Called TD, turned up too high and got out of formation. PUH for final tie -in 08:36 08:54 0.30 9,750 9,785 PROD1 DRILL DLOG P Tie in to formation. Page 8 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:54 09:12 0.30 9,785 10,308 PROD1 DRILL WPRT P RIH to log RA 09:12 10:00 0.80 10,308 10,308 PROD1 DRILL WPRT T Unable to pet past the window.. Try various TF and speeds. Circulating at min rate between attempts to go down. 10:00 11:54 1.90 10,308 0 PROD1 DRILL TRIP T POOH 11:54 14:54 3.00 0 0 PROD1 DRILL PULD T Undeploy BHA #12, lay down Resistivity tool and agitator, adjust motor and PU 2.79/2.78 crayola mill. 14:54 16:48 1.90 0 9,740 PROD1 DRILL TRIP T RIH 16:48 17:12 0.40 9,740 10,325 PROD1 DRILL DLOG T Tie in to formation, +14', RIH through window, stacked some weight at 10308'. 17:12 17:24 0.20 10,325 10,350 PROD1 DRILL DLOG P Tie into RA for zero correction. 17:24 18:39 1.25 10,350 12,560 PROD1 DRILL WPRT P RIH 18:39 19:54 1.25 12,560 10,250 PROD1 DRILL MILL P Tag 12520'. Offline with pumps pop 9 P P P P through RIH take weight at 12525, tag 12560. POOH laying in Liner pill, pulling heavy 44K, Pull heavy through Ankerite and 10298. All liner pill out off CT 19:54 20:30 0.60 10,250 10,309 PROD1 DRILL MILL T Drift window 15deg HS dry, tag 10309'. PUH online with pumps 1.3 BPM RIH 8 FPM and 3 FPM Stall X2 trying to pop through. No luck. PUH 20:30 20:45 0.25 10,306 10,313 PROD1 DRILL MILL T Orient 45deg RT TF RIH 3FPM dry. Tag setting down 2K WOB. Hold weight on mill, pop through window. RIH to 10311'. Back ream up to 10306. RIH 45deg RT TF no pumps to 10313', no problem 20:45 21:15 0.50 10,306 10,313 PROD1 DRILL MILL T Orient 15deg RT TF, backream up 1 FPM slowing down to .5 FPM 10310 to 10309. RIH to 10313 no pumps. Drift no problem 21:15 21:45 0.50 10,340 10,306 PROD1 DRILL MILL T Orient 90R backream 10306'. orient 15 RT HS RIH no pumps to 10313', Set down weight 10315'. RIH tie in RA marker. No correction. PUH orient 90L back ream 21:45 22:00 0.25 10,313 10,306 PROD1 DRILL MILL T Orient 15deg RT. RIH to 10313' no pumps, Orient 135R backream 22:00 22:15 0.25 10,313 10,306 PROD1 DRILL MILL T Orient 15deg RT. RIH to 10313' pumps off, orient 135L backream up to 10306' 22:15 22:30 0.25 10,313 10,306 PROD1 DRILL MILL T Orient 15deg HS RIH to 10313, pumps off. Orient 195 22:30 22:45 0.25 10,306 10,250 PROD1 DRILL MILL T Orient 15R RIH drifting window pumps off. X 2 22:45 23:30 0.75 10,250 10,250 PROD1 DRILL CIRC P PUH to 10250' Online with KWF 23:30 00:00 0.50 10,250 PROD1 DRILL TRIP P POOH displacing well to KWF Page 9 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/04/2010 24 hr Summary POOH pumping KWF, P/U liner assembly. Could not make it past window, POOH & P/U new 2.79" crayola mill. Start dressing /milling window from 10,309' @ 1 fph. 2 stalls at the start, good milling indications with metal shavings during window dressing process. 00:00 01:45 1.75 5,600 0 PROD1 DRILL TRIP P POOH 01:45 02:00 0.25 0 0 PROD1 DRILL SFTY P Flow check well. PJSM laying down BHA 02:00 02:30 0.50 0 0 PROD1 DRILL PULD P Lay down BHA #13 02:30 03:30 1.00 0 0 COMPZ CASING PUTB P Rig up floor for liner ops 03:30 05:30 2.00 0 907 COMPZ CASING PUTB P PU Liner, PU liner running tools, MU Infector 05:30 07:42 2.20 907 10,310 COMPZ CASING RUNL P RIH, Correct at flag to 10207.42', +15.2' 07:42 09:00 1.30 10,310 10,310 COMPZ CASING RUNL T Tagging up at window, tried various speeds, PUH up to mandrel at 10115' and Set down up to 91( WOB. 09:00 10:45 1.75 10,310 0 COMPZ CASING TRIP T POOH 10:45 11:00 0.25 0 0 COMPZ CASING SFTY T At surface. Flow check, PJSM. 11:00 11:30 0.50 0 0 COMPZ CASING PULD T Lift Inj. head off well, LD BHA, Prep floor for laying down liner 11:30 12:45 1.25 0 0 COMPZ CASING PULD T Lay down Liner 12:45 14:00 1.25 0 0 COMPZ DRILL PULD T PJSM, MU BHA 15 14:00 17:00 3.00 0 0 COMPZ DRILL TRIP T RIH 17:00 18:30 1.50 9,750 9,750 COMPZ DRILL DLOG T Tie in depth - swap well to Drilling fluid 18:30 19:00 0.50 9,750 10,310 COMPZ DRILL TRIP T Made 3 attempts - Conference call to town. 19:00 19:30 0.50 10,310 10,310 COMPZ DRILL TRIP T Made 11 attempts in total - complete toolface rotation. RIH 20 fpm, not pumping up (a7 10310', P/U weight 30K. No luck. Last attempt was to pump over the lip while lightly sitting on bottom. No luck. 19:30 22:00 2.50 10,310 10,310 COMPZ DRILL MILL T Begin Milling / dressing window with crayola @ 10,308.5' 1.35 bpm, 3200psi, BHP 4170, ECD 12.4, WOB .5. Light stalls @ 10309.65', 10,310.03'. Good milling @ 1 fph, from 10309.5' to getting metal shavings to surface. 22:00 23:00 1.00 10,310 10,311 COMPZ DRILL MILL T Stacked then stalled @ 10310.72' P/U and had same result again 10,310.59. P/U weights looked clean. Feather into, continue with good milling down to 10,311.05'. Motor worked dropped off, WOB .8K. lighter metal shaving's at surface. 23:00 00:00 1.00 10,311 10,312 COMPZ DRILL MILL T Motor work picked up again @ 10,311.3' - continue milling depth @ midnight 10312.1'. Very good metal shavings the past hour. Page 10 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/05/2010 24 hr summary Mill /Backream window wil 2.79" crayola mill. New bottom of window @ 10,311' according to motor work through window dressing. P/U 1.3AKo with Bi- center and drift through window. Successfull @ 25 fpm. P/U Liner assembly and made it through window on first attempt. 00:00 00:30 0.50 10,312 10,312 COMPZ DRILL MILL T Stall @ 10312.47' - P/U weight clean, shut down pumps and try a dry run. Tagged @ 10313'. Toolface same @ 15 R, P/U weight clean @ 30K. Good metal shaving to surface. 00:30 01:00 0.50 10,312 10,312 COMPZ DRILL MILL T Start pumping and try to RIH back to depth but getting stalls and motor work @ 10,310.5', Slight overpull on dry P/U of 2K over on bottom hole sensor. RIH & tagged again @ 10,309.7, 10,306.9' - Tag and stalls moving up hole but no drag or overpull. 01:00 02:00 1.00 10,312 10,342 COMPZ DRILL MILL T RIH .5 fpm, @ 1.30 bpm, clean drift down to 10,312' - continue milling 1 - 2 fph. Very clean, no weight loss, start pushing 5 fph from 10312.8', 10,313.5' speed up to 2 fpm, down to PIP tag mark. Correct depth to -1 ft. 10,341.99' 02:00 03:30 1.50 10,342 10,325 COMPZ DRILL MILL T P/U weight 28K, stop pumping @ 10,316' -clean through window. RIH no pumps - clean no tag @ 15 R @ 20 fpm, twice. Turn to 35 R to see if still a clean drift, looked good. Call town to discuss backreaming steps. 03:30 05:00 1.50 10,325 10,325 COMPZ DRILL REAM T Start backreaming @ 15 R then work in 20 degree increments, starting at new depths. RIH pumps down @ 15 Right. Motor work seen @ 80 left, pass through twice. Increase to 45 increments. 05:00 07:00 2.00 10,325 0 COMPZ DRILL TRIP T POOH 07:00 07:15 0.25 0 0 COMPZ DRILL SFTY T At surface, PJSM 07:15 09:00 1.75 0 0 COMPZ DRILL PULD T Undeploy BHA 15 09:00 10:00 1.00 0 0 COMPZ DRILL SVRG T Service injector head, repair BOP hose on locking system on 2 3/8" Deployment Rams. 10:00 11:15 1.25 0 0 COMPZ DRILL PULD T Deploy BHA 16 11:15 13:00 1.75 0 0 COMPZ DRILL TRIP T RIH 13:00 13:06 0.10 0 9,785 COMPZ DRILL DLOG T Tie in depth, +14 correction, 13:06 13:12 0.10 9,785 10,250 COMPZ DRILL TRIP T RIH, Close EDC 13:12 13:27 0.25 10,250 10,309 COMPZ DRILL TRIP T RIH to drift window, tag at 15 FPM, 20 FPM 15R... 25 FPM 15R get through window RIH to see RA tag, no correction. 13:27 13:57 0.50 10,309 10,320 COMPZ DRILL TRIP T PUH through window RIH through window 15R, 25 FPM, X 4, no pumps Page 11 of 23 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:57 15:12 1.25 10,264 10,264 COMPZ DRILL CIRC T Kill well 15:12 18:12 3.00 10,264 0 COMPZ DRILL TRIP T POOH - flo -check well at surface. 18:12 19:12 1.00 0 0 COMPZ CASING PULD T Lay down BHA & make up bent sub with Indexing guide shoe. 19:12 21:42 2.50 0 880 COMPZ CASING PUTB T P/U & scribe liner assembly (25 joints) 21:42 00:00 2.30 880 10,330 COMPZ CASING RUNL T RIH pumping KWF through GS, tie into flag with +15' correction. Stop pumping, P/U weight - 32K. RIH Set TF to 15R @ 25 fpm through window. Slight weight bobble. - good drift. 05/06/2010 RIH set liner from 12487' - 11663'. Set Anchored Billet top @ 11649'. Start BOPE test, waived by Jim Regg. 00:00 01:00 1.00 10,330 12,487 COMPZ CASING RUNL P RIH 45 fpm with Liner, drifted through window with no problems, saw weight bobble @ 10,646 in OH. Clean RIH, performed weight check @ 12487' - 35K, RIH to setting depth A 12487'. Start pumping 1.2 bpm, 3800 psi, P/U weight 29K. 01:00 01:30 0.50 12,487 10,300 COMPZ CASING RUNL P Liner set from 12,487 - 11,663 TOL, POOH to window pumping across the top. Tie in with zero correction at PIP tag. 01:30 03:30 2.00 10,300 0 COMPZ CASING DISP P Pump KWF through CT while POOH. 03:30 04:30 1.00 0 77 PROD2 STK PULD P Lay down BHA- P/U OH anchored Billet BHA 04:30 05:30 1.00 77 77 PROD2 STK PULD T Open EDC - EDC comms failure - Pull BHA from well. * * * *BHI Downtime * * * ** 05:30 07:45 2.25 77 9,784 PROD2 STK TRIP P RIH 07:45 07:51 0.10 9,784 9,784 PROD2 STK DLOG P Tie in depth +14', 07:51 07:57 0.10 9,784 10,250 PROD2 STK TRIP P RIH, Close EDC before entering open hole, Record up and down weights. 10K down, 30K up. 07:57 08:03 0.10 10,250 11,650 PROD2 STK TRIP P Slide through window no problem RIH to TOL 08:03 08:33 0.50 11,650 11,663 PROD2 STK WPST P Tag TOL, 11663.65' 1.5 WOB. Online with pumps setting OH anchor. 4000psi CTP, 3.5K WOB. OH Anchor set. TOL 11649.25'. 08:33 11:03 2.50 11,663 0 PROD2 STK TRIP P POOH 11:03 11:18 0.25 0 0 PROD2 STK OWFF P At surface, perform flowcheck, PJSM 11:18 11:45 0.45 0 0 PROD2 STK PULD P LD BHA 11:45 14:00 2.25 0 0 PROD2 WHDBO CIRC P Flush stack, grease tree, and choke valves. 14:00 18:00 4.00 0 0 PROD2 WHDBO BOPE P * * * ** *Start BOP test * * * * ** Waived by state Jim Regg. Page 12 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 0 0 PROD2 WHDBO BOPE P Bravo 8 - HCR valve replaced due to hydraulic actuator leak. - Continue with BOP test while replacing valve. 20:00 00:00 4.00 0 0 PROD2 WHDBO BOPE P Remove check valves from BHA, test inner reel valves, stripper & the rest of BOP components. Draw down test, & Alarm test completed. Test pressures 250 low / 3000 psi high. 05/07/2010 Complete BOP test - probelms with Bravo 8 - Hydraulic valve, replaced. P/U and RIH with Drilling BHA. Dry tag TOB @ 11650', P/U and start KOB @ 11649'. After 4 ft into KO picked up and stuck BHA into Billet. Tried to get free with no luck. Disconnect from EDC and POOH for fishing BHA. 00:00 02:00 2.00 0 0 PROD2 WHDBO BOPE P Complete testing BOP's. Had to replace Bravo 8 Actuator again due to by -pass of Hyd. Seals & actuation. BOP test completed 02:00 03:30 1.50 0 0 PROD2 WHDBO CIRC P Get set up to pump KWF back into CT string, Install checks in BHA & clean up equipment after BOP test. Perform valve check list and update board. 03:30 04:30 1.00 0 0 PROD2 WHDBO CIRC P Start pumping KWF through CT. 04:30 05:30 1.00 0 0 PROD2 DRILL PULD P Make up BHA with 1.3 AKO and Bicenter bit. Open EDC. 05:30 07:00 1.50 0 9,750 PROD2 DRILL TRIP P RIH 07:00 07:15 0.25 9,750 10,250 PROD2 DRILL DLOG P Tie in Depth +14, RIH 07:15 09:45 2.50 10,250 10,250 PROD2 DRILL CIRC P Circulate KWF out of well 09:45 09:51 0.10 10,250 10,309 PROD2 DRILL TRIP P RIH, Tag billet. PU, Roll pumps. RIH attempt to run through window, through window 09:51 10:39 0.80 10,309 11,650 PROD2 DRILL TRIP P Tag Billet no pumps 11649.7'. PUH 30K, online with pumps 1.3BPM 10:39 11:39 1.00 11,650 11,651 PROD2 STK KOST P Start time drilling 1 FPH, .5 WOB, ��� 6.6K CTW. 3400CTP, 4392 BHP. 4 Out MM bypassed. 11:39 11:51 0.20 11,651 11,651 PROD2 STK KOST P Increase ROP 2 FPH ArM t/ t, 11:51 12:15 0.40 11,651 11,651 PROD2 STK KOST P Stall PU 37K CTW, Increase rate to 1.4BPM RIH, Decrease ROP back to 1FPH 12:15 12:28 0.22 11,651 11,651 PROD2 STK KOST P Mill Ahead, .5WOB, 1.3FPH, 3400 CTP, 7K CTW, 4342 BHP 12:28 13:28 1.00 11,651 11,652 PROD2 STK KOST P Increase ROP 2FPH 13:28 13:40 0.20 11,652 11,354 PROD2 STK KOST P Increase 3FPH 13:40 13:55 0.25 11,354 11,350 PROD2 DRILL KOST T PUH, weight on bit stacking, motor work dropped off. 13:55 14:04 0.15 11,354 11,349 PROD2 STK KOST T Stuck. In a stall. PU 40K, RIH 0 CTW. 14:04 14:13 0.15 11,349 PROD2 STK KOST T Still stuck orient 90L. PU 40K No luck. Orient around 360deg. PUH RIH. PUH stuck. Online with pumps Page 13 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:13 15:13 1.00 PROD2 STK KOST T RIH pumps off stack 3.9 K Try orient Left Orient 180 out, poped loose Orient to 330, pull up higher but pulling junk or rock orient 180 out, push down, seems freer, orient back to 330 and push down Pulling up to 10646, junk following. RIH, set 3K at 11653, orient L Push down 11652 3.5 wob Pull up 11645 -2 wob 11644.43 -4K wob 15:13 16:13 1.00 PROD2 STK TRIP T Push down at 330 TF fast 11654 5.6 wob Pull up 11644 at 330 TF -3.6 wob run slow to neutral, orient Orient 180 out and ramp up pump, still stall RIH hard at 180 out, 13K down at surface, wob 4.9 Pull to 50k , up and down only goes down to 11655 now, takes WOB to 11K Now 11657 takes 5K wob (different Spot) Orient 270TF, dragging something Orienting different quadrants Down to -20 but only 5K WOB Pull 60, -12 wob 16:13 16:19 0.10 PROD2 STK TRIP T CTW at nuetral weight Disconnect From BHA, Clean pick up 16:19 20:19 4.00 10,300 0 PROD2 STK TRIP T POOH 20:19 20:49 0.50 0 0 PROD2 STK SFTY T Ct @ surface, close swab valves. Safety meeting for laying down BHA and working with space out/BHA of next run. 20:49 21:19 0.50 0 0 PROD2 STK PULD T Lay down BHA - disconnect looked clean on EDC. 21:19 22:19 1.00 0 0 PROD2 STK EQRP T Pull apart MP choke due to al. build up from billet milling. Choke seat was damaged. damaged. replaced. 22:19 23:31 1.20 0 54 PROD2 STK PULD T P -test choke connection. Check GS spear vs EDC fishing neck, looked good. Begin deploying fishing BHA with Hip- tripper. 23:31 23:59 0.48 54 54 PROD2 STK TRIP T RIH pumping through EDC following MP schedule. 05/08/2010 RIH with Hip- tripper, could not get through window, multiple tries. POOH found one finger missing on GS spear. P/U magnet run, did not recover finger. RIH with 2 degree bent sub, HOT and Hipp tripper, latched BHA fish @ 11,594.2', Hit Down & Up until tripper stop working (4 hours). Moved fish 1.5' to 11,592.7. Disconnect to POOH. Page 14 of 23 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment - 00:00 02:00 2.00 54 10,300 PROD2 STK TRIP T RIH pumping through EDC. - Tie in with +13.5 ft correction. Stop pumping, close EDC & weight check 31 K. Bring pumps up and check flow & vibration of hammer. Looked good. Stop pumping through window. Tagged up (C77, 10313' 02:00 03:00 1.00 10,300 10,312 PROD2 STK TRIP T Tagged up at window @ 10,313'. Set down 4K not pumping. P/U and try to ease into, tagged up again. Three times dry. P/U heavy weight 35K, but not on bit - dry pipe. P/U 30 ft and start pumping slowly @ .2 bpm. Tagged up same spot. P/U weigtht 32K. Increase pump rate to .5 bpm and try again @ 20 fpm. Tagged again 10311' soft tag and Hip- tripper stalled. P/U and try to vibrate slowly down through @ 10310'. no luck. 03:00 04:00 1.00 10,312 10,312 PROD2 STK TRIP T RIH dry taq (a7 10312.6' WOB 2K, P/U and try .8 bpm through window. No luck. P/U 300 ft and try dry @ 35 fpm. tagged same spot, P/U 20 ft and try to sling shot threw - RIH speed 45 - 50 fpm, Stop quickly @ 10311'. No luck. Try 40 fpm pumping .8 bpm and stop r@ 10,311' - 2K WOB, No luck POOH. 04:00 07:00 3.00 10,312 0 PROD2 STK TRIP T Open EDC POOH. 07:00 08:30 1.50 0 0 PROD2 STK TRIP T Undeploy BHA, Finger missing on 2.5" G/S spear 08:30 09:30 1.00 0 0 PROD2 STK TRIP T Locate X -over for Magnet run 09:30 10:30 1.00 0 0 PROD2 STK TRIP T Deploy BHA 10:30 13:00 2.50 0 0 PROD2 STK TRIP T RIH 13:00 13:06 0.10 0 9,875 PROD2 STK DLOG T Tie in depth +13 13:06 13:12 0.10 9,875 103,010 PROD2 STK FISH T RIH to fish GS finger 13:12 13:24 0.20 10,310 10,320 PROD2 STK FISH T RIH no pumps 5 FPM, Tag, PUH, RIH 5 FPM, running through window, no bobbles, tie into RA marker 0 correction. 13:24 15:24 2.00 10,320 0 PROD2 STK TRIP T POOH 15:24 17:24 2.00 0 67 PROD2 STK PULD T At surface, Flow check well 10 minutes, Well dead Lots of metal, No G/S finger. LD /PU fishing BHA 17:24 20:24 3.00 67 11,550 PROD2 STK TRIP T RIH circulating through EDC. Tie in +13.5 correction. Stop above window and close EDC, weight check 34K. Test the tool, set 15R. Small weight bobble @ 10312.5, continue RIH pumping .2 bpm to keep spear clean. Page 15 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:24 21:24 1.00 11,550 11,594 PROD2 STK FISH T Increase pump rate to .5 bpm, 2800 psi, weight check of 32K. RIH weight 9K, Set into top of fish nu, 11594' set down 4K, P/U to 40K, WOB - 2K - fish latched - reset to neutral weight and start RIH slowly pumping. .8 bpm, free spin 3300 - hammering 3700psi, free point @ 11591' WOB 1.2, start tapping down @ 11594.1' WOB 1.6, circ press 3480, vibration 3 to 4 on BHA sensor. Stall @ 11594.3' circ. press. 4400psi. 21:24 22:24 1.00 11,594 11,588 PROD2 STK FISH T P/U weight 38K @ 11589.7', RIH slowly start pumping and let tool tap starting @ 11594'. .8 bpm, 3400psi, WOB 1.4, CT weight 11K, hammering down on tool. Slowly worked and hammered back down. Stall again @ 11594.25'. P/U - Start tapping up. P/U CT weight 46K, WOB - 11 K, 1.0 bpm, 4000psi. Tension started @ 11588.7'. 22:24 23:00 0.60 11,583 11,593 PROD2 STK FISH T Increase P/U weight to 50K surface & -13K on BHA. pumping 1 bpm, 4000psi, depth 11585.2'. Hit up for 1.3 hrs, Final numbers - 1 bpm, 4000psi, P/U weight 50K, WOB - 15K, Depth 11583.8'. RIH and try tapping down again. 23:00 00:00 1.00 11,593 11,593 PROD2 STK FISH T Tagged up early RIH @ 11593. Slightly moved fish uphole. RIH and tap down, starting @ 11592.7'. Good tapping down to 11593.1' Stall. - Try in Up mode - Tripper may have failed. 05/09/2010 Hipp- tripper moved fish 1.5', POOH, P/U up down jars. latched into fish @ 11591' Total 4 jars down, 2 jars up then 2 jars down. Fish popped free. BHA & fish recovered at surface. No external damage to BHA. Slack MNGT with 150 ft cut back. Current string lenght 13890'. 00:00 00:30 0.50 11,593 11,593 PROD2 STK FISH T While hitting down, Hip tripper failed. Stop pumping and try straight pull.. CT weight 55K - WOB -10K, @ 11583.5'. 60K, WOB - 10k, 11581.8'. Work stirng a couple of times dry. No luck, max. pull 60K on stirng & -12K WOB. 00:30 03:30 3.00 11,593 67 PROD2 STK TRIP T Pump off GS Spear. Moved the Top of fish 1.5' from 11594.1' to 11592.7' ft. POOH for jar run, no problem at window. POOH following MP. 03:30 04:30 1.00 67 0 PROD2 STK PULD T CT @ surface. Bleed off and choke and flo -test well. No -flo for 15 minutes. Safety meeting on Laying down BHA. lay down BHA, GS spear looks good. 04:30 05:30 1.00 0 0 PROD2 STK EQRP T Injector maint. & set up to pump slack out of CT string. Page 16 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 0 0 PROD2 STK CIRC T Pump 218' of cable out of string. 06:00 06:15 0.25 0 0 PROD2 STK SFTY T Crew change PJSM 06:15 08:00 1.75 0 0 PROD2 STK PULD T Cut Eline, MU BHA 08:00 09:45 1.75 0 10,225 PROD2 STK TRIP T RIH 09:45 09:57 0.20 10,225 10,225 PROD2 STK TRIP T Correct depth +13.5', as per average all previous tie in. Record up and down weights, 28.5K up, 7 -8K RIH 09:57 10:27 0.50 10,225 10,314 PROD2 STK TRIP T RIH, slide through window, one bobble at 10314'. Continue RIH 10:27 10:30 0.05 10,314 11,580 PROD2 STK TRIP T Record Up weight 10:30 10:36 0.10 11,580 11,591 PROD2 STK FISH T RIH latchin• into fish setting 3K Down, CTP psi increase. Shut down pumps. PUH 45K, RIH -10K CTW. cocking jors 10:36 10:57 0.35 11,591 11,606 PROD2 STK FISH T RIH /PUH cocking jars jarring down X 4, All good licks 10:57 11:03 0.10 11,606 11,591 PROD2 STK FISH T RIH /PUH cocking up jars 45K PUW, X2 11:03 11:18 0.25 11,591 11,606 PROD2 STK FISH T Jar up X 1 Jar Down X 2 11:18 12:18 1.00 11,606 10,315 PROD2 STK TRIP T 2nd down jar, Pop free, PUH 35 -37K PUW. Constant PUW continue POOH 18 FPM 12:18 12:39 0.35 10,315 10,225 PROD2 STK TRIP T PUH through window 5 FPM 12:39 16:09 3.50 10,225 0 PROD2 STK TRIP T POOH 50 FPM 16:09 16:24 0.25 0 0 PROD2 STK SFTY T At surface, PJSM. 16:24 18:24 2.00 0 0 PROD2 STK PULD T LD BHA, Complete Fish on... Continue laying down BHA.. 18:24 19:54 1.50 0 0 PROD2 STK CIRC T Valve check -list, position Injector and pump slack back into CT. Cable stopped moving after surging 10 bbls, pump additional 20 bbls to ensure slack is back. 19:54 21:30 1.60 0 0 PROD2 STK CTOP T Cut CT to find cable = 150 ft. 21:30 00:00 2.50 0 0 PROD2 STK CTOP T Start re- heading CT Connector, Pull testing to 20K, Made up BHI connector. CT conenctor leaked when pressure testing. Cut off and re -head 05/10/2010 RIH for Cleanout run to TOB. Tag TOB 11652'. PU OH Anchored Billet setting on depth at 11653', TOB 11513'. PU drilling assembly, RIH. 00:00 02:30 2.50 0 0 PROD2 STK CTOP T make up CT connector and pull test to 30K, pressure test. Held good. P -test riser to 2500 psi on well. 02:30 03:00 0.50 0 0 PROD2 STK PULD T Pre -job for P/U BHA, make up motor & Bi- center. Flo- check. 03:00 03:30 0.50 0 62 PROD2 STK PULD T P/U BHA and set in stack. Make up injector. 03:30 06:00 2.50 62 9,770 PROD2 STK TRIP T Open EDC & RIH following MP Schedule. Page 17 of 23 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:15 0.25 9,770 11,652 PROD2 STK DLOG T Tie in depth +13 correction. RIH 06:15 06:45 0.50 11,652 11,652 PROD2 STK TRIP T Tag TOB 11652.13'. 2.4K WOB, PU clean 34K No pumps 06:45 07:45 1.00 11,652 10,250 PROD2 STK TRIP T POOH, Above window open 07:45 10:00 2.25 10,250 0 PROD2 STK TRIP T POOH, circ 1.3 BPM following MP schedule 10:00 11:15 1.25 0 0 PROD2 STK PULD T PJSM, LD BHA 11:15 12:30 1.25 0 0 PROD2 STK PULD T PU /MU BHA 12:30 15:30 3.00 0 9,975 PROD2 STK TRIP T RIH following MP schedule 15:30 15:45 0.25 9,975 10,250 PROD2 STK DLOG T Tie in Depth +14 correction, RIH to 10250, Bleed off CT, Close EDC. Record up weights, 31 K PUW. 15:45 16:45 1.00 10,250 11,653 PROD2 STK TRIP T RIH to setting depth 16:45 17:00 0.25 11,653 11,653 PROD2 STK TRIP T Tact, PU string weight. 28K, Online with pumps setting OH anchor, 'l 440psi, 2.5K WOB. PUH 31K. � 17:00 19:30 2.50 11,653 0 PROD2 STK TRIP T POOH 19:30 19:45 0.25 0 0 PROD2 STK SFTY T PJSM, flow check, 19:45 21:30 1.75 0 0 PROD2 STK PULD T LD BHA 26, PU BHA 27 21:30 23:15 1.75 0 9,750 PROD2 STK TRIP T RIH 23:15 23:24 0.15 9,750 9,779 PROD2 STK DLOG T Tie in depth +13'. 23:24 00:00 0.60 9,779 10,250 PROD2 STK TRIP T RIH to 10250, close EDC RIH to tag billet 05/11/2010 Started Drilling Operation from TOB @ 11513' to 12168 ft. Perform Mud swap @ 11900' due to poor weight transfer.Seen better WT Transfer & Lower PSI after mud swap. 00:00 00:30 0.50 10,250 11,512 PROD2 STK TRIP T RIH - stop pumping @ 11,400' - Dry tag TOB @ 11512.4'. P/U 37 K dry, 31 K wet, RIH weight 8.5K. Start pumping 1.4 bpm. Zero WOB. 00:30 01:30 1.00 11,512 11,514 PROD2 STK MILL T RIH slowly starting from 11511' - 1.45 bpm, 3580psi, BHP 4400, ECD 12.7, WOB .2. Motor work detected starting @ 11512.3'. Start KOB © 1 fph. Bypass Managed pressure choke. Better WOB 1.1K & motor work starting @ 11513'. Time drilling. 270 L 01:30 02:30 1.00 11,514 11,515 PROD2 STK MILL T Good smaller Al. Shavings to surface. Continue Time milling 2 fph. " *Stall @ 11514.2' - WOB jumped to 2K, Come down on pumps, clean P /U. 34K. Continue 1 - 2 FPH @ 11514.' WOB .6K. Clean looking 1.4 bpm, 3400psi, CT weight 8K. Page 18 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:48 1.30 11,515 11,532 PROD2 STK MILL P Increase to 3 fph. 1.4 bpm, 3350psi, WOB .5, CT weight 8K, BHP 4360psi. Getting less Al. & some formation over shakers. 11,515.8' Increase to 10fph. WOB .5K Increase to 20 fph @ 11520.8', WOB .6K. Drill a total of 20 ft past Billet to 12532'. 03:48 04:00 0.20 11,532 11,532 PROD2 STK MILL P Slow pump rate to .2 bpm, P/U through Billet - clean P/U weight 33K, Set up on Managed pressure choke. RIH with no pumps, clean, increase pump rate and start drilling ahead. 04:00 06:00 2.00 11,532 11,680 PROD2 DRILL DRLG P Drilling ahead - 1.45 bpm, 3500psi, BHP 4400, ECD 12.7, WOB 1.3K, Ct weight 7K, ROP 45. 06:00 08:00 2.00 11,680 11,680 PROD2 DRILL WPRT P Wiper trip P/U weight 32K. Tie into RA Zero correction. 08:00 11:00 3.00 11,680 11,830 PROD2 DRILL DRLG P Drilling ahead - 1.4 bpm, 3800psi, BHP 4440, ECD 12.8, WOB 2k, Ct weight 3.5K, ROP 70. Hit good sand Cad 11715 Pulled a 200 ft wiper trip for the GEO's to discuss formation intown. 11:00 13:00 2.00 11,830 11,830 PROD2 DRILL WPRT P Wiper trip - P/U weight 34K 13:00 16:00 3.00 11,830 11,980 PROD2 DRILL DRLG P Back on bottom drilling - 1.40 bpm, 3800psi, BHP 4400, ECD 12.8, WOB 2K, ROP 80, Start new mud @ 11,900ft. * ** Pulled a BHA wiper trip @ 11936' due to weight loss and slow ROP - pulled heavy - 40K. Good ROp & weight transfer on bottom. 16:00 18:00 2.00 11,980 11,980 PROD2 DRILL WPRT P Wiper trip P/U weight 35K. 18:00 20:45 2.75 11,980 12,115 PROD2 DRILL DRLG P Back on bottom drilling. CTP= 3200psi @ 1.39 bpm. BHP =4245, ECD 12.75, WOB 2.15K, ROP =65. 20:45 23:00 2.25 12,115 12,115 PROD2 DRILL WPRT P Wiper Trip - P/U WT= 33k.Had to Reboot MWD Real Time Computer. Start PUH slow to Re -start Computer and get back on Depth. Tie into RA Marker W/ -2' Correction. 23:00 00:00 1.00 12,115 12,168 PROD2 DRILL DRLG P Back on bottom drilling. CTP= 3360psi @ 1.45 bpm. BHP= 4180psi, ECD 12.15, ROP =52, Seeing good weight transfer @ surface & downhole.SW =4.5k WOB =2k. Perform BHA wiper @ 12168' 05/12/2010 Able to Drill down from 12168' to 12,560' before seeing poor weight transfer and slow ROP. Discuss plan forward w /town and decision was made to trip for Agitator. Inspected & Used same Bit with new Agitator. Page 19 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 12,168 12,168 PROD2 DRILL DRLG P Starting to Toss some surface weight and seeing a increase of WOB with slow ROP. Perform BHA Wiper. Continue W /Drilling operations. ROP =38, WOB= 1.6k - 2.2k CTP =3345 @ 1.43 bpm, BHP =4210 psi. 02:00 04:45 2.75 12,168 12,265 PROD2 DRILL WPRT P Wiper Trip. Up Wt =36k 04:45 08:03 3.30 12,265 12,415 PROD2 DRILL DRLG P Back on Bottom Drilling Ahead. CTP= 3465psi @ 1.45 bpm, WOB =1.5, ROP =60, BHP= 4300psi. Had some weight transfer problems around 12370', once we made it through the hard section the weight came back. to 3K surface weight. 08:03 10:33 2.50 12,415 12,415 PROD2 DRILL WPRT P Wiper trip - 36K off bottom 10:33 12 :03 1.50 12,415 12,460 PROD2 DRILL DRLG P Drilling ahead - 1.40 bpm, 3400psi, BHP4300, ECD 12.4, ROP 50, WOB 2K, CT weight 4K. BHA feels like slip sticking @ 12,458' 12:03 12:33 0.50 12,460 12,460 PROD2 DRILL WPRT P P/U to get better weight transfer - P/U heavy 45K - work pipe 4 or 5 times. up to 12450'. Circ. B /U. and popped free after 20 minutes. Build Hi -low sweeps. P/U 200 ft - 33K. 12:33 15:33 3.00 12,460 12,560 PROD2 DRILL DRLG P Drilling ahead - 1.40 bpm, 3500 psi, BHP 4300, ECD 12.6, ROP 30 to 50, WOB 2k, CT weight 2K. SLip sticking off /on. Crossed a fault @ 12, 447'. Pumped 5 low / 5 high sweep to see if ROP increased. No change WOB or over the shakers. 15:33 19:15 3.70 12,560 0 PROD2 DRILL TRIP P Wiper trip - P/U weight 35K - POOH for agitator 19:15 19:45 0.50 0 0 PROD2 DRILL SFTY P OOH, Close EDC. PJSM 19:45 21:15 1.50 0 0 PROD2 DRILL PULD P Un- Deploy Drilling BHA #27. Inspect Injector. Inspected Drill Bit, found that the Bit was balled up and one small piece of shale in channel of bit. 21:15 21:30 0.25 0 0 PROD2 DRILL SFTY P PJSM Before Deployment Of BHA #28 21:30 23:00 1.50 0 78 PROD2 DRILL PULD P Deploy BHA #28 With Agitator & Same Bit. Power Up Tool & Test. All looked Good. 23:00 00:00 1.00 78 6,800 PROD2 DRILL TRIP P Complete Deployment of BHA #28, RIH following MPS 05/13/2010 Continue Drilling Operation after Tripping for Agitator. Encounter Ankerite from 12600' to 12711' with slow ROP most of the day. 00:00 00:15 0.25 6,800 9,755 PROD2 DRILL TRIP P Continue RIH with BHA #28 following MPS 00:15 00:30 0.25 9,755 9,785 PROD2 DRILL DLOG P Make GR Tie -In @ 2 FPM from 9755' to 9772' ( + 13' Correction) Change Depth to 9785' Page 20 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 9,785 12,560 PROD2 DRILL TRIP P Continue In Hole To Last Drill Depth. RIH Wt= 10k, Closed EDC @ 10250', Orientation 18 deg High Side. No problem through window. 02:00 03:45 1.75 12,560 12,605 PROD2 DRILL DRLG P Back on bottom Drilling @ 1.35 BPM, CTP =3825 psi / ROP =60 FPH, WOB =1.7k BHP =4355 psi. 03:45 07:45 4.00 12,605 12,634 PROD2 DRILL DRLG P Encounter Hard area @ 12,600' CTP =3780 psi @ 1.33 bpm, WOB =2.45k ROP =14 to 20 fph. Surface weight looks good, Appears we are drilling in a section of Ankerite. Did a P/U after 5 hours of sitting on Ankerite. 07:45 13:45 6.00 12,634 12,675 PROD2 DRILL DRLG P P/U weight 38K off bottom - Wiper 50 ft - Continue drilling ahead is slow ankerite. WOB 2.5 - 3.1K, Ct weight 4K. 13:45 18:00 4.25 12,675 12,705 PROD2 DRILL DRLG P May have drilled through Ankerite section. P/U 50' for weight check - 33K 18:00 19:45 1.75 12,705 12,710 PROD2 DRILL DRLG P Still Drilling in Ankerite. Very slow ROP. CTP= 3845psi @ 1.36 bpm / ROP =7.5 / WOB= 2.83k / BHP =4400 psi. Crew Change & Weekly SLT meeting. 19:45 23:00 3.25 12,710 12,710 PROD2 DRILL WPRT P Wiper Trip. Up Weight= 36k. CTP= 3590psi @ 1.35 bpm. Clean PU. 23:00 00:00 1.00 12,710 12,734 PROD2 DRILL DRLG P Back On Bottom Drilling again. Note: Did See some Drag while RIH from 12520' to 12690'. CTP =3890 psi @ 1.37 bpm, WOB =2.8k / ROP =36 fph. BHP =4400. Seen good Drilling Break @ 12711', ROP up to 60 fph. 05/14/2010 Drilled to TD @ 13000ft, Spotted Liner Beads in Lateral. Made up 2727 of 2 3/8" Slotted Liner. Total losses for entire lateral = 37 bbls. 00:00 01:15 1.25 12,734 12,803 PROD2 DRILL DRLG P Seen Drilling break Ccil 12,711', ROP =50 fph, CTP= 4000psi @ 1.37bpm / WOB= 2.38k, 01:15 01:30 0.25 12,803 12,803 PROD2 DRILL WPRT P BHA Wiper. Seeing Good ROP & WOB, But Poor Surface Weight of -3000# / Up Wt =37k with a 5k overpull. 01:30 03:15 1.75 12,803 12,860 PROD2 DRILL DRLG P Back on Bottom Drilling Ahead. Decend ROP & Surface Weight, ROP =60 / WOB =2.2k. 03:15 06:15 3.00 12,860 12,860 PROD2 DRILL WPRT P Wiper Trip. Up Wt= 36k, noticed some weight drag from 12620' to 12730' While RIH. Worked pumps to help weight transfer. Weight check prior to bottom 32K. 06:15 08:15 2.00 12,860 12,890 PROD2 DRILL DRLG P Mud check - switch to new mud once pit space is available. Drilling ahead - 1.4 bpm, 3800 psi, BHP 4460, ECD 12.9, ROP 30, WOB 1.5, CT weight 5K. Page 21 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 09:45 1.50 12,890 13,000 PROD2 DRILL DRLG P New mud at bit, Good ROP and WOB transfer. Continue drilling ahead. Pump sweeps 7 /low7/ high prior to TD. 09:45 13:15 3.50 13,000 13,000 PROD2 DRILL WPRT P Sweeps out bit, P/U weight 35K, Wiper trip with Tie in. - 2 ft correction. RIH small weight bobbles from 12,636 - 12,720/ (toolface change). Mix up beaded liner pill (30 bbls) Tag bottom lightly. 12,299' . 13:15 14:15 1.00 13,000 10,300 PROD2 DRILL WPRT P P/U slowly while starting to pump pill down CT. Wipe up through bottom 200' section. RIH -Spot liner pill from TD pumping .4 bpm, pulling 40 fpm. P/U weight 35K Pump total of 28 bbls. 14:15 16:45 2.50 10,300 72 PROD2 DRILL TRIP P KWF @ bit, Open EDC & POOH pumping KWF. 16:45 17:15 0.50 72 72 PROD2 DRILL SFTY P CT @ surface. Flow check well. Safety meeting for laying down BHA & function testing BOP's. 17:15 18:00 0.75 72 72 PROD2 DRILL SFTY P Crew Change / PJSM. Flow Check Well. 18:00 18:30 0.50 72 0 PROD2 DRILL PULD P Un- Deploy BHA. 18:30 19:00 0.50 0 0 COMPZ CASING BOPE P Function Test BOPE 19:00 19:15 0.25 0 0 COMPZ CASINGSFTY P PJSM Before Picking Up Liner. 19:15 22:30 3.25 0 0 COMPZ CASING PULD P Start Picking Up 2 3/8" liner. 22:30 00:00 1.50 0 0 COMPZ CASING OTHR P Standby for Indexing GS from Prudhoe to Run Orienting Tool. Clean up rig floor, prep Coiltrak assembly. 05/15/2010 TD Liner. Swap Well Over to Seawater and Freeze Protected Well from 3000' to surface with Diesel. Set BPV.BIew Reel Dry With N2. Prep For Reel & Injector Swap. Note: Rig Release @ 18:00 HRS * ** Excempt move due to phase conditions * * ** 00:00 00:15 0.25 0 0 COMPZ CASINGSFTY P Indexing GS on Location. PJSM Before Making up Liner Setting BHA. 00:15 01:15 1.00 0 2,782 COMPZ CASING PULD P MU Liner Setting Assemble. Surface Check BHA. PT Lubricator Connection. 01:15 05:00 3.75 2,782 13,000 COMPZ CASING RUNL P RIH w /Liner. Had + 14' Correction © Flag. Up Wt =37K / RIH Wt= 10K @ Flag. Change Depth from ( 10168' to 10182' ) No Problem Through Window w/ Liner. 05:00 05:15 0.25 13,000 13,000 COMPZ CASING RUNL P Had To work liner down from 12500 to TD. Up Wt off bottom 45K. No Problem pumping off liner. 05:15 06:45 1.50 12,999 10,272 COMPZ CASING DISP P Performing Tie -in log to confirm depth of liner top.Up Wt= 33k. -2 ft correction. TOL = 10,272' - BOL = 12,999. Open EDC and circulate out KWF with SW Page 22 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:45 2.00 10,272 72 COMPZ CASING DISP P POOH pumping SW followed by Diesel for freeze protection from 3000' to surface. CT chased out with SW. 08:45 09:45 1.00 72 0 COMPZ CASING PULD P CT @ surface - safety meeting & pressure undeploy. 09:45 10:45 1.00 0 0 COMPZ CASING PULD P Set up rig floor, flush stack and break down tools 10:45 13:15 2.50 0 0 DEMOB WHDBO NUND P P/U BPV lubricator pressure test and run BPV 13:15 14:45 1.50 0 0 DEMOB RIGMN1 CIRC P Rig up SLB and blow down CT to Tiger tank through the stack. 14:45 15:15 0.50 0 0 DEMOB MOVE MOB P Finsih purging all stack and rig lines. 15:15 16:15 1.00 0 0 DEMOB RIGMNT CTOP P Stand back CT injector, remove BHA & install slip connector to unstab p 16:15 18:00 1.75 0 0 DEMOB RIGMNT CTOP P Unstab CT string. Prep Injector & Reel for Swap. All Charges for rig, crane work and truck charges will be added to 3K -09 after 6:00 PM. ** *Rig Release * * ** Page 23 of 23 Conoco Alaska s • ConocoPhilli Alaska p� ) Inc. Kuparuk River Unit Kuparuk 1Q Pad 1Q-03A 50- 029 - 21249 -01 Baker Hughes INTEQ Definitive Survey Report BAKER p HUGHES 17 May, 2010 II ConocoPhillips la r- ConocoPhillips Definitive Survey Report BAKER ES Alaska i Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1Q Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad MD Reference: 1Q -03 © 90.00ft (Nordic 1) Well: 1Q North Reference: TRUE Wellbore: 1Q Survey Calculation Method: Minimum Curvature Design: 1Q -03 Database: EDM Alaska Prod v16 1 Project Kuparuk River Unit — ` ^ -- — �._—_. _ s Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point i Map Zone: Alaska Zone 04 _ — Using geodetic scale factor • Well 1 Q - 03 I Well Position +NI-S 0.00 ft Northing: 5,984,656.79ft Latitude: 70° 22' 8.996 N +E / - 0.00 ft Easting: 528,507.43ft Longitude: 149° 46' 6.028 W Position Uncertainty 0.00 ft Wellhead Elevation: ft _ Ground Level: 47.50 ft 1 Wellbore 1Q — ! Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( (nT) BGGM2009 5/1/2010 17.21 79.83 57,377 Design 1Q -03A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,275.00 Vertical Section: Depth From (TVD) +W-S +E/ -W Direction • (ft) (ft) (ft) ( 42.50 0.00 0.00 39.52 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 50.00 10,275.00 1Q -03 GyroData (1Q -03) GYD -CT -CMS Gyrodata cont.casing m/s 2/1/2010 2/1/2010 i 10,299.00 12,505.14 10-03A (1Q -03A) MWD MWD - Standard 4/29/2010 5/3/2010 5/17/2010 11:49:39AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips MAI Conoco Phillips Definitive Survey Report BAKER ES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1Q - 03 Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad MD Reference: 1Q-03 @ 90.00ft (Nordic 1) i Well: 1Q North Reference: TRUE Welibore: 1Q Survey Calculation Method: Minimum Curvature Design: 1Q Database: EDM Alaska Prod v16 1 S urvey Map Map Vertical MD Inc Azl TVD TVDSS +N/.S +E/ -W DLS • Northing Easting Section Survey Tool Name Annotation (ft) (1 ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) 10,275.00 53.86 42.47 6,561.00 6,471.00 5,211.66 5,150.64 5,989,887.51 533,637.68 2.31 7,297.92 MWD (2) TIP 10 10,299.00 54.18 42.67 6,575.10 6,485.10 5,225.96 5,163.78 5,989,901.86 533,650.76 1.49 7,317.31 MWD (2) KOP; Top of Window 1 10,330.49 65.76 40.37 6,590.83 6,500.83 5,246.36 5,181.79 5,989,922.32 533,668.69 37.31 7,344.51 MWD (2) Interpolated AZI 10,360.53 69.82 38.40 6,602.18 6,512.18 5,267.85 5,199.43 5,989,943.88 533,686.25 14.82 7,372.31 MWD (2) Interpolated AZI 10,390.50 72.71 36.60 6,611.81 6,521.81 5,290.37 5,216.70 5,989,966.46 533,703.43 11.20 7,400.67 MWD (2) Interpolated AZI 10,405.33 72.46 35.75 6,616.25 6,526.25 5,301.79 5,225.05 5,989,977.91 533,711.74 5.72 7,414.80 MWD (2) 10,435.31 70.05 32.41 6,625.88 6,535.88 5,325.30 5,240.96 5,990,001.48 533,727.56 13.26 7,443.05 MWD (2) 10,465.37 67.92 29.43 6,636.66 6,546.66 5,349.36 5,255.38 5,990,025.59 533,741.88 11.65 7,470.79 MWD (2) 10,495.76 66.64 35.15 6,648.41 6,558.41 5,373.05 5,270.34 5,990,049.34 533,756.75 17.86 7,498.59 MWD (2) 10,525.72 62.79 37.99 6,661.21 6,571.21 5,394.80 5,286.47 5,990,071.15 533,772.80 15.45 7,525.63 MWD (2) 10,555.52 58.14 40.54 6,675.89 6,585.89 5,414.88 5,302.86 5,990,091.28 533,789.11 17.29 7,551.55 MWD (2) 10,585.02 56.01 42.54 6,691.93 6,601.93 5,433.41 5,319.28 5,990,109.88 533,805.45 9.19 7,576.29 MWD (2) 10,615.81 60.55 43.66 6,708.11 6,618.11 5,452.53 5,337.17 5,990,129.06 533,823.27 15.07 7,602.42 MWD (2) 10,645.87 64.73 45.23 6,721.93 6,631.93 5,471.58 5,355.87 5,990,148.18 533,841.89 14.66 7,629.01 MWD (2) 10,675.62 69.57 46.85 6,733.48 6,643.48 5,490.60 5,375.60 5,990,167.27 533,861.55 17.02 7,656.24 MWD (2) 10,705.35 74.05 48.77 6,742.76 6,652.76 5,509.55 5,396.52 5,990,186.31 533,882.40 16.27 7,684.18 MWD (2) 10,735.46 78.21 51.73 6,749.97 6,659.97 5,528.23 5,419.00 5,990,205.07 533,904.80 16.79 7,712.89 MWD (2) 10,765.41 82.17 55.44 6,755.08 6,665.08 5,545.74 5,442.74 5,990,222.67 533,928.47 17.99 7,741.51 MWD (2) . 10,795.57 78.47 57.85 6,760.15 6,670.15 5,562.09 5,467.56 5,990,239.11 533,953.23 14.58 7,769.91 MWD (2) 10,825.65 83.17 58.62 6,764.95 6,674.95 5,577.71 5,492.80 5,990,254.83 533,978.41 15.83 7,798.03 MWD (2) 10,855.66 87.54 62.25 6,767.38 6,677.38 5,592.46 5,518.81 5,990,269.67 534,004.36 18.90 7,825.96 MWD (2) 10,885.59 88.40 65.63 6,768.44 6,678.44 5,605.60 5,545.68 5,990,282.91 534,031.17 11.65 7,853.19 MWD (2) 10,915.48 91.11 69.92 6,768.56 6,678.56 5,616.90 5,573.34 5,990,294.32 534,058.79 16.98 7,879.51 MWD (2) 10,945.31 90.86 74.89 6,768.05 6,678.05 5,625.92 5,601.76 5,990,303.44 534,087.17 16.68 7,904.55 MWD (2) 10,975.08 90.95 78.34 6,767.58 6,677.58 5,632.81 5,630.71 5,990,310.44 534,116.10 11.59 7,928.29 MWD (2) 11,005.32 93.47 81.39 6,766.41 6,676.41 5,638.12 5,660.45 5,990,315.87 534,145.81 13.08 7,951.32 MWD (2) 11,035.67 94.00 78.43 6,764.44 6,674.44 5,643.43 5,690.27 5,990,321.29 534,175.60 9.89 7,974.38 MWD (2) 11,070.46 92.24 73.80 6,762.54 6,672.54 5,651.76 5,723.98 5,990,329.75 534,209.28 14.22 8,002.27 MWD (2) 11,100.79 90.21 68.25 6,761.89 6,671.89 5,661.62 5,752.64 5,990,339.71 534,237.90 19.48 8,028.11 MWD (2) 11,130.57 92.21 64.58 6,761.26 6,671.26 5,673.53 5,779.92 5,990,351.73 534,265.13 14.03 8,054.66 MWD (2) 5/17/2010 11:49:39AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips KAI Conoco Phillips Definitive Survey Report BAKER A HUGHES laska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1Q Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad MD Reference: 1Q -03 @ 90.00ft (Nordic 1) I Well: 1Q - 03 North Reference: TRUE 1 WOlibore: 1Q Survey Calculation Method: Minimum Curvature Design: 1Q-03 Database: EDM Alaska Prod v16 r Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation • (ft) (1 C) (ft) (ft) (ft) (ft) (ft) (ft) ( /100') (ft) 11,160.42 92.91 60.53 6,759.93 6,669.93 5,687.27 5,806.38 5,990,365.57 534,291.54 13.76 8,082.09 MWD (2) 11,190.66 91.07 56.62 6,758.88 6,668.88 5,703.02 5,832.16 5,990,381.42 534,317.26 14.28 8,110.65 MWD (2) 11,220.62 92.64 52.65 6,757.91 6,667.91 5,720.35 5,856.58 5,990,398.83 534,341.60 14.24 8,139.56 MWD (2) 11,250.49 94.61 47.52 6,756.02 6,666.02 5,739.47 5,879.43 5,990,418.04 534,364.38 18.36 8,168.85 MWD (2) 11,280.52 93.87 42.86 6,753.80 6,663.80 5,760.57 5,900.67 5,990,439.22 534,385.54 15.67 8,198.64 MWD (2) 11,305.50 93.41 37.93 6,752.21 6,662.21 5,779.55 5,916.82 5,990,458.26 534,401.62 19.78 8,223.56 MWD (2) 11,340.05 92.67 33.97 6,750.38 6,660.38 5,807.48 5,937.07 5,990,486.26 534,421.76 11.64 8,257.99 MWD (2) 11,370.00 91.26 25.62 6,749.35 6,659.35 5,833.43 5,951.93 5,990,512.26 534,436.52 28.26 8,287.46 MWD (2) 11,400.13 95.62 26.90 6,747.54 6,657.54 5,860.39 5,965.24 5,990,539.27 534,449.72 15.08 8,316.73 MWD (2) 11,430.27 98.78 23.93 6,743.76 6,653.77 5,887.39 5,978.07 5,990,566.32 534,462.44 14.33 8,345.72 MWD (2) 11,460.13 95.96 20.44 6,739.93 6,649.93 5,914.81 5,989.24 5,990,593.78 534,473.51 14.95 8,373.98 MWD (2) 11,491.51 92.18 19.06 6,737.71 6,647.71 5,944.26 5,999.82 5,990,623.27 534,483.98 12.82 8,403.43 MWD (2) 11,520.31 89.63 17.12 6,737.25 6,647.25 5,971.63 6,008.76 5,990,650.67 534,492.81 11.12 8,430.23 MWD (2) 11,550.33 87.17 15.25 6,738.09 6,648.09 6,000.45 6,017.12 5,990,679.51 534,501.06 10.29 8,457.78 MWD (2) 11,580.11 88.40 10.88 6,739.24 6,649.24 6,029.43 6,023.85 5,990,708.51 534,507.68 15.23 8,484.42 MWD (2) 11,610.24 88.28 6.42 6,740.11 6,650.12 6,059.19 6,028.38 5,990,738.30 534,512.09 14.80 8,510.26 MWD (2) 11,640.21 88.62 1.42 6,740.93 6,650.93 6,089.07 6,030.42 5,990,768.18 534,514.03 16.72 8,534.61 MWD (2) 11,670.32 88.16 357.45 6,741.77 6,651.77 6,119.16 6,030.13 5,990,798.27 534,513.61 13.27 8,557.63 MWD (2) 11,700.36 88.19 353.48 6,742.73 6,652.73 6,149.09 6,027.75 5,990,828.18 534,511.13 13.21 8,579.21 MWD (2) • 11,730.29 90.06 350.49 6,743.19 6,653.19 6,178.72 6,023.58 5,990,857.79 534,506.84 11.78 8,599.41 MWD (2) 11,760.36 93.93 347.78 6,742.14 6,652.14 6,208.22 6,017.92 5,990,887.27 534,501.07 15.71 8,618.56 MWD (2) 11,790.43 94.27 343.30 6,739.99 6,649.99 6,237.26 6,010.43 5,990,916.27 534,493.47 14.90 8,636.19 MWD (2) 11,820.26 94.02 339.30 6,737.83 6,647.83 6,265.43 6,000.89 5,990,944.41 534,483.83 13.40 8,651.86 MWD (2) . 11,850.43 91.84 335.88 6,736.29 6,646.29 6,293.28 5,989.41 5,990,972.21 534,472.24 13.43 8,666.03 MWD (2) 11,880.26 89.17 332.59 6,736.03 6,646.03 6,320.14 5,976.45 5,990,999.02 534,459.17 14.20 8,678.50 MWD (2) 11,910.21 84.90 330.53 6,737.58 6,647.58 6,346.43 5,962.21 5,991,025.25 534,444.84 15.82 8,689.72 MWD (2) 11,940.29 82.43 327.22 6,740.90 6,650.90 6,372.02 5,946.76 5,991,050.78 534,429.29 13.68 8,699.63 MWD (2) 11,970.32 81.56 322.83 6,745.08 6,655.08 6,396.38 5,929.72 5,991,075.07 534,412.16 14.76 8,707.57 MWD (2) 12,000.37 82.52 318.86 6,749.24 6,659.24 6,419.45 5,910.93 5,991,098.07 534,393.29 13.47 8,713.41 MWD (2) 12,025.41 85.70 316.49 6,751.81 6,661.81 6,437.87 5,894.16 5,991,116.41 534,376.45 15.81 8,716.94 MWD (2) 12,055.39 85.76 311.74 6,754.05 6,664.05 6,458.67 5,872.70 5,991,137.14 534,354.91 15.80 8,719.34 MWD (2) 5/17/2010 11:49:39AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips MRS CanocaPhillips Definitive Survey Report HUGHES BAKER Alaska 1 Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1Q -03 I Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) i Site: Kuparuk 1Q Pad MD Reference: 1Q -03 @ 90.00ft (Nordic 1) I Well: 1Q - 03 North Reference: TRUE 1 Wel'bore: 1Q Survey Calculation Method: Minimum Curvature i Design: 1Q Database: EDM Alaska Prod v16 � i Survey -_ - --' Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W +E/ -W Northing Fasting ° Section Survey Tool Name Annotation (ft) ( °) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( 1100') (ft) 12,085.23 89.02 309.52 6,755.40 6,665.40 6,478.08 5,850.08 5,991,156.45 534,332.22 13.21 8,719.91 MWD (2) • 12,115.29 88.62 304.97 6,756.02 6,666.02 6,496.26 5,826.17 5,991,174.55 534,308.24 15.19 8,718.72 MWD (2) 12,145.27 88.56 301.04 6,756.76 6,666.76 6,512.58 5,801.04 5,991,190.77 534,283.05 13.11 8,715.32 MWD (2) 12,175.10 88.89 296.32 6,757.43 6,667.43 6,526.89 5,774.88 5,991,204.98 534,256.84 15.86 8,709.71 MWD (2) 12,205.43 89.29 291.79 6,757.91 6,667.91 6,539.25 5,747.19 5,991,217.23 534,229.11 14.99 8,701.62 MWD (2) 12,235.40 88.44 287.08 6,758.50 6,668.50 6,549.22 5,718.95 5,991,227.09 534,200.83 15.97 8,691.33 MWD (2) 12,265.70 89.29 281.93 6,759.10 6,669.10 6,556.80 5,689.63 5,991,234.56 534,171.49 17.22 8,678.53 MWD (2) 12,295.38 89.45 277.36 6,759.43 6,669.43 6,561.77 5,660.38 5,991,239.42 534,142.22 15.41 8,663.74 MWD (2) 12,327.17 90.46 275.45 6,759.45 6,669.45 6,565.32 5,628.79 5,991,242.84 534,110.62 6.80 8,646.38 MWD (2) 12,362.24 91.75 269.21 6,758.78 6,668.78 6,566.74 5,593.77 5,991,244.14 534,075.60 18.17 8,625.19 MWD (2) 12,385.28 93.56 267.71 6,757.71 6,667.71 6,566.13 5,570.77 5,991,243.43 534,052.60 10.20 8,610.07 MWD (2) 12,415.56 95.26 265.34 6,755.38 6,665.38 6,564.30 5,540.63 5,991,241.49 534,022.48 9.61 8,589.49 MWD (2) 12,445.55 96.80 263.04 6,752.23 6,662.23 6,561.28 5,510.97 5,991,238.36 533,992.83 9.19 8,568.28 MWD (2) 12,475.35 97.41 260.48 6,748.54 6,658.54 6,557.04 5,481.70 5,991,234.01 533,963.58 8.77 8,546.39 MWD (2) 12,505.14 96.74 261.04 6,744.87 6,654.87 6,552.29 5,452.52 5,991,229.15 533,934.42 2.92 8,524.16 MWD (2) 12,560.00 96.74 261.04 6,738.44 6,648.44 6,543.81 5,398.71 5,991,220.46 533,880.65 0.00 8,483.37 PROJECTED to TD • 5/17/2010 11:49:39AM Page 5 COMPASS 2003.16 Build 69 1Q-03A and 1 Q -O3AL1 Final CTD Schematics 3 -1/2" Baker FVL @ 1763.7' RKB (locked out) 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 3 -1/2" Camco KBUG gas lift mandrels @ 1973.9', 4133.6' RKB 16" 62# H -40 shoe 103' MD ` @ Deformed joint @ 5440' RKB (passed CT deployed dummy BHA) "' 3 -1/2" Cameo KBUG gas lift mandrels @ 5540.1', 6274.8', 6780.9', 7285.4', 7794.4', 8380.0', 8912.8', 9476.6' RKB 3 -1/2" Camco MMG -2 gas lift mandrel @ 9949.6' 9 -5/8" 36# J -55 Baker 3 -1/2" PBR @ 9993.3" RKB (3.0" ID) shoe @ 5224' MD Baker FHL packer @ 10007.8' RKB (3.0" ID) 3 -1/2" Camco MMG -2 production mandrels @ 10044.8', 10114.6' RKB Holes @ 10290' and 10298' RKB (9 -8 -09 caliper) Tubing perfs @ 10299- 10309'(C -sand squeeze) • C -sand perfs (sqz prior to - _ e 3 -1/2" Camco MMG -2 production mandrel @ 10307.6' RKB CTD) 10170' - 10208' MD _ Top of Liner @ Baker FB -1 packer @ 10,347.8' RKB (4.0" ID) B -sand perfs (sqz prior to 10273' MD Baker SBE @ 10,351.1' RKB CTD) 10250' - 10267' MD \ 3 -1/2" Camco D nipple @ 10,387.4' RKB (2.75" min ID, No -Go) Perf holes ` ` 3 -1/2" tubing tail @ 10,421' RKB 10,295'- 10,305' RKB / \\\\,,- 3 -1/2" Monobore whipstock = -- \\\ TOWS © 10,299.3' MD ::. \ \ h I \\ 1Q -03AL1 1.16W,Ve \\ FISH (from pre -riq wellwork) \ \ (A3/A4 sang, wp11) .,,.,.,,, v ■ Kickoff from 1Q -03A @ 11512' 27' of Slickline tools \ __ -_ -_ _ _ - TD @ 13000' (top @ 10,347') \ `\ ___. r__,.., – a_; � - , ---- - - -----' Deployment Sleeve @ 10273' - 10274' Catcher Sub above D - nipple v \ \ .' / Slotted liner from 10274' - 12999' CA -2 Plug w/ gauges in D- nipple \�' �7 (10,387.4 RKB) %;' 1Q -03A F � �� (A3 sand, wp05) r - '� A - sand perfs Kickoff from 1Q -03 @ 10299.3' • 10556' - 10742' MD — ___ ---- - -_______ To @ 12565' - - -- Anchored billet @ 11512'- 11523' 7" 26# J -55 shoe @ Slotted liner from 11523'- 11652' 10910' RKB Anchored billet @ 11650'- 11663' —_ __ Reig Release Rig Accept 51/ 1 512 01 0 4/2/2010 Last Update 5118/2010 Slotted liner from 11663' - 12487' : I I �; KU P 1 1 Q -03A C�oct Phimps NeI( Attributes Max Angle & MD TD Aaska Wellho re APUUWI IF Id Name Well Status Ind(*) I MD (ftK8) Act Btm MKS) ronacot+nl,p. 500292124901 KUPARUK RIVER UNIT PROD 12,848.0 mm Coent H2S (pp.) (Date !Annotation End Date 1KB - Gsd (ft) Rig Release Date went fg 1.9_o3n,sn a7.?M SSSV: Locked Out 1 1 100 1 8/6/2009 Last WOE , 42.30 4/1/1985 m Srhenietu: Aclual_ .. 4141 A Depth (ftK8) End Date Annotation Last Mod ... End Date Last Tag: A Rev Reason: WELL SIDETRACKED Imosbor 5/17/2010 -_. 1111 4111 1415.. { Casing Strings HANGER. 33 ,. ; . 'Casing Description String 0... String ID ... Top (ft68) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.063 34 - 0 103.0 62.50 H C g D SURFACE s pt Stri 9 g 5/8 O Str8 7g 66 ID Top (35 HKB0 ) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I 5,223.8 36.00 J - 55 BTC Casing Descriptio String 0... String ID Top (H(B) Set Depth (f Set Depth (TIM) ... String Wt... String ... String Top Thrd " PRODUCTION 7 6.156 41.9 10,300.0 26.00 J - 55 BTC Casing Description String 0... String ID ... Top OMB) Set Depth (f... Sat Depth (1VD) .. String Wt... String .. String Top Thrd CONDUCTOR, LINER A TOP 23/8 1.995 11,512.4 11,652.0 4.60 L - 80 STL 34.103 Liner Details Top Depth SAFETY VLV, _ (TVD) Top Intl Nomi... 1,764 Top (fI88) (8KB) (1 Ian Description Comment 10 9n) 11,512.4 BILLET OH ANCHORED BILLET 1.995 GAS LIFT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1,974 - LINER A BOTTOM 2 3/8 1.995 11,651.3 12,487.0 4.60 L -80 STL I III, Liner Details GAS LIFT, Top Depth 4,134 (TVD) Top Intl Komi... Top (f t ) (1NCB) (7 Ian Desalption Comment ID (in) 11,651.3 BILLET OH Anchored Billet 1.995 11,664.0 . DEPLOY GS Torq Thru sub 1.000 SURFACE, 35.5,224 g g - Tubing Strings nr_r. Tubing Description String 0... String ID ...Top (ftKB) Sat Depth (1... Set Depth (1V13) ... String Wt... String ... String Top Thrd GAS LIFT, 5,540 _ - - `'' 1 UBING I 31/2 2.992 I 32.5 10,421.0 I 9.30 J -55 EUE8rd Completion Details GAS LIFT + - -- Top Depth 6,275 (TVD) Top Inc! II Nrinl... T op ( HKB) ( (% Item Description Comment ID (In) F GAS LIT. _- - -. -- -_. -_- s 781 - 32.5 HANGER McEVOY TUBING HANGER 3.500 I _ 1,763.7 SAFETY VLV BAKER SSSV TV!: ( OUT 6/19/2986) 2.810 9,993.3 PBR GASLIFT,_ 4141 i l l 7,265 - BAKER PBR 3.000 GAS LIFT, ,, . 10.007.8 PACKER BAKER'FHL' PACKER 3.000 - 7,794 - - -— 10,154.3 BLAS I J I CARBIDE BLAST JT 3.500 1 -_ GAS LIFT,_ 10,246 -7, BLAST JT STEEL BLAST JT 3.500 8,380 10,347.2 LOCATOR BAKER LOCATOR w/5' SEALS 3.000 GAS LIFT, . 10,347.8 PACKER _ -- - BAKER FB -2 PACKER - - -- 4.000 8,913 i 'I 10,351.1 SBE BAKER SBE 4.000 GAS LIFT, 10,387.4 NIPPLE CAMCO 'D' NIPPLE 2.750 9,477 10420.3 ''SOS CAMCO SHEAROUT SUB 3.000 411 — Notes: General & Safety End Date 1 Annotation GAS LIFT, 99W 5/17/2010 (NOTE WELL SIDE' RACKED 10 - 03A & 10 03AL7(off main wellbore) 2 page schematic 1141 PBR, 9,993 -- - L" PACKER, - - - 0,006 7 PRODUCTION, 4141 10,045 P PRODUCTION, _ 10,115 litt ( '1 PRODUCTION, 42- 10,300 PRODUCTION, �: 10,308 LOCATOR, lit 10,317 PACKER,_ - - 10,348 _ _ 4141 4141 mi mos SBE,10,351 - _..i` mit fig NIPPLE, 10,387 ":_:.. SOS, 10,420 __ ,.. Mandrel Details n Top Depth Top Port F (ND) Inc! OD Valve Latch Size TRO Run Stn Top ( ( BC B) (MKB) (1 Make Model (in) Seri Typo TyP. (in) (Psi) Run Dab Com... 1 1,973.9 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 5/24/2006 2 4,133.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/17/2010 3 5,540.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 5/24/2006 4 6,274 8 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/17/2010 LINERATOP, 5 6,780.9 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 8/10/1993 11412.11,652 11 6 7,285.4 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 10/25/1985 7 7,794.4 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/172010 8 8,380.0 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 6/8/2003 LINERA 9 8,912.8 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/172010 BOTTOM, • • _ 11,651 - 12,487 r 12,848 10 9,476.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 8/10/1993 TO (10-034 1 ` 12,848 KU P • 1 Q -03A CanocoPhiitips ,0* AJ'aS1c1l. Ire; - - - KB -Grd CR) Release Dab [ 42.30 Rig Release 4/1/1985 _S4henssiu HANGER, 33 7 • 1 � x CONDUCTOR, 34 -103 SAFETY VLV, 1,761 GAS LIFT, 1,974 I GAS LIFT, 4,134 SURFACE, 35 -5,224 GAS LIFT, 5,540 GAS LIFT, _ 6,275 GAS LIFT, 6,781 GAS LIFT, 1. 7,285 GAS LIFT,_ 7,790 GAS LIFT, 8,380 GAS LIFT, 8,913 GAS LIFT, 9,477 GAS LIFT, 9,950 PBR, 9,993 PACKER,_ — 10,008 PRODUCTION, 10,045 pi OF PRODUCTION, 10,115 PRODUCTION, A 42- 10,300 PRODUCTION, 10,308 LOCATOR, 10,347 ara PACKER, 10,348 0136, 10,351 -- NIPPLE, 10,387 SOS,10,420 - Mandrel Detaiis Top D Top OD (TV Port D) 1981 Valve Latch Size TRO Run Stn Top (ttKB) IRKS) _ (1 Make Model (in) Sere TYPe Type (in) (pal Run Date Can, 11 9,949.6 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 3/182010 12 10,044 -8 CAMCO MMG 11/2 PROD DMY RKP 0.000 0.0 3/18/2010 Closed 13 10,114.6 CAMCO MMG 1 1/2 PROD OPEN 0.000 0.0 3/31/2010 14 10,307.6 CAMCO MMG 1 1/2 PROD OPEN 0.000 0.0 3/31/2010 LINER ATOP, 11512- 11,652 LINERA BOTTOM, 11,651 - 12,487 TD(10-03A),� 1 12,848 10-03 Well Events Summary DATE SUMMARY 3/14/10 DRIFT TBG 2.69" & TAGGED @ , 9' SLM, EST. 4T FILL. PULL 1.5" OV r • 9' RKB & 1" GLV «t 7794' RKB. IN PROGRESS. 3/16/10 SET 2.75" CA-2 PLUG WITH GAUGES © 10387' RKB; A SANDS ISOLATED. ATTEMPT TO SET ' ° -"u' CATCHER TIGHT @ 5435' SLM.PULL 1" GLV FROM 4133' RKB.IN PROGRESS 3/17/10 SET CATCHER @ 10387' RKB.SET 1" DV @ 4133' & 7794' RKB.REPLACE 1" GLVS WITH 1" DVS @ 6274' RKB,8912' RKB.PULLED 1.5" CV'S FROM 10044' 10114' & 10308' RKB ALL C SANDS OPEN. 3/18110 SET 1.5" DV @ 10044' RKB.BULLHEAD 265 BBL'S DOWN IA TO CSAND FORMATION.SET 1.5" DV @ 9949' RKB.ATTEMPT TO DRIFT 5' OF 2.5" O.D. BAILER UNABLE TO PASS 5435' SLM.ABLE TO DRIFT 5' 2.25" DRIVEDOWN BAILER TO TOP OF CATCHER @ 10368' SLM,SCALE.MITIA FAILED; IN PROGRESS. 3/19/10 PERFORMED MITIA- PASSED. PULLED OFF FOR HIGHER PRIORITY JOB. 3/20/10 PERFORMED 30 MIN C SAND ONLY SBHPS @ 10220' RKB = 2245 PSI, 161 deg F. 15 MIN GRDIENT =2212 PSI. ATTEMPT TO PULL 36" CATCHER SUB; HAD TO DROP 2 CUTTER BARS TO CUT iMRE.RECOVERED ALL BUT 5' WIRE.'""2 CUTTERS AND 26.92' TOOLSTRING AND 3' CATCHER IN HOLE""".IN PROGRESS 3/21/10 PULLED 6.5' ROLLER STEM 1.5" CUTTER FROM 10297' SLM.PULLED 5' 1.875" CUTTER FROM 10306' SLM.RAN 2.25" LIB AND 2.60" LIB NO DEFINITIVE PICTURE.BAILED SCALE AND SAND TO 10317' SLM. IN PROGRESS. 3/22/10 BAILED FILL TO TOP OF TOOLSTRING © 10322' SLM.FISHED 20' .108 WRE.ATTEMPT TO PULL TOOLSTRING.SHEARED "R" TOOL.IN PROGRESS 3/23/10 BAILED SAND ON T/S FISH. ROPESOCKET © 10357' RKB. ATTEMPTED PULL TOOLSTRING & CATCHER (OAL: 29.91'); NO MOVEMENT, TOOLS SANDED IN. JOB SUSPENDED. 3/25/10 JARRED ON SUCKLINE FISH @ 10378' CTMD. HIT 50 X 45k (19 k OVER) LICKS WITH NO MOVEMENT. POOH TO CUT PIPE AND INSTALL FRESH CONNECTOR. IN PROGRESS. 3/26110 LOAD TBG WITH 100 BBLS OF 776 LUBICANT/DIESEL. WEIGHT OFF BTM REDUCED BY 6000#. JARRED ON FISH WITH OIL JARS (19K 31 HITS) WITH NO MOVEMENT. LOST ONE DOG OFF OF THE BAKER PULLING TOOL (4 3/4" LONG X 1/2" WIDE .20" THICK) JOB IN PROGRESS. 3/27/10 TAGGED @ 10351' SLM, NO IMPRESSION OF F /N. SET C SAND DVs @ 10115' AND 10308' RKB. IN PROGRESS. 3/28/10 PERFORMED CCL CORRELATION LOG TO DETERMINE DEPTH OF FISH, AND IF SPACE EXISTS TO ACCOMODATE A TUBING CUT BELOW THE SBE. TOP OF FISH ENCOUNTERED AT A DEPTH OF 10,347.0', INDICATING APPROXIMATELY 1.5' OF FISH EXTENDING UP INTO TUBING JOINT ABOVE PACKER. 3/28/10 BAILED 5' OF FILL TO TOP OF FISH © 10358' SLM. READY FOR E/L. 3/29/10 DRIFTED TBG WITH 10' x 2.25" TO TOP OF FISH @ 10354' SLM. READY FOR E -LINE. 3/30/10 PFRFORATED 10,299' - 10,309' INTERVAL WITH 2" X 10' GUN, LOADED 6 SPF, 60 -DEG PHASED BIG -HOLE CHARGES. CCL STOP DEPTH AT 10293'. CCL TO FIRST SHOT OFFSET MEASURED AT 6.0'. 3/31/10 PULLED C SAND DVs @ 10308' AND 10114' RKB. READY FOR CTU. 4/1/10 PUMPED 26 BBLS 17 PPG OF CLASS G CEMENT LAYING IN FROM 10347 CTMD, SQUEEZED 11 BBLS BEHIND PIPE, ACHIEVED SQZ PRESSURE OF 2000 PSI, JETTED TUBING TO TOC AT 10124 CTMD WITH BIOZAN/SW, WELL IS FRFF7F PROTECTED, TRAPPED 500 PSI ON WELL 4/3/10 TAGGED CEMENT PLUG 1 , 10080' SLM. ATTEMPTED MIT TBG, FAILED. 4/4/10 RAN 2.98" OD BI- CENTER BIT. MILLED HARD CEMENT (0.1 TO 2.0 FPM) FROM 10,126' TO 10,243' CTMD. PRIOR TO RUNNING IN WELL, ATTEMPTED TO MITT THE TUBING. TRAPPED PRESSURE ON HARDLINE AND CONFIRMED THAT ALL VALVES ON HARDUNE WERE LEAKING BY. WELLHEAD HELD 2000 PSI. OPEN WELL TO TANKS AND BLED TO 0 PSI. CONFIRM Q NO FLOW. RETURN IN AM TO FINISH MILLING. 4/5110 RAN 2.98" OD BI- CENTER BIT AND TAGGED AT 10,243' CTMD. CONTINUED MILLING HARD CEMENT FROM 10,243' CTMD TO 10,358' CTMD (10,343' RKB, STOPPING - 15' SHALLOW OF COIL FLAG). FREEZE PROTECTED WELL WITH 35 BBLS DIESEL. READY FOR SLICKLINE TAG. ;IQ-03 Well Events Spy 4010 PRE -CTD T-POT ( INCONCL E TO LOW T PRESSURE ), T ED ), IC-POT ( PASSED ), IC -PPPOT ( PASS , RE- ENERGIZE IC-PO, MIT -OA ( PASSE 4/6/10 TAG TOC @ 10,325' SLM, RAN PDS MULTIFINGER CALIPER f/ 10,325' SLM TO 9700' SLM-, GOOD DATA, COMPLETE. 417/10 (PRE CTD) PT & DD MV, SV & SSV. RESULTS INCONCLUSIVE DUE TO QUESTIONABLE VALVES. 4/11/10 PT TREE PRE CTD ( PASSED), T-DDT ( PASSED ) 4/13/10 MONITOR TUBING BUR. TUBING HAD 10 PSI_ BLEED T TO 0 PSI. • Page 1 of 2 Schwartz, Guy L (DOA) I a , - 3 11N From: Schwartz, Guy L (DOA) (f) - 3A 2./0- 026 Sent: Wednesday, March 31, 2010 9:55 AM 1 Q 3AL_ 2,1C= oL7 To: 'Ohlinger, James J' Subject: RE: 1Q -03 P &A (PTD 184 -233) James, The P & A segment of the procedure is acceptable as laid out in the last document you provided. You have approval to move ahead with the Cementing phase of the operation. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ohlinger, James J [mailto:James.J.Ohlinger @conocophillips.com] Sent: Wednesday, March 31, 2010 9:35 AM To: Schwartz, Guy L (DOA) Subject: RE: 1Q -03 My apologies, it was there at one point. I added the MASP. We were lined up on the schedule to pump the cement tomorrow. Is that going to be ok? From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, March 31, 2010 9:18 AM To: Ohlinger, James J Subject: RE: 1Q - James, I will make this change to the P & A sundry. Again.... as before this procedure should include the rig steps up to the window exit. Can you redo the sundry steps to include setting the whipstock and anything else the CTD does after it gets to location. Need reservoir pressure /MASP too. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ohlinger, James J [mailto:James.J.Ohlinger @conocophillips.com] Sent: Wednesday, March 31, 2010 8:52 AM To: Schwartz, Guy L (DOA) Subject: 1Q -03 I've attached a revised schematic and Pre -rig procedure for 1 Q -03. What's happened... Set a CA -2 plug w/ gauges in the D- nipple at 10,387 3/31/2010 • Page 2 of 2 Placed a catcher sub above while pulling the valves in the GLM's Went in with Slickline to pull the catcher sub and would not come free Dropped 2 cutter bars to release Fished the cutter bars and most of the wire 2 days with Slickline, and 2 days with Coil to try to fish the tools (27' Slickline BHA) Have given up trying to retrieve the tools, and planning to perform a dual string exit higher up in the well in the C- sand Straddle. Original KOP (in the 7 ") 10,555' New KOP 10,297' Targets the same, and 59' difference in original vs. new plan TD. James O!zlinger CTD Engineer ConocoPhillips AK, Inc. 907 - 265 -1102 office 907 - 748 -1051 cell 3/31/2010 - • TO 2 33 Application for Sundry to Plug Perforations KRU 1Q-03 1Q -03 Sundry (10 -403) Engineer: James Ohlinger CT Drilling Engineer , ,, « 1"'R' � ZtL � �z� -� {� (907) 265 -1102 C I tJ_c( k.� lam+ ` 76_ 3 -� -�a The anticipated spud date for Nabors CDR -2AC to drill dual CTD A -sand horizontal laterals from well 1Q -03 is April 2010. Summary of Operations: The 1Q-03 original completion will be cemented off prior to CTD drilling and although A -sand production will be replaced by the laterals, the current C -sand production in this well will be lost. Cement will plug all of the existing perforations. Pre -Rig Work • Slickline: Tag fill and obtain a SBHP survey • Slickline: Load Tubing & IA w/ diesel, dummy GLVs, MIT -IA. • Slickline: Dummy perf gun drift. • E -line: Run GR/CCL jewelry log / tie -in log from 10,340' RKB to 9,900' RKB. Shoot holes in the first 3 tubing joint below the Steel Blast joints, 10,295' to 10,305' RKB. • Slickline: Pull DV's out of the GLM's at 10,114' and 10,308' RKB. • Coil: Lay in cement plug from top of the fish at 10,347' RKB up to the GLM at 10,114.6' RKB, and squeeze into the 3 -1/2" straddle. • Slickline: Tag top of cement. • Coil: Pick up 2 -3/8" motor with 2.70" x 2.98" Bicenter bit. Drill out cement to 10,340' RKB. • Slickline: Tag TOC, pressure test cement plug. A caliper is a contingent on cement milling operation • Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Set top of whipstock at 10,297' MD. 3. Mill 2.80" window at 10,297'. 4. 1Q -03A Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 12,950' MD b. Run the 2 slotted liner from TD to 11,800' MD. An aluminum liner top billet will be placed at - 11,800' MD. Page 2 of 3 3/31/2010 I , • Application for Sundry to Plug Perforations KRU 1Q-03 5. 1 Q -03AL1 Lateral a. Kick off of the aluminum liner top billet at 11,800' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 12,950' MD c. Run the 2%" slotted liner from TD to 10,290' MD, into the 3 -1/2" tubing in the mother -bore. Post -Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Reservoir Pressure 1Q-04 is the closest offset well (60' left) producing in the A -sand interval and had a static bottom hole pressure of 1938 psi (6.1 ppg EMW). This is a combined A/C pressure. 1Q -02B is injecting water 60' to the right of 1Q -03 at 2131 psi. Similar pressures are expected as the laterals are drilled. The most recent static bottom hole pressure reading in 1Q -03 was 2517 psi (7.40 ppg EMW). MASP Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3000 psi. Maximum potential surface pressure is 1863 psi assuming a gas gradient to surface based on the most recent bottom hole pressure measurement which was 2517 psi at 6,543' TVD on October, 2009. Page 3 of 3 3/31/2010 1Q -03 Proposed CTD Sidetrack 3 -1/2" Baker FVL @ 1763.7' RKB (locked out) 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface iiiiiiiiiii 3 -1/2" Camco KBUG gas lift mandrels @ 1973.9', 4133.6' RKB 16" 62# H -40 MI shoe @ 103' MD Deformed joint @ 5440' RKB (passed CT deployed dummy BHA) I 3 -1/2" Camco KBUG gas lift mandrels @ 5540.1', 6274.8'. 6780.9', 7285.4', 7794.4', 8380.0', 8912.8', 9476.6' RKB 3 -1/2" Camco MMG -2 gas lift mandrel © 9949.6' 9 -5/8" 36# J -55 Baker 3 -1/2" PBR @ 9993.3" RKB (3.0" ID) shoe @ 5224' MD Baker FHL packer @ 10007.8' RKB (3.0" ID) 3 -1/2" Camco MMG -2 production mandrels @ 10044.8', 10114.6' RKB Holes @ 10290' and 10298' RKB (9 -8 -09 caliper) Tubing perfs @ 10299 - 10309' (C -sand squeeze) • C -sand perfs (sqz prior to CTD) 10170' - 10208' MD 3 -1/2" Camco MMG -2 production mandrel © 10307.6' RKB Baker FB -1 packer @ 10,347.8' RKB (4.0" ID) Baker SBE @ 10,351.1' RKB B -sand perfs (sqz prior to ) 10250' - 10267' MD „ 3 -1/2” Camco D nipple © 10,387.4' RKB (2.75" min ID, No -Go) Perf holes = E \ 3 -1/2" tubing tail @ 10,421' RKB 10,295'- 10,305' RKB \\�\ 1Q -03AL1 Lateral FISH 3 -1/2" Monobore whipstock w/ � 27 TD @ 12,950' MD of Slickline tools, top @ 10,347' TD 2-3/8" @ slotted /solid liner from TD to 4° kick removed ���` Catcher Sub above D- nipple TOWS @ 10,293' RKB` ��� 10,290' MD . \ CA -2 Plug w/ gauges in D- nipple @10,387,4 RKB 10,297' ELM. r" \ \ \, , \ \ ` 1 Q -03A Lateral • A -sand perfs \\`�`� TD @ 12,950' MD 10556' - 10742' MD — — 2 -3/8" slotted liner w/ aluminum billet = — --- - - - - -- - - -- 'Iiiiiid - -- — @ 11,800' - - -- - -- -- -- - - - - - - - 7" 26# J -55 shoe @ 10910' RKB �.01111 EITAITE o[F ALAsEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James L. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Q-03A ConocoPhillips Alaska, Inc. Permit No: 210 -026 Surface Location: 1216'FNL, 1116' FEL, Sec. 26, T12N, R9E, UM Bottomhole Location: 290' FSL, 1483' FEL, Sec. 13, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. incerely, Daniel T. Seamount, Jr. Chair DATED this 11 day of March, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) RECEIVE • • STATE OF ALASKA MAR 0 9 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL klaskaQi&Gascaacommission 20 AAC 25.005 1;9 Anchorage 1 a. Type of Work: 1 b. Proposed Well Class: Development - Oil Q - Service - Winj ❑ Single Zone 1 c. Specify if well is proposed for: Drill ❑ Re -drill 0 Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket U Single Well 11. Well Name and Number: ConocoPhillipsAlaska, Inc. Bond No. 59 - 52 - 180 • 1Q - 03A , 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 12870' ' TVD: 6630' ' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation ease Number): Surface: 1216' FNL, 1116' FEL, Sec. 26, T12N, R9E, UM Y� ADL6 1, 25634 Kuparuk River Oil Pool ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 292' FSL, 1368' FEL, Sec. 13, T12N, R9E, UM 2572, 2567 5/15/2010 Total Depth: 9. Acres in Property: 14. Distance to 290' FSL, 1483' FEL, Sec. 13, T12N, R9E, UM 2560 Nearest Property: 20245 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 90 feet • 15. Distance to Nearest Well Open Surface: x - 528507' y - 5984657 ' Zone 4 GL Elevation above MSL: 47.5 feet ' to Same Pool: 3C -13 @ 1085' , 16. Deviated wells: Kickoff depth: 10555 ft. i 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 97 deg Downhole: 2517 psig . Surface: 1863 psig 18. Casing Pro ram: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 1045' 11825' 6633' 12870' 6630' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 10944 6934 10817 6869 10690 Casing Length Size Cement Volume MD TVD Conductor /Structural 69' 16" 240 sx CS II 101' 101' Surface 5189' 9.625" 1300 sx CS III, 550 sx CS I, 5224' 3636' Intermediate 89 sx CS I Production 10878' 7" 470 sx Class G, 250 sx CS I 10910' 6916' Liner Perforation Depth MD (ft): . 3 , jo Perforation Depth TVD (ft): - ' ' • • • • ' 0498' - 0x21', Cl4CLUYX, C723' C7C/3', C737' 6708', 6822' 6826! 20. Attachments: Property Plat ❑ BOP Sketch El Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date: .4Q / 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 11021/ , Printed Name V. Cawve Title Alaska Wells Manager Signature . Phon 265 -63o6 Date 3/e/ Z 0 Commission Use Only Permit to Drill .,. API Number: 1 2. < Cy Permit Approval See cover letter Number 2 /C 6 c_' 6 c... 50- 0 ?Si " CI' C-C-:1 Date: „a/ Ilip for other requirements Conditions of approval : If box is checked, /e well may not be used to explore for, test, or produce coalbed m gas hydrates, or gas contained in shales: 7 'A 3000 / o S4 661 s (- 10 Samples req'd: Yes No Mud log req'd: Yes ❑ No 2' Other: � H2S measures: Yes [/ No El Directional svy req'd: Yes RI No ❑ • 4 2.5o C] ( St. AhI.a 1C 5 ( VIA .v.,) � I 3/ i 5 //© DATE: APPROVED BY THE COMMISSION _ COMMISSIONER r r n Form m 10 -401 (Revised 7/2009) his permit is valid for 24 m f the time dlf t p r val (20 AAC 25.005(9)) ,Submit in Duplicate ConocoP h lli p s RECEIVED Alaska MAR 0 9 2010 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 *deal 8488COMCOfi February 26, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill two lateral sidetracks out of Kuparuk Well 1 Q -03 using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 1 Q -03 as early as May 2010. The CTD objective is to drill two lateral sidetracks (1 Q -03A, 1 Q- 03AL1); targeting the A3 and A4 -sands to access reserves in the northwest corner of a fault block and develop banked oil along sealing faults. Both laterals will be drilled from a single exit in the 7" casing. The window will be milled with a 2.80" mill off a whipstock set at 10,555' MD. Attached to this application are the following documents: — Permit to Drill Application Forms for 1Q-03A and 1 Q -03AL1 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic — Sundry Application — Plug perforations If you have any questions or require additional information please contact me at 907 - 265 -1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer • Permit to Drill Summary of Operations KRU 1Q-03A, and 1 Q -03AL1 Laterals Coiled Tubing Drilling Overview: Well 1 Q -03 is currently a producer completed in the C1, A4, and A2 sands through the 7" production casing with 3-1/2" tubing to surface. The proposed CTD sidetracks will be named 1Q-03A & 1 Q -03AL1 and will target the A3 and A4 -sands to access reserves in the northwest corner of a fault block and develop banked oil along sealing faults. A cement plug will be placed across the existing perforations, and a 2.80" pilot hole will be a drilled on the high - side of the 7" casing to a depth of approximately 10,585' MD. A whipstock will then be set at 10,555' MD for a - high-side casing exit. The 1 Q -03A completion is planned for a 2 -3/8" slotted liner with a liner -top aluminum billet for the KOP for the AU lateral at 11,825' MD. The completion for 1 Q -03AL1 will consist of a 2 -3/8" slotted liner with the liner top brought up into the existing 3 -1/2" tailpipe to approximately 10,400' MD. Operational Outline Pre -Rig Work • Slickline: Tag fill and obtain a SBHP survey • Slickline: Load Tubing & IA w/ diesel, dummy GLVs, MIT -IA. • E -line: Shoot holes in the 3'/2" tubing below the Baker FB -1 Packer and in the 3 -1/2" Straddle to put cement across /above the tubing tail, and squeeze into the 3 -1/2" Straddle. • Coil: Mill out the D- nipple at 10,389' MD to 2.80" with a left -hand motor. • Coil: Lay in a cement plug from tag depth up above the Tubing Tail, and squeeze into the 3 -1/2" straddle to shut -off the A & C- sands. • Slickline: Tag top of cement, pressure test. • Coil: Drill out cement to the top of the D- Nipple at 10,389' MD. • Slickline: Drift whipstock dummy. • Prepare wellsite for rig arrival. Rig Work `3 %Q °O6o s 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. 3. Set top of whipstock at 10,555' MD. 4. Mill 2.80" window at 10,555'. 5. 1Q -03A Sidetrack t a. Drill a 2.70" x 3" bi- center lateral to a TD of 12,870' MD ' rrJ b. Run the 2%" slotted liner from TD to 11,825' MD. An aluminum liner top billet will be placed at 11,825' MD. ,x10 -0P4 6. 1 Q -03AL 1 Lateral a. Kick off of the aluminum liner top billet at 11,825' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 12,830' MD - FOP c. Run the 2%" slotted liner from TD to —10,400' MD, into the 3 -1/2" tubing in the a f o _027 mother -bore. Page 2 of 5 3/2/2010 • • Permit to Drill Summary of Operations Cont. KRU 1Q - 03A and 1Q - 03AL1 Post -Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program • Chloride -based Biozan brine (8.9 ppg) for milling operations, and chloride -based Flo -Pro mud ( -8.9 ppg) for drilling operations. • There is no SSSV installed in 1 Q -03 so we will have to load the well with completion fluid to deploy the 2- %" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class 11 drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 1Q - 03A 10,555 12,870 2% ", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 1Q - 03AL1 11,825 12,830 2 4.7 #, L -80, ST -L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 62 H -40 34 103 1640 670 Surface 9 ° / 36 J -55 35 5,224 3520 2020 Casing 7" 26 J -55 32.3 10,910 4980 4320 Tubing 3 % " 9.3 J -55 32.5 10,421 7950 8330 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid - may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3000 psi. Maximum potential surface pressure is 1863 psi assuming a gas gradient to surface based on fFe most recent bottom hole pressure measurement which was2517 psi at 6,543' TVD on October, 2009. • The annular preventer will be tested to 250 psi and 2500 psi. Page 5 of 5 3/2/2010 • Permit to Drill Summary of Operations Cont. KRU 1Q -03A and 1Q -03AL1 Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1Q -03A 20,245' 1Q - 03AL1 20,245' • Distance to Nearest Well within Pool (toe measured to offset well 3C -13) Lateral Name Distance 10-03A 1085' 1 Q -03AL1 1100' Logging MWD directional, resistivity, and gamma ray will be run over the entire open - hole sections. Reservoir Pressure 1Q -04 is the closest offset well (60' left) producing in the A -sand interval and had a static bottom hole pressure of 1938 psi (6.1 ppg EMW). This is a combined A/C pressure. 1Q -02B is injecting water 60' to the right of 1 Q -03 at 2131 psi. Similar pressures are expected as the laterals are drilled. The most recent static / bottom hole pressure reading in 1Q-03 was 2517 psi (7.40 ppg EMW). Hazards • There is some "cork screwed" tubing at 5,440' MD RKB, and a Gyro and whipstock drift have been successfully deployed with confidence that CTD can continue. • Well 1Q-03 has 100 ppm H as measured on Aug. '09. The maximum H level on the 1Q pad is 200 ppm measured on July '09 at 1Q-23. All H monitoring equipment will be operational. Page 5 of 5 3/2/2010 • Permit to Drill Summary of Operations Cont. KRU 1Q -03A and 1Q -03AL1 Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.9 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 allows for the use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located 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 with trapped wellhead pressure. Pressure deployment of the 2'/" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 1Q -03 does not have a SSSV, so the well will have to be loaded with completion fluid 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 charts show the different pressure parameters in both "pumps on" and "pumps off" conditions. Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 2517 psi 2517 psi Mud Hydrostatic (8.9 ppq) 3070 psi 3070 psi Annular friction (i.e. ECD) 1000 psi 0 psi Mud + ECD Combined 4070 psi 3070 psi (no choke pressure) (overbalanced (overbalanced -1553 psi) -553 psi) Target Pressure (11.8 ppg) 4070 psi 4070 psi Choke Pressure Required 0 psi 1000 psi to Maintain 11.8 BHP Example: Using the 1Q-03 SBHP from Oct, 2009; is a reservoir pressure of 2517 psi at 6543' TVD (7.40 EMW). While drilling and circulating at 1.5 bpm with 2" e-coil, head from the 8.9 ppg mud (3072 psi), plus an estimated 1000 psi of annular friction (assuming friction of 94 psi /1000 ft) will provide 4070 psi BHP (11.80 ppg EMW) and overbalance the reservoir by -1553 psi. When circulation is shut down, the mud will still overbalance the reservoir pressure. However maintaining -1000 psi at surface when the pumps are shut down will maintain a constant 11.8 EMW to promote formation stability. Page 5 of 5 3/2/2010 1Q-03 Proposed CTD Sidetrack 3 -1/2" Baker FVL @ 1763.7 RKB (locked out) 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 16" 62# H-40 3 -1/2" Camco KBUG gas lift mandrels @ 1973.9', 4133.6' RKB shoe @ 103' MD — — Deformed joint @ 5440' RKB (passed CT deployed dummy BHA) _ 3 -1/2" Camco KBUG gas lift mandrels @ 5540.1', 6274.8', 6780.9', 7285.4', 7794.4', 8380.0', 8912.8', 9476.6' RKB 9 -5/8" 36# J -55 shoe @ 5224' MD 3 -1/2" Camco MMG -2 gas lift mandrel @ 9949.6' mom IMMMII Baker 3 -1/2" PBR @ 9993.3" RKB (3.0" ID) Baker FHL packer @ 10007.8' RKB (3.0" ID) • — C -sand perfs (sqz prior to 3 -1/2" Camco MMG -2 production mandrels @ 10044.8', 10114.6', CTD) 10170' - 10208' MD 10307.6' RKB _ — ` --,_ Holes @ 10290' and 10298' RKB (9 - 8 - 09 caliper) B -sand perfs (sqz prior to Baker FB -1 packer @ 10,347.8' RKB (4.0" ID) CTD) 10250' - 10267' MD ■ Baker SBE @ 10,351.1' RKB Perf holes – 10,370' l l Tubing punch perfs @ 10370' (to lock in tubing tail) ANIL Camco D nipple @ 10,387.4' RKB (2.75" min ID, No -Go) 1Q -03AL1 Continency Lateral 2 -3/8" liner top @ 10,400' MD Cement top 3 -1/2" tubing tail @ 10,421' RKB 1000' approximate length below nipple @ 2 -3/8" slotted /solid liner from TD to 10400' MD 10400' MD ` 2 -5/8" whipstock tray w/ OH ...--) anchors set in 2.80" cement ,` ` pilot hole at 10,555' MD. \,, • 1Q -03A Lateral A -sand perfs (sqz prior • TD @ 12,900' MD to CTD) — 2 - 3/8 " slotted liner w/ aluminum billet 10556' - 10742' MD cement 4111 11 11100 1 \ Cement pilot hole (2.80 ") 0' drilled to 10585' MD 7" 26# J -55 shoe 'r , @ 10910' RKB t' ' ' V- .. , ..,t KUP 1Q -03 Conoc JPhllll� ,� . Well Attributes _ Max Angle & MD TD ? ` Wellbore APUUWI 'Field Name Well Status Ind (1 MD (ItKB) Act Btm (RKB) Alaska Ire. Iles fti 500292124900 I KUPARUK RIVER UNIT PROD 60.86 3,000.00 10,944.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date • •• we Conrig: -13. 3, 2254010 933:19 AM SSSV: Locked Out 100 8/6/2009 Last WO: 42.30 4/1/1985 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 10,708.0 10/7/2009 Rev Reason: UPDATE TO 9.0 FORMAT Imosbor 2/25/2010 Casing Strings F Casing Description String 0... String ID ... Top (ftK8) Set Depth (f._ Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.063 34.0 103.0 103.0 62.50 H HANGER, 33 - Casing Description ;String 0... String ID .. Top (ftKB) Set Depth (L_ Set Depth (TVD) ... String Wt... String ... String Top Thrd I E P SURFACE 95/8 8.766 35.0 5,223.8 3,635.5 36.00 J BTC Casing Deaciption !String 0... [String ID ... 'Top (Po(8) Set Depth (f._ Set Depth (TVD) ... 1 Strmg Wt... String ... String Top Thrd PRODUCTION 7 6.156 32.3 10,910.1 6,916.0 26.00 J-55 BTC Tubing Strings J Tubing Description String 0... String ID ... ■Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd CONDUCTOR,_ TUBING 31/2 2.992 I 32.5 10,421.0 6,646.2 9.30 J - 55 EUE8rd 34103 . __ --- Completion Details Top Depth SAFETY VLV, [. (TVD) Top Ind Norni... 1,764 Top (ftK8) (RKB) (1 /tern Description Comment ID (in) • 32.5 32.5 -1.06 HANGER McEVOY TUBING HANGER 3.500 1,763.7 1, 681.5 34.55 SAFETY VLV BAKER SSSV 'FVL' (LOCKED OUT 6/19/2986) 2.810 GAS LIFT, 1,974 9,993.3 , 389.6 51.50 BAKER PBR 3.000 10 6 ,398.6 51.00 PACKER BAKER 'FHL' PACKER 3.000 GAS411F = 10,154.3 6,488.8 52.62 BLAST JT CARBIDE BLAST JT 3.500 10,246.7 6,544.2 53.44 BLAST JT STEEL BLAST JT 3.500 10,347.2 6,603.3 54.43 LOCATOR BAKER LOCATOR w /5' SEALS 3.000 10,347.8 6,603.7 54.44 PACKER BAKER FB-2 PACKER 4.000 SURFACE, 355,224 10,351.1 6,605.4 53.90 SBE BAKER SBE 4.000 GAS LIFT, 1 10,387.4 6,626.6 54.27 NIPPLE CAMCO 'D' NIPPLE 2.750 5,540 10,420.3 6,645.7 54.52 SOS CAMCO SHEAROUT SUB 1 3.000 GAS LIFT, 6,275 ..i Other In Hole. (Wlreiineretrievable plugs, valves, pumps, fish, etc.) i Top Depth GAS LIFT, (TVD) Top Ind 6,761 Top (RKB) (RKB) P) Description _ Comment I Run Date ID (in) 10,690 6,797.6 57.05 FISH 1 1/2" CV Empty Pocket; Fell to Rathole ',11/1/1993 1.000 GAS LIFT, _ -' -- 7,265 Perforations & Slots • - 1 Shot • GAS DFT, IV__ Top (TVD) Btm (TVD) ' Dens 7' 1. Top (ftKB) Btm (ftKB) (MR) (RKB) Zone Date (. Type Comment GAS LIFT, 10,170 10,208 6,498.3 6,521. C-1, UNIT B, 5/4/1985 12.0 IPERF 5" Scalloped Gun e,360 10-03 10,250 10,267 6,546.2 6,556.3 UNIT 8, 10-03 5/4/1985 12.0 IPERF 5" Scalloped Gun GAS LIFT, �y. 8,913 10,556 10,638 6,723.3 6,769.1 A-4, A-3, 10-03 5/4/1985 4.0 IPERF 120 deg. phasing, 4' Cartier JJ 11 Gun GAS LIFT, 10,556 10,638 6,723.3 6,769.1 A-4, A-3, 10-03 7/25/1993 4.0 RPERF Oriented 13 deg. CCW F/ Bottom of 9,477 Hole, 2 1/8" EnerJet 1 10,670 10,690 6,786.7 6,797.6 A -2, 10-03 5/4/1985 4.0 IPERF 120 deg. phasing, 4" Cagier JJ II Gun GAS LIFT, -._ 9,950 10,670 10,690 6,786.7 6,797.6 A-2, 10-03 7/25/1993 4.0 RPERF 2 1/8" EnerJet, Oriented 13 deg. MI CCW F/ Bottom of Hole I 10,734 10,742 6,821.6 6,825.9 A -2, 10-03 5/4/1985 4.0 IPERF 120 deg. phasing, 4" Cattier JJ II Gun PBR, 9,993 . _ PACKER, Notes: General & Safety - _ 10,008 -_ End Date Annotation 4/3/1996 NOTE: VIDEO SURVEY; Deformed TBG @ 5460'; LEAK @ 10302' PRODUCTION, 4 /3/1996 NOTE: Attempt to drift Buckled 10 _ Tbg @5640' RKB on 9/11197 - No Success PRODUCTION, 11/22/1997 NOTE: Possible Problem w/ Key Profile of 'D' Nipple 10,115 5/25/2006 NOTE: TBG TIGHT SPOT 5447' WLM W/2.79 "X96" DRIFT a 2/25/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 (2 page schematic, print double- sided) IPERF, - - -- 10,170.10,208 • ■ • ''. IPERF, 10,25010,267 - PRODUCTION, 10,306 - LOCATOR, 10,347 PACKER, 10,348 SBE, 10,351 NIPPLE, 10,387 SOS, 10,420 Mandrel Details Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run RPERF, Stn Top (ftKB) (ftKB) 1°) Make Model (in) 5ery Type Type (in) (Ph) Run Date Com... 10,ss510,638 N. 1 1,973.9 1,852.9 39.02 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 5/24/2006 IPERF, 10,556 - - 2 4,133.6 3,043.2 57.52 CAMCO KBUG 1 GAS LIFT GLV BK2 0.156 1,370.0 6/8/2006 RPERF, 10600 10,670. 3 5,540.1 3,797.6 57.94 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 5/24/2006 PERF, 10,870 - - - 4 6,274.8 4,200.4 55.15 CAMCO KBUG 1 GAS LIFT GLV BK2 0.188 1,390.0 6/8/2006 FISH, 10,690 • 5 6,780.9 4,492.7 54.16 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 8/1011993 IPERF, _ - 6 7,285.4 4,787.9 53.92 CAMCO KBUG 1 GAS LIFT DMY BK.2 0.000 0.0 10/25/1985 10,734 742 7 7,794.4 5,084.6 54.95 CAMCO KBUG 1 GAS LIFT GLV BK2 0.188 1,375.0 6/8/2006 8 8,380.0 5,425.3 53.75 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 6/8/2003 9 8,912.8 5,737.3153.36 CAMCO KBUG 1 GAS LIFT GLV BK2 0.188 1,355.0 6/8/2006 PRODUCTION, 32 10,910 * 10 9,476.6 6,070.8 51.85 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 8/10/1993 TD, 10,946 IA KUP 1Q-03 ConoccPhnlips x,11. . -... - ... - ... ..... KB-Grd (R) Rig Release Date '° 42.30 4/1/1985 Well Conti¢ -10.03, 21250010 903:19 AM Schematic -Actual It • 1 HANGER, 33 a 1 CONDUCTOR, 34.103 SAFETY VLV, 1,764 ASV GAS LIFT, 1,974 GAS LIFT, __ 4,134 SURFACE, 35 -5,224 GAS LIFT, 5,540 GAS LIFT, _.. 6.275 II GAS UFT, 6,781 Ift a '' GAS LIFT, it 7,285 1 GAS LIFT, IIIV 7,794 GAS LIFT, ___ 8,380 II I GA6LIFT,___ 8,913 GAS LIFT, ilt 9,477 a GAS LIFT, ,_ 9,950 II . 1 PBR, 9,993 :. ... PACKER, _ 10,008 — ............._. - a PRODUCTION, 10,045 a' ''. PRODUCTION, 10,115 1 _ a : at IPERF, -- _ 10,170 - 10,209 1 IPERF, _ 10,25010, 267 — —` - PRODUCTION, 10,308 1 LOCATOR,_ 10,347 PACKER, 10,348 T SBE, 10,351 G -' NIPPLE, 10,387 e�� SOS, 10,420 Mandrel Details Top Depth Top Port (TVD) Inc! OD I 1 Valve Latch Siu TRO Run RPERF, Stn Top (RKB) (RKB) (1 Make Model (in) Sery Type Type (in) (Pm) Run Date Conn_. 10,55610638 11 9,949.6 6,362.6 51.73 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 6/8/2006 IPERF, 10,55610638 12 10,044.8 6,421.7 51.79 CAMCO MMG 1 1/2 PROD CV RKP 0.000 0.0 1/20/2009 Open RPERF, 10.67o-10, 690 13 10,114.6 6,464.7 52.18 CAMCO MMG 11/2 PROD CV RKP 0.000 0.0 1/16/2009 Open 10,670 690 - - -- 14 10,307.6 6,580.0 53.40 CAMCO MMG 1 1/2 PROD CV RKP 0.000 0.0 1/16/2009 Open FISH,10,690 IPERF, 10,734 - 10,742 PRODUCTION, 32-10,910 N 4 ' TD, 10,94 • I C onocoPhilli ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1Q Pad 1Q-03 1Q-03A Plan: 1 Q -03A wp03 Standard Planning Report 25 February, 2010 ertO BAKER HUGHES 4 11/ 0 - ConocoPhillips ream ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 Q -03 Company: ConocoPhillips(Alaska) Inc. TVD Reference: - - Mean Sea Level Project Kuparuk River Unit MD Reference: _ 1Q -03 © 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad North Reference: True Well: 1Q -03 Survey Calculation Method: Minimum Curvature Wellbore: 1 Q -03A Design: 1Q -03A wp03 Project Kuparuk River Unit 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 1Q Pad Site Position: Northing: 5,984,677.62ft Latitude: 70° 22' 9.206 N 1 From: Map Easting: 528,389.22ft Longitude: 149° 46' 9.484 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.22 ° Well 1Q-03 Well Position +N / -S 0.00 ft Northing: 5,984,656.79 ft , Latitude: 70° 22' 8.996 N +E / -W 0.00 ft Easting: 528,507.43 ft ' Longitude: 149° 46' 6.028 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.50ft < Wellbore 1Q-03A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) - (°) (nT) - BGGM2009 5/1/2010 17.21 79.83 57,377 Design 10-03A wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,500.00 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) (°) -47.50 0.00 0.00 315.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/.S +E/ -W Rate Rate - Rate TFO (ft) r) r) (ft) (ft) (ft) ( ° /100ft) (° /100ft) -- (1100ft) (°) Target 10,500.00 55.13 42.42 6,601.68 5,346.78 5,274.27 0.00 0.00 0.00 0.00 10,555.00 55.70 42.56 6,632.90 5,380.17 5,304.86 1.06 1.04 0.25 11.47 10,570.00 57.05 42.56 6,641.21 5,389.37 5,313.31 9.00 9.00 0.00 0.00 10,630.00 75.05 42.56 6,665.46 5,429.60 5,350.24 30.00 30.00 0.00 0.00 10,682.88 90.00 47.92 6,672.33 5,466.36 5,387.38 30.00 28.27 10.14 20.00 10,892.88 91.49 73.08 6,669.55 5,568.93 5,568.67 12.00 0.71 11.98 86.50 10,992.88 91.46 61.08 6,666.97 5,607.78 5,660.58 12.00 -0.03 -12.00 270.00 11,432.88 89.29 8.32 6,663.89 5,956.87 5,902.26 12.00 -0.49 -11.99 268.00 11,672.88 88.41 339.53 6,668.81 6,192.97 5,877.13 12.00 -0.36 -12.00 268.00 11,872.88 86.92 315.55 6,677.06 6,360.36 5,770.68 12.00 -0.74 -11.99 266.00 12,122.88 88.34 285.56 6,687.65 6,485.86 5,558.02 12.00 0.56 -12.00 272.00 12,322.88 91.32 309.37 6,688.26 6,577.43 5,381.86 12.00 1.49 11.91 83.00 12,402.88 94.57 318.42 6,684.14 6,632.75 5,324.35 12.00 4.07 11.31 70.00 12,602.88 97.43 294.45 6,662.93 6,750.09 5,165.60 12.00 1.43 -11.98 278.00 12,752.88 97.06 276.31 6,643.86 6,789.38 5,022.75 12.00 -0.24 -12.09 270.00 12,870.00 96.85 262.15 6,629.61 6,787.83 4,906.80 12.00 -0.18 -12.09 270.00 • 2/25/2010 8 :55 :49AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Fri ConocoPhilhips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1Q - 03 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: - 1Q -03 © 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad North Reference: - True Well: 1 Q - 03 Survey Calculation Method: Minimum Curvature Wellbore: - 1Q Design: 1 Q 03A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +14/-S +EI W Section Rate Azimuth Northing Easting (ft) ( *) r (ft) (ft) (ft) (ft) (1100ft) (1 (ft) (0) 10,500.00 55.13 42.42 6,601.68 5,346.78 5,274.27 51.27 0.00 0.00 5,990,023.09 533,760.78 TIP 1 i , 10,555.00 55.70 42.56 6,632.90 5,380.17 5,304.86 53.26 1.06 11.47 5,990,056.59 533,791.24 KOP 10,570.00 57.05 42.56 6,641.21 5,389.37 5,313.31 53.79 9.00 0.00 5,990,065.82 533,799.65 End of DLS 9 10,600.00 66.05 42.56 6,655.48 5,408.78 5,331.13 54.91 30.00 0.00 5,990,085.30 533,817.40 1 10,630.00 75.05 42.56 6,665.46 5,429.60 5,350.24 56.11 30.00 0.00 5,990,106.18 533,836.431 4 1 10,682.88 90.00 47.92 6,672.33 5,466.36 5,387.38 55.85 30.00 20.00 5,990,143.08 533,873.42 End of DLS 30 1 10,700.00 90.13 49.98 6,672.31 5,477.61 5,400.29 54.67 12.00 86.50 5,990,154.38 533,886.29 10,800.00 90.85 61.95 6,671.46 5,533.47 5,483.01 35.68 12.00 86.50 5,990,210.55 533,968.78 10,892.88 91.49 73.08 6,669.55 5,568.93 5,568.67 0.18 12.00 86.60 5,990,246.33 534,054.30 6 10,900.00 91.49 72.23 6,669.37 5,571.05 5,575.47 -3.13 12.00 -90.00 5,990,248.48 534,061.09 10,992.88 91.46 61.08 6,666.97 5,607.78 5,660.58 -37.33 12.00 -90.02 5,990,285.53 534,146.05 7 1 11,000.00 91.43 60.22 6,666.79 5,611.27 5,666.79 -39.25 12.00 -92.00 5,990,289.05 534,152.25 11,100.00 90.98 48.23 6,664.69 5,669.61 5,747.75 -55.25 12.00 -92.02 5,990,347.69 534,232.98 ! 11,200.00 90.48 36.24 6,663.41 5,743.51 5,814.84 -50.44 12.00 -92.27 5,990,421.83 534,299.78 11,300.00 89.97 24.25 6,663.02 5,829.74 5,865.12 -25.01 12.00 -92.43 5,990,508.25 534,349.73 11,400.00 89.45 12.26 6,663.53 5,924.53 5,896.39 19.90 12.00 -92.47 5,990,603.15 534,380.63': 11,432.88 89.29 8.32 6,663.89 5,956.87 5,902.26 38.62 12.00 -92.41 5,990,635.50 534,386.38 i 8 11,500.00 89.02 0.27 6,664.89 6,023.75 5,907.28 82.36 12.00 -92.00 5,990,702.39 534,391.14 11,600.00 88.65 348.27 6,666.93 6,123.04 5,897.31 159.62 12.00 -91.88 5,990,801.64 534,380.80 11,672.88 88.41 339.53 6,668.81 6,192.97 5,877.13 223.33 12.00 -91.63 5,990,871.48 534,360.351 9 I 11,700.00 88.19 336.28 6,669.61 6,218.09 5,866.93 248.30 12.00 -94.00 5,990,896.56 534,350.06 11,800.00 87.42 324.29 6,673.46 6,304.72 5,817.49 344.52 12.00 -93.90 5,990,982.99 534,300.30 11,872.88 86.92 315.55 6,677.06 6,360.36 5,770.68 416.97 12.00 -93.44 5,991,038.44 534,253.27 1 10 1 11,900.00 87.04 312.29 6,678.49 6,379.14 5,751.17 444.04 12.00 -88.00 5,991,057.16 534,233.70 I 12,000.00 87.56 300.29 6,683.22 6,438.16 5,670.81 542.60 12.00 -87.83 5,991,115.86 534,153.12 ' 12,100.00 88.18 288.30 6,686.95 6,479.20 5,579.89 635.91 12.00 -87.26 5,991,156.55 534,062.06 12,122.88 88.34 285.56 6,687.65 6,485.86 5,558.02 656.08 12.00 -86.81 5,991,163.12 534,040.16 11 12,200.00 89.48 294.74 6,689.12 6,512.39 5,485.71 725.97 12.00 83.00 5,991,189.38 533,967.76 12,300.00 90.98 306.65 6,688.72 6,563.35 5,399.88 822.70 12.00 82.82 5,991,240.00 533,881.74 1 12,322.88 91.32 309.37 6,688.26 6,577.43 5,381.86 845.40 12.00 82.87 5,991,254.01 533,863.67 12 12,400.00 94.46 318.09 6,684.37 6,630.62 5,326.26 922.32 12.00 70.00 5,991,306.98 533,807.88 12,402.88 94.57 318.42 6,684.14 6,632.75 5,324.35 925.18 12.00 70.44 5,991,309.11 533,805.96 13 12,500.00 96.09 306.81 6,675.08 6,698.13 5,253.32 1,021.63 12.00 -82.00 5,991,374.21 533,734.69 12,600.00 97.39 294.80 6,663.30 6,748.90 5,168.19 1,117.73 12.00 -83.08 5,991,424.65 533,649.38 12,602.88 97.43 294.45 6,662.93 6,750.09 5,165.60 1,120.40 12.00 -84.50 5,991,425.83 533,646.78 14 12,700.00 97.27 282.70 6,650.47 6,780.72 5,074.46 1,206.51 12.00 -90.00 5,991,456.11 533,555.53 12,752.88 97.06 276.31 6,643.86 6,789.38 5,022.75 1,249.20 12.00 -91.51 5,991,464.58 533,503.791 15 i 2/25/2010 8:55:49AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips rug • ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1Q - 03 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1Q -03 © 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad North Reference: True Well: 1Q Survey Calculation Method: - Minimum Curvature Wellbore: 1Q Design: 1Q -03A wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/ -W Section Rate Azimuth Northing Easting (ft) (°) ( *) (ft) (ft) (ft) (ft) 0100ft) (°) (ft) (ft) 12,800.00 97.03 270.61 6,638.08 6,792.21 4,976.08 1,284.19 12.00 -90.00 5,991,467.22 533,457.12 12,870.00 ' 96.85 262.15 6,629.61 , 6,787.83 4,906.80 1,330.09 12.00 -90.70 5,991,462.58 533,387.86 TD Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +WS +E/ -W Northing Easting Shape (°) ( (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1Q -03A t3 0.00 0.00 6,664.00 5,954.61 5,907.32 5,990,633.26 534,391.45 70° 23' 7.536 N 149° 43' 13.092 W - plan misses target center by 5.35ft at 11431.55ft MD (6663.87 TVD, 5955.57 N, 5902.06 E) - Point 1Q -03A t6 0.00 0.00 6,630.00 6,805.46 4,920.47 5,991,480.26 533,401.46 70° 23' 15.911 N 149° 43' 41.966 W - plan misses target center by 15.95ft at 12855.30ft MD (6631.37 TVD, 6789.60 N, 4921.29 E) i - Point ! 1Q -03A, AL1 Polygon 0.00 0.00 0.00 5,484.78 5,068.44 5,990,160.28 533,554.44 70° 23' 2.921 N 149° 43' 37.660 W - plan misses target center by 6606.33ft at 10500.00ft MD (6601.68 TVD, 5346.78 N, 5274.27 E) - Polygon Point 1 0.00 5,484.78 5,068.44 5,990,160.28 533,554.44 Point 2 0.00 5,314.58 5,381.83 5,989,991.30 533,868.45 Point 3 0.00 5,441.68 5,627.34 5,990,119.32 534,113.45 Point 4 0.00 5,635.56 5,930.10 5,990,314.33 534,415.44 Point 5 0.00 5,950.05 6,073.29 5,990,629.33 534,557.41 Point 6 0.00 6,302.25 6,030.61 5,990,981.33 534,513.40 Point 7 0.00 6,500.93 5,855.34 5,991,179.32 534,337.39 Point 8 0.00 6,986.32 4,700.04 5,991,660.26 533,180.36 Point 9 0.00 6,756.60 4,620.17 5,991,430.26 533,101.38 Point 10 0.00 6,426.96 5,314.01 5,991,103.30 533,796.40 Point 11 0.00 6,221.37 5,731.28 5,990,899.32 534,214.41 Point 12 0.00 5,957.19 5,771.29 5,990,635.32 534,255.42 Point 13 0.00 5,744.01 5,547.46 5,990,421.31 534,032.42 Point 14 0.00 5,487.79 5,065.45 5,990,163.28 533,551.44 1Q-03A t4 0.00 0.00 6,677.00 6,373.08 5,792.91 5,991,051.26 534,275.46 70° 23' 11.653 N 149° 43' 16.432 W - plan misses target center by 24.88ft at 11868.30ft MD (6676.82 TVD, 6357.08 N, 5773.86 E) - Point 1Q -03A KOP 0.00 0.00 6,638.00 5,426.06 5,253.23 5,990,102.28 533,739.44 70° 23' 2.343 N 149° 43' 32.252 W - plan misses target center by 69.24ft at 10556.89ft MD (6633.97 TVD, 5381.33 N, 5305.92 E) - Point 1Q-03A t1 0.00 0.00 6,672.00 5,503.77 5,332.54 5,990,180.28 533,818.44 70° 23' 3.106 N 149° 43' 29.929 W - plan misses target center by 64.72ft at 10670.24ft MD (6671.93 TVD, 5457.80 N, 5378.10 E) - Point 1Q -03A t5 0.00 0.00 6,688.00 6,560.53 5,418.58 5,991,237.26 533,900.46 70° 23' 13.499 N 149° 43' 27.387 W - plan misses target center by 8.69ft at 12282.45ft MD (6688.98 TVD, 6553.13 N, 5414.15 E) - Point ! 1Q-03A t2 0.00 0.00 6,667.00 5,615.62 5,635.00 5,990,293.27 534,120.45 70° 23' 4.204 N 149° 43' 21.072 W - plan misses target center by 18.89ft at 10972.47ft MD (6667.49 TVD, 5598.30 N, 5642.52 E) - Point 2/25/2010 8:55:49AM Page 4 COMPASS 2003.16 Build 69 ' ConocoPhillips ream ConocoPh[dhtps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1Q - 03 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: - 1Q-03 @ 90.00ft (Nordic 1) Site: Kuparuk 1Q Pad North Reference: True Well: 1Q Survey Calculation Method: Minimum Curvature Wellbore: 1Q Design: 1Q 03A_wp03 Casing Points Measured Vertical - = Casing - Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (1 , 5,224.00 3,545.57 9 5/8" 9 -5/8 12 -1/4 12,870.00 6,629.19 2 -3/8" 2 -3/8 3 Plan Annotations Measured Vertical Local Coordinates j Depth Depth 01/4 +E/-W 1 00 , (ft) (ft) " (ft) Comment 10,500.00 6,601.68 5,346.78 5,274.27 TIP 10,555.00 6,632.90 5,380.17 5,304.86 KOP 10,570.00 6,641.21 5,389.37 5,313.31 End of DLS 9 10,630.00 6,665.46 5,429.60 5,350.24 4 10,682.88 6,672.33 5,466.36 5,387.38 End of DLS 30 10,892.88 6,669.55 5,568.93 5,568.67 6 10,992.88 6,666.97 5,607.78 5,660.58 7 11,432.88 6,663.89 5,956.87 5,902.26 8 11,672.88 6,668.81 6,192.97 5,877.13 9 11,872.88 6,677.06 6,360.36 5,770.68 10 12,122.88 6,687.65 6,485.86 5,558.02 11 12,322.88 6,688.26 6,577.43 5,381.86 12 12,402.88 6,684.14 6,632.75 5,324.35 13 12,602.88 6,662.93 6,750.09 5,165.60 14 12,752.88 6,643.86 6,789.38 5,022.75 15 12,870.00 6,629.61 6,787.83 4,906.80 TD 2/25/2010 8:55:49AM Page 5 COMPASS 2003.16 Build 69 Project: Kuparuk River Unit Ma gireh utne c to Nadh 21. True Nod^ 72° WELLBORE DETAILS: 1Q-03A REFERENCE INFORMATION - Site: Kuparuk 10 Pad Magnetic Field Parent Wellbore: 1 Q -03 Co-ordinate (N/E) Reference: Well 10 -03. True North W ell: 1 Q -03 S trength 57601.1snT V e rtica l ( TVO ) R e f erence: Me Sea Level K BAR `�^'` Ti on MD 10500 K /+� ,prte� { Wellbore: 1Q-03A Model BM 62.67 Section (VS) Reference: Slot- (0.00N, 0.00E) Measured Depth ©nocoPhilh P Ian:1Q -03A W 03 1Q -0311Q - 03A Dare WV2 0 Depth Reference: 10-03 @90.00tt (Nor8 1) _p ( f Angle. Calculation Method: Minimum Curvature HUGHES 7200 - WELL DETAILS: 10-03 ' 7050 - Ground Level: 47.50 IQ- 03 /IQ -03A +NI -S +61 -W Northing Easting Latittude Longitude Slot 4? 0.00 0.00 5984656.79 528507.43 70° 22' 8.996 N 149° 46' 6.028 W 6900 ' °' TD 15 "4RO�rR mo -- _- - __- _ 14 a aN SECTION DETAILS ANNOTATIONS 6750 i 1 Sec MD Inc Azi TVDSS +NI -S +E / -W DLeg TFace VSec Target Annotation ` 12 1 10500.00 55.13 42.42 6601.68 5346.78 5274.27 0.00 0.00 51.27 TIP 6600 - 2 10555.00 55.70 42.56 6632.90 5380.17 5304.86 1.06 11.47 53.26 KOP 11 3 10570.00 57.05 42.56 6641.21 5389.37 5313.31 9.00 0.00 53.79 End of DLS 9 Q6450- 4 10630.00 75.05 42.56 6665.46 5429.60 5350.24 30.00 0.00 56.11 4 1 5 10682.88 90.00 47.92 6672.33 5466.36 5387.38 30.00 20.00 55.85 End of DLS 30 + 6 10892.88 91.49 73.08 6669.55 5568.93 5568.67 12.00 86.50 0.18 6 ©6300 ' 7 10992.86 91.46 61.08 6666.97 5607.78 5660.58 12.00 270.00 -37.33 7 --. 8 11432.88 89.29 8.32 6663.89 5956.87 5902.26 12.00 268.00 38.62 8 . - 61 9 - ' • 9 11672.88 88.41 339.53 6668,81 6192.97 5877.13 12.00 268,00 223.33 9 +, 10 11872.88 86.92 315.55 6677.06 6360.36 5770.68 12.00 266.00 416.97 10 .4 11 12122.88 88.34 285.56 6687.65 6485.86 5558.02 12.00 272.00 656.08 11 06000 0 12 12322.88 91.32 309.37 668826 6577.43 5381.86 12.00 83.00 845.40 12 13 12402.88 94.57 318.42 6684.14 6632.75 5324.35 12.00 70.00 925.18 13 '5850 . 14 12602.88 97.43 294.45 6662.93 6750.09 5165.60 12.00 278.00 1120.40 14 15 12752.88 97.06 276.31 6643.86 6789.38 5022.75 12.00 270.00 1249.20 15 X 5700 16 12870.00 96.85 262.15 6629.61 6787.83 4906.80 12.00 270.00 1330.09 TD p t Q - 03/ I Q - 03 - _ C 0 • ---- -- - - -- - - - - - -- -- -- --- 7 5550- - - - - 6 + 5400- - 4 End of DLS 30 5250 - End of DLS 9 , KOP 5100 -: TIP 4050 4200 4350 4500 4650 4800 4950 5100 5250 5400 5550 5700 5850 6000 6150 6300 6450 6600 6750 West( -) /East( +) (150 ft/in) 6480 - - 6520 ' 6560 TIP 7~ . . , • 6600 KOP ' O End of DLS 9 - TD 6640- - - '9 C1. "� ' y m 6680 + ' 1 5 • c y 6720 6 9 70 1 12 13 . 1Q- 03/1Q -03A t9 6760 End of DLS 30 l ' 6840- - 1Q- 113 /IQ -03 6880 ' 6920 - • -120 -R0 -40 0 T 40 80 120 1 6 0 200 240 2R0 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 1160 1200 1240 1280 1320 1360 1400 Vertical Section at 315.00° (40 ft/in) a401465m7reawdn WELLBORE DETAILS: 1Q-03A REFERENCE INFORMATION °"' Project: Kuparuk River Unit Magnetic NoM:21.7? Site: Kuparuk1Q Pad Mtgrehc Feld Parent Wellbofe: 10-03 Co -ordinate (NIE) Reference: We1110 -03, True North r Well: 1Q -03 S beig, 07e61.1an1 T ie on MD: 10500.00 Vertical (TVD) Reference. 10 -03 @ 9 ODIC (Nord 1) ��ER Conoco Phillips Weilbore: 1Q-03A apAg 97 Angle Section (VS)Reference: Sot- (040N,0.00E) din Plan: 1Q - 03A wp03(1Q - 03A) gpG Measured Depth Reference: 10 -03 @90.00 t(Nordic 1) fey Calculation Method' Minimum Curvature HUGHES 8800] 8600 - . 8400- -- . 8200 ' 8000- 7800 ' ' • 7600 / 7400- - . 7200- . 7000 ,r' IQ - 61 /IQ -03AL1 IQ-2110-2J • ' a 7 1 6800 c*� - . - ' ' „ 6600 '''''',0 ,`� \\ 0 C '' 6400 IQ- 03 /10.(13A + ±..6200 � \ ' p 6000 5800- I9- 03'10 -03 / 5600 10- 111/10 -01 / > z - - • 5400 - „op / • 5200- -- - --- -, ''6 ' 5000 - /,,' / . \ ^6770 4800 IQ 02/I - 02: I \ ' . a6on / _ . a400- 4200- • / E, c�- ' oznQ.ozB 4000 IQ- IUnQ16 w_ 10-22 _ - 1 3800 1' I 7014 r I 3600- ' f // - . / - - - - - - . - - 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 10-03 @ 90.00ft (Nordic 1) West( -) /East( +) (200 ft /in) • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing ❑ a Lubricator Riser 7 \ Annular/) Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator � above BHA rams t ..--- - -,1- � - I ❑ \ L i Choke 1 i 2-3/8" Pipe / Slip (BHA) i Choke Equalize - Manifold - 2 -3/8" Pipe / Slip (BHA) j L. Kill ►>T< j .�� ; ;J Blind / Shear 2" Pipe / Slip (CT) - 1 r' Choke 2 - I Swab Valves \ Wing Valves II Tree Flow Cross • , Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi Master Valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union • TRANSMITTAL LETTER CHECKLIST WELL NAME ,' �-�'C / / -3/4 PTD# 2_,/ 'G _60 /Development Service Exploratory Strati ra hic Test P P rY g P Non- Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter 1 CHECK ADD -ONS TEXT FOR APPROVAL LETTER WHAT l (OPTIONS) APPLIES 1 i MULTI LATERAL ! The permit is for a new wellbore segment of existing I I well ([f last two digits in I Permit No. , APE No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(t), 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 I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non- Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the l i Commission to obtain advance approval of such water well testing I ; program. Rev. 1'25/06 C 'Jody'transmittal_checklist L . . :,effE ` Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 _ Well Name: KUPARUK RIV UNIT 1Q -03A Program DEV Well bore seg ❑ PTD#: 2100260 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type DEV / PEND GeoArea 890 Unit 11160 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Top prod interval and TD in ADL 25634. 1 3 Unique well name and number Yes 1 4 Well located in a defined pool Yes 1 5 Well located proper distance from drilling unit boundary Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 16 Well located proper distance from other wells Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 7 Sufficient acreage available in drilling unit Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 3 miles I8 If deviated, is wellbore plat included Yes from an external property line where ownership or landownership changes. I9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 3/9/2010 13 Can permit be approved before 15 -day wait Yes '14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in 1Q -03 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 1Q -03 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 1Q -03 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set 22 CMT will cover all known productive horizons No OH slotted liner planned 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes _ Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 310 -065 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues. 27 If diverter required, does it meet regulations NA Wellhead in place. Will place BOP stack on top of tree. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation press= 2517 psi ( 7.4 ppg) Will drill with 8.9 ppg mud and utilize MPD techniques . GLS 3/11/2010 29 BOPEs,do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 1863 psi... Will test BOP to 3000 psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S reported on 10 pad .. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No KRU 1Q -03 measured 100 ppm H2S on 8/6/2009; measures required. Geology 36 Data presented on potential overpressure zones Yes The most recent BH pressure in KRU 1Q -03 measured 7.4 ppg EMW; this wellbore will be Appr Date 1 37 Seismic analysis of shallow gas zones NA drilled using coiled tubing and 8.9 ppg with Managed Pressure Drilling Techniques to maintain SFD 3/9/2010 38 Seabed condition survey (if off- shore) NA downhole pressure of 11.8 ppg ECD to ensure formation stability. 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering . lic Commissioner: Date: Commissioner: Date r . ' loner Date 041,61-/-1,-- 3 — 1S - /O /
