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Home My WebLink About210-027 • li k Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable i direct inspection of the file. _o O� Well History File Identifier _. Organizing (done) ❑ Two -sided III tIIiII 1111 ❑ Rescan Needed 1 111111 IlIJl ; SCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑Diskettes, No. ❑Maps: xi reyscale Items: ❑Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: \ ' Nei OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: • op /s/ f) Project Proofing I 1111111 11111 BY: Alg, Date: d� /s/ \V Scanning Preparation / x 30 = 30 + I. q = TOTAL PAGES 1 -1--- 9 (Count does not include cover sheet) BY: AAS2P Date: 1 / /s/ Production Scanning IIIIIIIIIII I Stage 1 Page Count from Scanned File: 50 (Count does include cov sheet) Page Count Matches Number in Scan in Preparation: YES NO BY: Maria Date: / 9 ID., /s/ j14 f Sta 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1 H11111111 1111 ReScanned 1111111111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111111111111 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10/25/2011 Permit to Drill 2100270 Well Name /No. KUPARUK RIV UNIT 1Q -03AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21249 -60 -00 MD 12999 TVD 6783 Completion Date 5/15/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey (Yga DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint 0 I Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / 1 Tye Med /Frmt Number dame Scale Media No Start Stop CH Received Comments C Lis 19877 Induction /Resistivity 9728 12999 Open 7/15/2010 OH LIS EWR logs PDS, // CGM, and TIFF graphics Log Induction /Resistivity 2 Col 10299 12999 Open 7/15/2010 MD MPR, GR Lo Induction /Resistivity 5 Col 10299 12999 Open 7/15/2010 MD MPR, GR Lo . Induction /Resistivity 5 Col 10299 12999 Open 7/15/2010 TVD MPR, GR D C Directional Survey 11491 12999 Open pt Directional Survey 11491 12999 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments III ADDITIONAL INFORMATION Well Cored? Y /` {b Daily History Received? IP Chips Received? 'f`7 Formation Tops 0 N Analysis - Y-1-14, Received? Comments: Compliance Reviewed By: \ _ Date: oq- I 1 J— ECE1V 117) FR . __ _ Company ConocoPhillips, Alaska, Inc. - _, ... t ofi /4jtict.- 1cv,144°.1cljotrintivsitif BAKER Well Name 10-03AL1 HUGHES Date 7/13/2010 11'4i TE Q Conoc ,;: .; , i Distribution , OH FINAL OH FINAL , ..„•,,' . .,,,,,, , ,,,...,. , f; , , , , ..„ . , , ..; ,,, .,1 , ,.. I ., Alaska Greater Kuparuk Area*** Data , 1 . , ` • .. ,, ' ''' No other distribution is allowed without .,, , : ,' c ' .., 1 ,,, .,' )., , V . 'RECIPIENTS t written approval from ConocoPhillips i t . Im Digital Data I 1'l-' ''''''''''''''' '):: '''' ''''''''' contact: Lisa Wri • ht, 907 263-4823 • ; , ConocoPhillips Alaska, Inc. . .. ' !. 1 ' 1;trIZsitl , „ kr,,,:•1', e 4 VVP , ;°' ;'''' • Sharon Allsup-Drake Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. +„ . 1 Hardcopy Print ! , 1, '', NSK Wells Aide, NSK 69 ? ATTN: MAIL ROOM 1 700 G Street, Anchorage, AK 99501 1 ; ' ' ConocoPhillips Alaska, Inc Ricky Elgarico . ! 1 Graphic Image 1 Disk"/ ' + + . i l'. File/ **" Electronic 00-G Street, I ' • 1 • ' ■ • ;7 CGM / TIFF LIS 7 And4orage,A1<-9904 + , .. , 1 , ftp://b2bftp.conocophillips.cbm **** ; , AOGCC a P 1 Hardcopy y Piint ' Christine Mahnken 1 Graphic image file 1 Disk 333 West 7th Ave, Suite 100 '.' in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS 1 Hardcopy Print, , BP Petrotechnical Data Center, MB33 1 Graphic image file 1 Dis k/ , . * ' ' David Douglas i ,--,, i' , 48 in lieu of sepia** Electronic , ,[+, ' . +++:++.-,,..., , P.O. Box 196612 : CGM / TIFF LIS Anchorage, Alaska 99519-6612 i , 1 + 1 Hardcopy Print, CHEVRON/KRU REP Glenn Fredrick . I Graphic i mage file 1 Disk*/ , P.O.Box 196247 CGM / TIFF I ''' ° ''' )' : ., I .,- ,: : in lieu of sepia** Electronic , , + ,., . A Anchorage, Alaska 99519 LIS ' + , , ,, , i. +,, +ci , Brandon Tucker, NRT + State of Alaska; DNR, Div. of Oil and Gas + 1 Disk*/ . 550 W. 7th Ave, Suite 800 Electronic +. i,. Anchorage, Alaska 99501-3510 LIS . DS Engineer / Rig Foreman - TOTAL ' . . Hardcopy Prints 4 Page 1 of 4 + 1 /d --61_7 Maunder, Thomas E (DOA) From: Eller, J Gary [J.Gary.Eller(cjlconoo ophallips:com] Sent: Monday, July 12, 201010:43 Alit To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay; Gantt, Lamar L; Ven1aaus, Dan E; Nabors CDR2 Company Man; Ohlinger, James J; Long, Jill W Subject RE: 10-03A (210-026) Tom In answer to your questions on the IQ-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 1. 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) [mailto:tom.maunder@alaska.gov) Sent: Friday, July 02, 2010 3 :03 PM To: E11er, J 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. 1 have reviewed the completion report recently submitted and have a couple of questions. t During operations late on April 23, it is stated "...check for BPV__.' Was a BPV in the welt? [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 4124, 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 -315' 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? Mat 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 an 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 free 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 r 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: 011 Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG LI WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 15, 2010 210 - 0270 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 11, 2010 50 029 - 21249 - 60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1216' FNL, 1116' FEL, Sec. 26, T12N, R9E, UM May 14, 2010 1Q - 03AL1 Top of Productive Horizon: 8. KB (ft above MSL): 90' RKB 15. Field /Pool(s): 535' FNL, 384' FEL, Sec. 24, T12N, R9E, UM GL (ft above MSL): 47.5' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 287' FSL, 1388' FEL, Sec. 13, T12N, R9E, UM 12999' MD / 6783' 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 12999' MD / 6783' TVD ADL 25634 TPI: x - 534491 y - 5990643 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x - 533483 y 5991460 Zone 4 1763' MD / 1681' TVD 2567 18. Directional Survey: Yes El 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 _11649' MD / 6736' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 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 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 10272' 12999' 6561' 6783' 3" slotted liner 24. Open to production or injection? Yes Q 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 10272'- 12999' MD 6561' -6783' TVD 10348' MD / 6598' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETION DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1. .iiii 1 t , . none 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 El 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 EE ` ' NONE ,E,N 1 1 ?OW ;woke Chi & Gat C0n3. Commission Anchorage Form 10 -407 Revised 12/2009 RBDMS JUN 11 ,11 ! ∎ ONTINUED ON REVERSE Submit original only RBDMS , t , 09 r,07 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Ei 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 (invert) 11860' 6723' Kuparuk A5 (invert) 12030' 6720' Kuparuk A4 12055' 6721.5' Kuparuk A5 12273' 6738' Kuparuk A4 12302' 6741' Kuparuk A3 12385' 6750' N/A Formation at total depth: Kuparuk A3 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(011011 Printed Na V. wv Title: Alaska Wells Manager // / 0 Signature s rT A f6 r Phone 265 - 6306 Date C1 / / // 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 la: 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 • • 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 @ 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. Out MM bypassed. 11:39 11:51 0.20 11,651 11,651 PROD2 STK KOST P Increase ROP 2 FPH 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. 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 @ 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 tag @ 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 @ 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 11 K, 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 latching 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 1 652 PROD2 STK TRIP T Tag TOB 11652.13'. 2.4K WOB 06:15 06:45 0.50 11,652 11,652 g , 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 Tag, PU string weight. 28K, Online with pumps setting OH anchor, 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 1 1 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 @ 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 . I 1 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 loss 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 1 • 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 @ 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 • 1 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 CASING SFTY 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.Blew 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 CASING SFTY 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 RIGMNT 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 pipe. 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 1Q -03A and 1Q -03AL1 Final CTD Schematics 3 -112" 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 I 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 3 -1/2" Camco MMG -2 gas lift mandrel @ 9949.6' 9 -5/8" 36# J -55 Baker 3 -1/2" PBR 0 9993.3" RKB (3.0" ID) shoe 0 5224' MD E Baker FHL packer 0 10007.8' RKB (3.0" ID) I;1 — 3 -1/2" Camco MMG -2 production mandrels @ 10044.8', 10114.6' RKB Holes 0 10290' and 10298' RKB (9 -8 -09 caliper) s. Tubing perfs 0 10299 - 10309' (C -sand squeeze) • C -sand perfs (sqz prior to - - e'= ,, - .�- -__ 3 -1/2" Camco MMG -2 production mandrel 0 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 0 10,387.4' RKB (2.75" min ID, No -Go) Perf holes 1 `s' \ 3 -1/2" tubing tail 0 10,421' RKB 10,295'- 10,305' RKB ‘\\\\`\ 3 -1/2" Monobore whipstock ‘ A TOWS @ 10,299.3' MD G >. . °�=.• �=� -r- \ v =� \\ 1Q -03AL1 is *ry Fa. \`\ (A3/A4 sand, wp11) FISH (from pre wellwork) ■ \ ` � Kickoff from 1Q - 03A @ 11512' 27' of Slickline tools \�\ TD @ 13000' (top 0 10,347') \ Deployment Sleeve @ 10273'- 10274' Catcher Sub above D - nipple \\ \ Slotted liner from 10274'- 12999' CA -2 Plug w/ gauges in D- nipple \;. . , (10,387.4 RKB) `sss` � 10-03A r (A3 sand, wp05) A - sand perfs `� — Kickoff from 1Q -03 @ 10299.3' • 10556' - 10742' MD TD @ 12565' Anchored billet @ 11512'- 11523' 17" 26# J - shoe © Slotted liner from 11523'- 11652' 110910' RKB Anchored billet @ 11650' - 11663' __ Rig Release: 5/15/2010 Rig Accept: 45/2010 Last update 5118/2010 Slotted liner from 11663' 12487' it ' r ✓ Conoc�Phillip Alaska • II I ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1Q Pad 1 Q -03AL1 50- 029 - 21249 -60 Baker Hughes INTEQ Fak1 Definitive Survey Report BKER HUGHES 17 May, 2010 ConocoPhillips RIO ConocoPhillips Definitive Survey Report BAKER Alaska 1 Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1Q _ I Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) Site: Kuparuk 10 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 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 Well 1Q-03 - � -- —� Well Position +N/ 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 Wellbore 1Q - 03AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 ( °) (nT) BGGM2009 5/1/2010 17.21 79.83 57,377 Design 1Q 03AL1 — � — Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,491.51 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction III (ft) (ft) (ft) (0) 42.50 0.00 0.00 36.40 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 10,299.00 11,491.51 1Q-03A (1Q-03A) MWD MWD - Standard 4/29/2010 5/3/2010 11,512.00 12,955.44 1Q -03AL1 (1Q- 03AL1) MWD MWD - Standard 5/11/2010 5/14/2010 5/17/2010 11:52:38AM Page 2 COMPASS 2003.16 Build 69 --° ConocoPhillips Nig ConocoPhillips Definitive Survey Report BAKER its Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1Q - 03 I Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) Site: Kuparuk 10 Pad MD Reference: 1Q -03 @ 90.00ft (Nordic 1) Well: 1Q North Reference: TRUE Wellbore: 10 Survey Calculation Method: Minimum Curvature Design: 10 Database: EDM Alaska Prod v16 ' r _ __ Survey MD Inc Az! TVD TVDSS +NI-S +El W Map Map DLS Vertical Northing Easting Section Survey Tool Name Annotation (ft) (1 ( °) (ft) (ft) (ft) (ft) (ft) (ft) (1100) (ft) • 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 8,344.83 MWD (2) TIP 1Q -03A 11,512.00 90.37 17.68 6,737.25 6,647.25 5,963.70 6,006.27 5,990,642.73 534,490.36 11.11 8,364.31 MWD (3) KOP 11,540.42 90.40 13.53 6,737.06 6,647.06 5,991.07 6,013.92 5,990,670.12 534,497.89 14.60 8,390.87 MWD (3) Interpolated AZI 11,570.40 90.31 9.15 6,736.87 6,646.87 6,020.45 6,019.81 5,990,699.53 534,503.68 14.61 8,418.03 MWD (3) Interpolated AZI 11,600.45 90.58 4.76 6,736.64 6,646.64 6,050.28 6,023.45 5,990,729.36 534,507.20 14.64 8,444.19 MWD (3) 11,640.38 91.04 1.90 6,736.08 6,646.08 6,090.13 6,025.77 5,990,769.22 534,509.37 7.25 8,477.64 MWD (3) 11,660.46 90.86 356.80 6,735.74 6,645.74 6,110.20 6,025.54 5,990,789.28 534,509.06 25.41 8,493.66 MWD (3) 11,690.47 90.89 354.37 6,735.28 6,645.28 6,140.11 6,023.23 5,990,819.19 534,506.64 8.10 8,516.37 MWD (3) 11,720.45 93.04 349.70 6,734.26 6,644.26 6,169.78 6,019.08 5,990,848.83 534,502.38 17.14 8,537.79 MWD (3) 11,750.45 94.64 345.93 6,732.25 6,642.25 6,199.03 6,012.76 5,990,878.06 534,495.95 13.63 8,557.58 MWD (3) 11,780.37 94.92 341.64 6,729.75 6,639.75 6,227.65 6,004.44 5,990,906.65 534,487.52 14.32 8,575.68 MWD (3),, 11,810.39 95.23 337.67 6,727.10 6,637.10 6,255.68 5,994.05 5,990,934.63 534,477.02 13.21 8,592.08 MWD (3) 11,840.44 95.10 333.55 6,724.39 6,634.39 6,282.94 5,981.69 5,990,961.84 534,464.56 13.66 8,606.68 MWD (3) 11,870.39 93.63 328.99 6,722.11 6,632.11 6,309.11 5,967.34 5,990,987.96 534,450.11 15.95 8,619.24 MWD (3) 11,900.04 93.01 326.47 6,720.39 6,630.39 6,334.14 5,951.54 5,991,012.92 534,434.21 8.74 8,630.01 MWD (3) 11,930.48 91.01 322.36 6,719.32 6,629.32 6,358.87 5,933.84 5,991,037.58 534,416.42 15.01 8,639.41 MWD (3) 11,960.38 89.35 318.31 6,719.23 6,629.23 6,381.88 5,914.76 5,991,060.52 534,397.26 14.64 8,646.61 MWD (3) 11,990.32 90.21 314.61 6,719.34 6,629.34 6,403.58 5,894.14 5,991,082.14 534,376.56 12.69 8,651.84 MWD (3) • 12,020.25 87.76 310.55 6,719.87 6,629.87 6,423.83 5,872.11 5,991,102.29 534,354.45 15.84 8,655.07 MWD (3) 12,050.22 85.91 307.02 6,721.53 6,631.53 6,442.57 5,848.79 5,991,120.94 534,331.06 13.28 8,656.31 MWD (3) 12,080.30 86.04 302.84 6,723.64 6,633.64 6,459.74 5,824.19 5,991,138.03 534,306.41 13.87 8,655.55 MWD (3) 12,110.35 86.68 298.39 6,725.55 6,635.55 6,475.01 5,798.39 5,991,153.19 534,280.55 14.93 8,652.53 MWD (3) 12,140.42 86.53 294.07 6,727.33 6,637.33 6,488.28 5,771.47 5,991,166.35 534,253.58 14.35 8,647.23 MWD (3) 12,170.38 84.12 289.42 6,729.77 6,639.78 6,499.34 5,743.75 5,991,177.31 534,225.82 17.43 8,639.68 MWD (3) 12,200.30 84.49 285.28 6,732.75 6,642.75 6,508.21 5,715.33 5,991,186.07 534,197.37 13.82 8,629.97 MWD (3) 12,230.37 85.32 281.62 6,735.42 6,645.42 6,515.18 5,686.21 5,991,192.93 534,168.23 12.43 8,618.29 MWD (3) 12,260.28 86.99 277.29 6,737.42 6,647.42 6,520.08 5,656.78 5,991,197.71 534,138.78 15.49 8,604.77 MWD (3) 12,280.38 86.44 275.14 6,738.58 6,648.58 6,522.25 5,636.83 5,991,199.81 534,118.83 11.02 8,594.68 MWD (3) 12,310.28 84.03 272.02 6,741.06 6,651.06 6,524.11 5,607.10 5,991,201.56 534,089.09 13.16 8,578.54 MWD (3) 12,340.39 83.69 268.62 6,744.28 6,654.28 6,524.28 5,577.17 5,991,201.61 534,059.16 11.28 8,560.91 MWD (3) 5/17/2010 11:52:38AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Waal Conoco Phillips Definitive Survey Report JJES Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference; 1Q - 03 } Project: Kuparuk River Unit TVD Reference: 1Q -03 @ 90.00ft (Nordic 1) i Site: Kuparuk 10 Pad MD Reference: 1Q -03 @ 90.00ft (Nordic 1) Well: 1Q - 03 North Reference: TRUE Wellbore: 1Q Survey Calculation Method: Minimum Curvature Design: 1Q Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI.W DLS Survey Tool Name Annotation • (ft) Cl (1 (ft) (ft) (ft) (ft) Northing g Easting ( °1100') Section 12,370.37 81.27 262.97 6,748.21 6,658.21 6,522.10 5,547.54 5,991,199.33 534,029.55 20.35 8,541.58 MWD (3) 12,400.18 82.36 266.61 6,752.45 6,662.45 6,519.43 5,518.16 5,991,196.54 534,000.18 12.63 8,522.00 MWD (3) 12,430.26 84.18 271.40 6,755.98 6,665.98 6,518.91 5,488.30 5,991,195.91 533,970.33 16.93 8,503.86 MWD (3) 12,460.62 84.31 275.92 6,759.03 6,669.03 6,520.84 5,458.17 5,991,197.72 533,940.19 14.82 8,487.53 MWD (3) 12,490.43 85.20 281.00 6,761.75 6,671.75 6,525.21 5,428.81 5,991,201.97 533,910.82 17.23 8,473.63 MWD (3) 12,520.16 84.89 285.21 6,764.32 6,674.32 6,531.92 5,399.97 5,991,208.58 533,881.96 14.15 8,461.92 MWD (3) 12,550.39 85.35 291.13 6,766.90 6,676.90 6,541.31 5,371.37 5,991,217.86 533,853.32 19.57 8,452.50 MWD (3) 12,581.40 86.71 296.33 6,769.04 6,679.04 6,553.75 5,343.06 5,991,230.19 533,824.96 17.29 8,445.73 MWD (3) 12,611.05 86.86 301.17 6,770.71 6,680.71 6,567.99 5,317.11 5,991,244.33 533,798.97 16.31 8,441.79 MWD (3) 12,640.43 88.09 307.79 6,772.00 6,682.00 6,584.60 5,292.93 5,991,260.84 533,774.73 22.90 8,440.81 MWD (3) 12,670.24 86.68 312.52 6,773.36 6,683.36 6,603.79 5,270.18 5,991,279.95 533,751.90 16.54 8,442.76 MWD (3) 12,700.40 86.47 317.77 6,775.17 6,685.17 6,625.13 5,248.95 5,991,301.20 533,730.60 17.39 8,447.33 MWD (3) 12,730.47 83.63 315.64 6,777.76 6,687.76 6,646.93 5,228.41 5,991,322.92 533,709.98 11.79 8,452.70 MWD (3) 12,760.74 87.01 312.86 6,780.23 6,690.23 6,667.97 5,206.81 5,991,343.88 533,688.29 14.44 8,456.81 MWD (3) 12,790.57 90.28 310.04 6,780.94 6,690.94 6,687.71 5,184.46 5,991,363.53 533,665.87 14.47 8,459.44 MWD (3) 12,820.35 91.20 307.04 6,780.55 6,690.55 6,706.26 5,161.17 5,991,381.99 533,642.51 10.54 8,460.55 MWD (3) 12,850.34 88.90 303.42 6,780.53 6,690.53 6,723.56 5,136.68 5,991,399.19 533,617.96 14.30 8,459.94 MWD (3) 12,880.26 90.25 299.68 6,780.75 6,690.75 6,739.21 5,111.19 5,991,414.75 533,592.41 13.29 8,457.42 MWD (3) • 12,910.42 88.56 295.69 6,781.06 6,691.06 6,753.22 5,084.49 5,991,428.65 533,565.66 14.37 8,452.85 MWD (3) 12,940.38 88.59 291.70 6,781.81 6,691.81 6,765.25 5,057.07 5,991,440.58 533,538.20 13.31 8,446.27 MWD (3) 12,955.44 89.17 289.82 6,782.10 6,692.10 6,770.59 5,042.99 5,991,445.86 533,524.10 13.06 8,442.21 MWD (3) ff 12,999.00 89.17 289.82 6,782.73 6,692.73 6,785.36 5,002.01 5,991,460.47 533,483.07 0.00 8,429.78 PROJECTED to TD 5/17/2010 11:52:38AM Page 4 COMPASS 2003.16 Build 69 .-- KUP • 1 Q -03ALI ConocoPhillips 0 .. Well Attributes Max ( Angle & MD 1TD N' kU Inc 3 Wellbore APUUWI (Field Name Well Status ,I ncl (°) I MD (ftKB) 'Act Btu (ftKB) t:onnroPlulm k • 500292124960 KUPARUK RIVER UNIT PROD 13,000.0 Comment 1H25 (ppm) 'Date A of tton End Date 1KB (ft) Rig Release Date SSSV' Wencafi a 2Q w2 1Q9 151161 107 034AM Last O ut I —100 'Annotation on WELL WO _ 42.30 4/1/1985 _ _ —__ f ' � Stllarne0c AEI . Y A notation ( Depth (ftKB) End Dale M Last Mod ... End Date L _ ELL SIDETRACKED _ _ Imosbor 5/17 /2010 _ Casing Strings I Casing Description I String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... Str ng ... String Top Thrd LINER AL1 2 3/8 1.995 I 10,272.6 I 12,999.0 I 4 60 , L STL HANGER, 33 _ f Liner Details Top Depth (ND) Top Incl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 10,272.6 DEPLOY GS Top set 1.000 3 Notes: General & Safety sm .. : End Date Annotation 5/17/2010 NOTE: WELL SIDETRACKED 1Q - 03A & 1Q - 03AL7 (2 page schematic) CONDUCTOR,_ - - -- - -- 34-103 SAFEN NLV,_ -1"" 1,764 GAS LIFT, lir 1,974 GAS LIFT, 4,134 ice l 11 SURFACE, I 35 -5,224 GAS LIFT, 5,540 GAS LIFT, 6,275 1 GAS LIFT, 6,781 or GAS LIFT, 7,285 GAS LIFT, ilt 7,794 GAS LIFT, 8,380 GAS LIFT, L 6,913 GAS LIFT, 9.477 —_ ...... ,„ ,. GAS LIFT, 9,950 It P09,9,993 PACKER,__ 10,008 1111 PRODUCTION, 10,045 et PRODUCTION, 1 It 0,115 ill Mandrel Details Top Depth Top Port (TVD) Inc] OD Valve Latch Sinn TRO Run ,.,,. i..� Stn Top (ftKB) (ftKB) C1 Mace Model (in) UM Type Type (in) (psi) Run Date Con... 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 t/ ' - 4 6,274.8 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/17/2010 5 6,780.9 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 8/10/1993 PRODUCTION, ' 1 -- 6 7,285.4 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 10/25/1985 42 10,300 1 I 7 7,794.4 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/17/2010 8 8,380.0 CAMCO KB GAS DMY BK2 6/82003 LINERAL1, 9 8,912.8 CAMCO KBUG UG 1 1 GAS LIFT LIFT DMY BK2 0.000 0.000 0.0 0.0 3/17201 10$7312,999 TD (10 1 0 9,476.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 8/10/1993 - \ i i 13,000 - — • KUP • 1 Q -03AL1 ✓ Pftiilips d 3 c +r� Au /(a. ... ' E wen C 10c 7 KB•Grd(ft) Rig Release Date AT29?4Pdt 42.30 4/1/1985 HANGER, 33 ■ CONDUCTOR, 34-103 - ir SAFETY VLV, ilWt f 1,764 GAS LIFT, ..,. 1,974 LIFT, I it GA3 4,134 l f SU RFACE,_ I 355,224 GAS L IFT, _ 5, GAS L 11 6 .275- -__ 0 GAS LIFT_ 6,781 , GAS LIFT, ,285 I GAS LIFT, 7,794 ... I GAS LIFT __ 8.380 37 G J GAS LIFT, 8,913 GAS LIFT__ s4n GAS LIFT, 9.950 la PBR, 9,993 - - -- 1' Lam:,: -___ PA CKER,_ 10,008 PRODUCTION, 1 lit 0,045 PRODUCTION, Ig 10,115 sti4 Mandrel Details Top Depth Top 4 " Pori (TV()) I ^cl OD Valve latch See TRO Run Model (i S Stn To B (ftKB) (1 Make e TYP a Type On) (psi) Run Dab n, Co.. ktrft f [ 11 9,949.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0. 0 3/18/2010 ,. ■ 12 10,044.8 CAMCO MMG 1 1/2 PROD DMY RKP 0.000 0.0 3/18/2010 Closed (` iI 13 10,114.6 CAMCO MMG 1 1/2 PROD OPEN 0.000 0.0 3/312010 [ A 14 10,307.6 CAMCO MMG 1 1/2 PROD OPEN 0.000 0.0 3/31/2010 PRODUCTION, 42- 10,300 LINER 99 i i 1 12,999 TD (10 0 13, 0 0 13,000 • Page 1 of 2 Schwartz, Guy L (DOA) 1 a 3 1V From: Schwartz, Guy L (DOA) 1 A ` 2./0 026, Sent: Wednesday, March 31, 2010 9:55 AM 1 - 3AL Zr L OZ-1 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 -03 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 Olilinger CTD Engineer ConocoPhillips AK, Inc. 907 - 265 -1102 office 907 - 748 -1051 cell 3/31/2010 • 233 pTo f Application for Sundry to Plug Perforations KRU 1Q-03 1Q -03 Sundry (10 -403) Engineer: James Ohlinger P CT Drilling Engineer " (907) 265 -11102 (' "`"� `c s4r,Q-1 _11,7,ct 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. 3/O-6(.5 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. 1 Q -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 • • Application for Sundry to Plug Perforations KRU 10-03 5. 1 Q -03AL 1 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 16" 62# H -40 E 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) 1111 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 IIMI 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) I r 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 1I 3 -1/2" Camco MMG -2 production mandrel @ 10307.6' RKB ----- I Baker FB -1 packer @ 10,347.8' RKB (4.0" ID) B -sand perfs (sqz prior to 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 hales _ 3 -1/2" tubing tail @ 10,421' RKB 10,295'- 10,305' RKB a \\ \\ FISH 1Q- 03AL.1 Lateral 3 -1/2" Monobore whipstock w/ _ .„— TD @ 12,950' MD 4° kick removed"" ` `�\ 2T of Stidclir�e tools, top 10,347' 2 -3/8" slotted/solid liner from TO to \`� Catcher Sub above D- nipple TOWS @ 10,293' RKB I =I < \ \\ CA -2 Plug w/ gauges in D- nipple of 10,357.4 RKB 10,290' Mt? 10,297 ELM. \ \` „, .) ■ ` /,,, A -sand perfs '��;,\ 1 %� Q -03A Lateral 10556' - 10742' MD TD @ 12,950' MO ..- - 1 2 -3/8” slotted liner w/ aluminum billet C? 11,800' -/ 7:1-2— - _ _ " 7" 26# J -55 shoe 'k @ 10910' RKB ` `'. "N • • s 0[F AltnsEn 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, 1 Q -03AL 1 ConocoPhillips Alaska, Inc. Permit No: 210 -027 Surface Location: 1216'FNL, 1116' FEL, Sec. 26, T12N, R9E, UM Bottomhole Location: 301' FSL, 1440' 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ��day of March, 2010. cc: Department of Fish 85 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) • so REC EIVED STATE OF ALASKA MAR 0 9 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL al&GasCons.C x► 20 AAC 25.005 "Pt • /0 Af1C110 la. Type of Work: 1 b. Proposed Well Class: Development - Oil Q ' Service - Winj ❑ Single Zone lc. Specify if well is proposed for: Drill ❑ Re -drill El 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 ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 1Q - 03AL1 , 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 12830' ' TVD: 6673' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designatio n (Lease Number): Surface: 1216' FNL, 1116' FEL, Sec. 26, T12N, R9E, UM ADU 25634 Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 181' FSL, 1138' FEL, Sec. 13, T12N, R9E, UM 2572, 2567 5/15/2010 Total Depth: 9. Acres in Property: 14. Distance to 301' FSL, 1440' 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 fe to Same Pool: 3C -13 @ 1100' , 16. Deviated wells: Kickoff depth: 11825 ft. • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 96° d Downhole: 2517 psig' Surface: 1863 psig - 18. Casing Prod 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 2430' 10400' 6675' 12830' 6673' 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' I 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 q i • j p Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch Ei Drilling Program II Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 3 /c /% 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 110". d Printed Name V. Cawvey Title Alaska Wells Manager Signature Z Phon 265 -63o6 Date y8724/0 Commission Use Only Permit to Drill API Number: Permit Approval 1 See cover letter Number: 2./L ^ ( -�P s � r t t �, for other requirements 2 -��%�? �..- • ---7 � 50- �'c?.- - 1 2-4 (w {; ` � Date: � Conditions of approval : If box is checked well not be used to explore for, test, or produce coalbed meyhane, gas hydrates, or gas contained in shales: IX 44 3D 00,...., � ' gd p /e.51 Samples req'd: Yes ❑ No L r J ✓ Mud log req'd: Yes ❑ No ' Other: ' L H2S measures: Yes [ E No ❑ Directional svy req'd: Yes No [1 1-250e) p - An,. & .4.4. /e., c.,..40 0 APPROVED BY THE COMMISSION //. DATE: l , COMMISSIONER Form 10 (Revised 7/2009) This permit is valid for 24 mo frolo the 4 a • . • ' royal (20 AAC 25.005(9)) Submit in Duplicate o ' 3 • It to tf; 7.' . ! . , , y. • Conoco Phillips s RECEIVED Alas P.O. BOX 100360 MAR 0 9 2010 ANCHORAGE, ALASKA 99510 -0360 Alaska ON & Gas Cons. Commission February 26, 2010 AndiCfale 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 1 Q -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 1Q-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 AL1 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'/z" 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. Ri g Work 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 a. Drill a 2.70" x 3" bi- center lateral to a TD of 12,870' MD b. Run the 2%" slotted liner from TD to —11,825' MD. An aluminum liner top billet will he placed at 11.825' MD. 6. 1Q -03AL1 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 Th 5 c. Run the 2%" slotted liner from TD to 10,400' MD, into the 3 -1/2" tubing in the mother -bore. I ' 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 II 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 ° /g 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 the most recent bottom hole pressure measurement which was 2517 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' 1 Q -03AL1 20,245' • Distance to Nearest Well within Pool (toe measured to offset well 3C -13) Lateral Name Distance 1Q-03A 1085' 1 Q -03AL1 1100' Logging MWD directional, resistivity, and gamma ray will be run over the entire open -hole sections. , Reservoir Pressure 1 Q -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). 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 1 Q -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 1 Q -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 Tess 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 23/4" 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 ppg) 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 - I 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 MIIII 3 -1/2" Camco KBUG gas lift mandrels @ 1973.9', 4133.6' RKB shoe @ 103' MD M 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' ■ NNE 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 ii I' =' 3 -1/2" Camco MMG -2 production mandrels @ 10044.8', 10114.6', CTD) 10170' - 10208' MD 10307.6' RKB i! Illj' i ,, ri i . 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 i■ Baker SBE @ 10,351.1' RKB Pert holes ,1,0,370 '! ;? I � ,1 I!, 1." ".. " ".� Tubing punch perfs @ 10370' (to lock in tubing tail) 1Q -03AL1 Continency Lateral111'111Inl'I 2 ,finer top @ 10,400 MD ;! p� I!Ill' 3 -1 /2" Camco D nipple @ 10,387.4' RKB (2.75" min ID, No -Go) ,, U,! ; Iii !' � Ceme t to 1 000 . a rowmat len th � u , , II iG 1 3 -1/2" tubing tail @ 10,421' RKB Pp e .. I !i4J ? �1, 1 !! I,i '' , ' 1 ! '' ', 1 below nipple @,1'I! 2 3/,8I slotted /sold liner from!TD t � oh1 ! ' illiile , 1! , I i h I ,I fi, i ,1 11 ti G ibili ul, i III I `Hill , IP� 1 111 , I'— 1 0 4 00 M4, 111 1 I 10,400 � B MD i` , I �,I a;, i � l ,, ill, II r„ 1! ili I'h ,..,'41111 ,1111 1,1141. (J1111 ��1! ! i u 'I 1' 'III�I 'III I� 1'! i, ii�� II: ) ��II �. Ili I�I )li .jlile, 1 ��r llf l 1I 11 l 1,1 1'1 , I��k 1 1,' NI 14 '. I '' `` 40 2 -5/8' whipstock tray w/ OH '; I ' N + i ., enchorsset,in2807cement� ' y �� 1 "u y ,, r !,, i' ilot hole at',10,555' ' MD , 1 1 '' , , ` �, �,� 1 Q 03A Lateral l,,,j Il ti a ! i s ! i m ill A-sand perfs,(sgz prior,, ,I IN -- ?,'� TD @;1:2900 MD,II��!I!p; 1 , , i ;,pilil �� ll'�� I I to CTD) 'I' s d !i er I mi u list s;. ; - �..�.� -- ,' am°' : - .�� 2 3/8 II I t o . I ptl otte N 'p ' ��h !I -j!' hf- � IIko � j l l�i l , i , II I I u, 742 MD IV !I � ` II�1111' h!I� i� �, ll, t �i ! I r'I )!I n l �! 10556 10 . '''"!'4:14,41:414:1414,:4:44:!+.44..-i.94,, �!;, � � �.1i1,1r,�!! �II lL,I,�,�l � ::,1. ! y ,,1,,., T ' 4k i- 1 y Cement L '' ', -t!,+ Cement pilot hole ,80) 'a N j � I :11, „'` a drilled t 1 M 51 , �I '' ' 1 7" 26# J-55 shoe ` i' lliV ii h,:,Jii!II'' i f l:ileuai ,.:d @ 10910' RKB KU P • 1 Q-03 Ct}t11DCdPhillips Well Attributes = I Max Angle & MD _ TD I _ Alaska, ITL:. ,- ' Welibore APIIUWI Field Name Well Status Inc] r) MD (MB) Act Btm (tIKB) Cw10c'a,,m, 500292124900 KUPARUK RIVER UNIT PROD 60.86 3,000.00 10,944.0 Commend H23 (ppm) Date Annotation End Date KB (ft) Rig Release Data ••• Well Conag: - 701 72520111 9'.33:19 AM SSSV: Locked Out I 100 8/6/2009 Last WO: 42.30 4/1/1985 Schematic - Aetna! Annotation Depth MKS) 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 Casiriq Strings -' Casing Description String 0... String 10 _. Top (18(8) Set Depth (0.- Set Depth (TVD) ... String Wt... String String Top Thrd CONDUCTOR 16 15.063 34.0 103.0 103.0 62.50 H - HANGER, 33 3 Casing Description String 0... String ID ... Top (11(8) Set Depth (t.- Set Depth (TVD) .- String Wt... String ... String Top Thrd v 1 SURFACE 95/8 8.766 35.0 5,223.8 3,635.5 36.00 J-55 BTC Casing Description String 0_ String ID _ Top (11KB) Set Depth (0.. Set Depth (TVD) . String Wt... String String Top Thrd PRODUCTION 7 6.156 32.3 10 910.1 6,916.0 26.00 J-55 BTC Tubing Strings -- .,, I Tubing Description String 0... String ID Top (11K8) Set Depth (1.. Set Depth (TVD) . String Wt... String String Top Thtd CONDUCTOR, TUBING 312 2.992 32.5 10 421.0 6,646.2 9.30 J-55 EUE8rd 34-103 'II Top Details- - _ _ - - -_ Top Depth ;. SAFETY (TVD) Top Ind Nomi... - -^ 1,7769 69 �.. Top (11KB) ME) ) (•) Item Description Comment (in) 11 32.5 32.5 -1.06 HANGER McEVOY TUBING HANGER 3.500 5 1,763.7 1,681.5 34.55 SAFETY VLV BAKER SSSV'FVL' (LOCKED OUT 6/19/2986) 2.810 GAS LIFT, 7,974 9,993.3 6,389.6 51.50 PBR BAKER PBR 3.000 10,007.8 6,398.6 51.00 PACKER BAKER 'FHL' PACKER 3.000 GAS UFT, - 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, 355,724 10,351.1 6,605.4 53.90 SBE BAKER SBE 4.000 GAs UFT, - 10,387.4 6,626.6 54.27 NIPPLE CAMCO 'D' NIPPLE 2.750 5,540 _ IL 10,420.3 6,645.7 54.52 SOS CAMCO SHEAROUT SUB 3.000 GAS uF 477s 5 = Other In Hole 'reline retrievable plugs, valves, pumps, fish, etc.) - - Top Depth GAS UFT, (TVD) Top M el . 6,781 ; Top (fdkB) (1008) (1 Desciption Comment Run Date ID in lli 10,690 6,797.6 57.05 FISH 1 1/2" CV Empty Pocket Fell to Rathole 11/1/1993 1.000 GAS UFT, _ -- 7,288 P $Iota . ,_. _ -i Shot GAS UFT, 11-- Top (TVD) Bbn (ND) Dens 7 ' Top (111(B) Btm (18(8) MKS) (RKB) Zone Date (nh••• Type Comment GAS UFT '�' 10,170 10,208 6,498.3 6,521.2 C UNIT B, 5/4/1985 12.0 IPERF 5" Scalloped Gun 8,380 10-03 10,250 10,267 6,546.2 6,556.3 UNIT B, 10-03 5/4/1985 12.0 IPERF 5" Scalloped Gun As a 913 10,556 10,638 6,723.3 6,769.1 A-4, 43, 10-03 5/4/1985 4.0 IPERF 120 deg. phasing, 4" Carrier JJ II Gun GAS LIFT, 10,556 10,638 6,723.3 6,769.1 A-4, 43, 10-03 7/25/1993 4.0 RPERF Oriented 13 deg. CCW F/ Bottom of 9,477 ar Hole, 2 1/8" EnerJet I? 10,670 10,690 6,786.7 6,797.6 42, 10-03 5/4/1985 4.0 IPERF 120 deg. phasing, 4" Carrier 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. 2' CCW F/ Bottom of Hole •! @@ 10,734 10,742 6,821.6 6,825.9 A -2, 10-03 5/4/1985 4.01IPERF 120 deg. phasing, 4" Carrier JJ 11 Gun PBR, E - Notes General & Safet PACKE - - - - 70,006 ~� End Date Annotation 4/3/1996 NOTE VIDEO SURVEY; Deformed TBG @ 5460'; LEAK @ 10302' PRODUCTION, 10,00.5 4/3/1996 NOTE: Attempt to drift Buckled Tbg @ 5640' RKB on 9/11/97 - No Success II 11/22/1997 NOTE: Possible Problem w/ Key Profile of'D' Nipple PRODUCTION, 10,116 5 5/2006 NOTE: TBG TIGHT SPOT 5447 WLM W2.79" X 96" DRIFT 2/25/2010 NOTE VIEW SCHEMATIC w /Alaska Schematic9.0 (2 page schematic, print double- sided) II IPERF, i. ' 10.170 -10.208 a IPERF, _ g __-_- 10,250-10,267 � =iI E PRODUCTION, 10,308 LOCATOR, 10,347 -'+ PACKER, 10,348 SBE, 10,351 I NIPPLE, 10,387 303,,0, +20 Mandrel Details - - - -_ Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run RPERF, Stn Top MEI) (RKB) (•) Make Model (in) gem Type Type (in) (pail Run Date Com... 10.55510,638'\ 1 1,973.9 1,852.9 39.02 CAMCO KBUG 1 GAS LIFT DMY BK2 0.0001 0.0 5/24/2006 IPERF, 10,556 638 - = 2 4,133.6 3,043.2 57.52 CAMCO KBUG 1 GAS LIFT GLV BK2 0.156 1,370.0 6/8/2006 10,670.1oEao \ 3 5,540.1 3,797.6 57.94 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 5/24/2006 IPERF, \ - 10 s70.10,690 - - 4 6,274.8 4,200.4 55.15 CAMCO KBUG 1 GAS UFT 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 0.0001 0.0 8/10/1993 IPERF, - 6 7,285.4 4,787.9 53.92 CAMCO KBUG 1 GAS LIFT DMY BK2 0.0001 0.0 10/25/1985 10'734 7 7,794.4 5,084.6 54.95 CAMCO KBUG 1 GAS UFT 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 5,737.3 53.36 CAMCO KBUG 1 GAS LIFT GLV BK2 0.188 1,355.0 6/8/2006 PRODUCTION, 32 10,944 • 10 9,476.6 6,070.8 51.85 CAMCO KBUG 1 GAS LIFT DMY BK2 0.0001 0.0 8/10/1993 TD, 10,991 KUP • I Q -03 ConacoPhillips Al,)1y ••• KB-G,d (11) Rig RM.. Date Well Can696 -10433. 3252010 933:19 AM 42.30 4/1/1985 S9lema 18 -Actual HANGER,33 1J CONDUCTOR 34-103 SAFETY VLV, 1,761 LIFT, 1 GAS .. 1 974 GASUFT, I� 4,134 SURFACE, 35 -5,224 GAS UFT, 5,540 GAS LIFT, 6,275 �- GAS LIFT, 6,781 GAS LIFT, 7,285 GAS LIFT, 7.794 GAS UFT, _ 8,380 GAS LIFT, 8,913 m GAS LIFT, 9,477 GAS LIFT, 9,950 P8R 9,993 PACKER, 10,008 PRODUCTION, 0,045 - PRODUCTIO, 1011 IPERF, 10,17610,208 IPERF, _ 10,250. 10,267 s ' PRODUCTION, 10,308 _— LOCATOR, I 1 10,3471 PACKER, 10,348 ME, 10,351 1 NIPPLE, 10,387 1 SOS, 10,420 Mandrel Details - - -.- -- - - Top Depth Top P - 7VD) ix! 00 Valve Latch size TRO Run RPERF, Stn Top (1IKB) (KKK) (1 Make Model (in) Senn Type Type (in) (Pei) Run Date Com.- 10,556 10,638 11 9,949.6 6,362.6 51.73 CAMCO MMG 1 112 GAS LIFT OV RK 0.188 0.0 6/8/2006 IPERF, 10.556.10.638 . - . 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, 10,675 - 10,690 — 13 10,114.6 6,464.7 52.18 CAMCO MMG 1 1/2 PROD CV RKP 0.000 0.0 1/16/2009 Open IPERF, — 10,670-10,690 14 10,307,6 6,580.0 53.40 CAMCO MMG I 1 1/2IPRO0 CV RKP 0.000 0.0 1 /16/2009 Open FISH, 10,890 IPERF, 10,73410,742 PRODUCTION, 32-10.910 TD, 10,944 . • C onocoPhilli s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1Q Pad 1Q-03 1 Q -03AL1 Plan: 1 Q -03AL1 wp02 Standard Planning Report 25 February, 2010 Et/ BAKER HUGHES ConocoPhillips la au Conoc hiIIips 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: 1 Q -03AL1 Design: 1Q- 03AL1_wp02 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 1 Site Position: Northing: 5,984,677.62ft Latitude: 70° 22' 9.206 N I From: Map Easting: 528,389.22 ft Longitude: 149° 46' 9.484 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.22 ° Well 1Q I Well Position +N / -S 0.00 ft Northing: 5,984,656.79ft / 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: 47.50 ft I r Wellbore 1Q - 03AL1 Magnetics Model Name - Sample Date Declination Dip Angle Field Strength (°) (°) (nT} BGGM2009 5/1/2010 17.21 - 79.83 57,377 Design 1Q- 03AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,825.00 Vertical Section: Depth From (ND) +W-S +E/ -W Direction 1 (ft) (ft) (ft) r) - 47.50 0.00 0.00 298.00 Plan Sections I Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/ -W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (1100ft) (°/100ft) (° /100ft) ( °) Target 11,825.00 87.24 321.30 6,674.63 6,324.60 5,802.39 0.00 0.00 0.00 0.00 11,855.00 91.67 322.08 6,674.91 6,348.14 5,783.80 15.00 14.77 2.60 10.00 11,895.00 96.26 325.95 6,672.14 6,380.41 5,760.36 15.00 11.47 9.69 40.00 11,975.00 90.74 315.28 6,667.25 6,442.00 5,709.77 15.00 -6.91 -13.35 243.00 12,075.00 91.23 300.28 6,665.52 6,503.07 5,630.97 15.00 0.49 -14.99 272.00 12,225.00 91.52 277.78 6,661.88 6,551.65 5,490.12 15.00 0.19 -15.00 271.00 12,375.00 91.40 300.28 6,658.01 6,600.23 5,349.27 15.00 -0.08 15.00 90.00 12,475.00 90.06 315.23 6,656.72 6,661.28 5,270.44 15.00 -1.34 14.94 95.00 I 12,725.00 87.01 277.83 6,663.35 6,770.97 5,050.84 15.00 -1.22 -14.96 265.00 12,830.00 82.30 292.93 6,673.19 6,798.57 4,950.35 15.00 -4.48 14.38 108.00 2/25/2010 8:58:11AM Page 2 COMPASS 2003.16 Build 69 •- Conoco Phillips p ConocoPhillips Planning Report BAKER n 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 Q 90.00ft (Nordic 1) Site: Kuparuk 10 Pad North Reference: True Well: 1Q - 03 Survey Calculation Method: Minimum Curvature Wellbore: 1Q Design: 1 Q - 03AL1 _wp02 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) ( %100ft) C) - (ft) (ft) 11,825.00 87.24 321.30 6,674.63 6,324.60 5,802.39 - 2,153.99 0.00 0.00 5,991,002.82 534,285.12 TIP / KOP 11,855.00 91.67 322.08 6,674.91 6,348.14 5,783.80 - 2,126.52 15.00 10.00 5,991,026.27 534,266.44 2 1 11,895.00 96.26 325.95 6,672.14 6,380.41 5,760.36 - 2,090.68 15.00 40.00 5,991,058.45 534,242.88 3 1 11,900.00 95.92 325.28 6,671.61 6,384.51 5,757.55 - 2,086.27 15.00 - 117.00 5,991,062.55 534,240.06 11,975.00 90.74 315.28 6,667.25 6,442.00 5,709.77 - 2,017.09 15.00 - 117.07 5,991,119.84 534,192.06 4 12,000.00 90.87 311.53 6,666.90 6,459.17 5,691.61 - 1,993.00 15.00 -88.00 5,991,136.94 534,173.84 , 12,075.00 91.23 300.28 6,665.52 6,503.07 5,630.97 - 1,918.84 15.00 -88.05 5,991,180.61 534,113.04' 5 12,100.00 91.29 296.53 6,664.97 6,514.96 5,608.99 - 1,893.85 15.00 -89.00 5,991,192.42 534,091.01 12,200.00 91.49 281.53 6,662.54 6,547.46 5,514.75 - 1,795.39 15.00 -89.08 5,991,224.56 533,996.66 12,225.00 91.52 277.78 6,661.88 6,551.65 5,490.12 - 1,771.67 15.00 -89.45 5,991,228.65 533,972.02 6 12,300.00 91.49 289.03 6,659.91 6,569.01 5,417.30 - 1,699.23 15.00 90.00 5,991,245.73 533,899.14 12,375.00 91.40 300.28 6,658.01 6,600.23 5,349.27 - 1,624.50 15.00 90.30 5,991,276.69 533,831.00 7 12,400.00 91.07 304.02 6,657.47 6,613.53 5,328.11 - 1,599.58 15.00 95.00 5,991,289.91 533,809.79 12,475.00 90.06 315.23 6,656.72 6,661.28 5,270.44 - 1,526.24 15.00 95.08 5,991,337.43 533,751.95 8 12,500.00 89.74 311.49 6,656.77 6,678.44 5,252.27 - 1,502.14 15.00 -95.00 5,991,354.52 533,733.71 1 12,600.00 88.45 296.54 6,658.36 6,734.22 5,169.63 - 1,402.98 15.00 -94.99 5,991,409.98 533,650.86 12,700.00 87.28 281.58 6,662.10 6,766.77 5,075.45 - 1,304.55 15.00 -94.76 5,991,442.16 533,556.57 12,725.00 87.01 277.83 6,663.35 6,770.97 5,050.84 - 1,280.85 15.00 -94.20 5,991,446.28 533,531.95 9 12,800.00 83.60 288.59 6,669.50 6,788.02 4,978.19 - 1,208.70 15.00 108.00 5,991,463.04 533,459.24 12,830.00 - 82.30 292.93 6,673.19 - 6,798.57 4,950.35 - 1,179.17 15.00 107.12 5,991,473.48 533,431.37 TD 2/25/2010 8 :58 :11AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Nal • 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: 1 Q 03AL1_wp02 Targets - Target Name - hit/miss target Dip Angle Dip Dir. TVD +W3 +E/-W Northing Easting= - Shape (°) ( °) (ft) (ft) (ft) (ti) (ft) Latitude Longitude 1Q -03AL1 t4 0.00 0.00 6,673.00 6,796.35 4,948.43 5,991,471.26 533,429.46 70° 23' 15.821 N 149° 43' 41.147 W - plan misses target center by 2.93ft at 12830.00ft MD (6673.19 TVD, 6798.57 N, 4950.35 E) - Point 1Q -03AL1 KOP 0.00 0.00 6,677.00 6,436.33 5,729.14 5,991,114.26 534,211.46 70° 23' 12.275 N 149° 43' 18.298 W - plan misses target center by 13.79ft at 11957.69ft MD (6667.65 TVD, 6429.46 N, 5721.69 E) - Point 1Q -03AL1 t1 0.00 0.00 6,666.00 6,472.52 5,681.28 5,991,150.26 534,163.46 70° 23' 12.631 N 149° 43' 19.698 W - plan misses target center by 3.57ft at 12016.24ft MD (6666.64 ND, 6469.67 N, 5679.23 E) - 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 6756.20ft at 12333.66ft MD (6659.04 TVD, 6581.37 N, 5386.01 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 1 Q -03AL1 t3 0.00 0.00 6,657.00 6,702.25 5,234.11 5,991,378.26 533,715.46 70° 23' 14.894 N 149° 43' 32.785 W - plan misses target center by 6.92ft at 12528.45ft MD (6656.99 ND, 6696.49 N, 5230.27 E) - Point 1Q -03AL1 t2 0.00 0.00 6,660.00 6,558.52 5,422.58 5,991,235.26 533,904.46 70° 23' 13.479 N 149° 43' 27.270 W - plan misses target center by 8.31ft at 12292.43ft MD (6660.10 ND, 6566.61 N, 5424.48 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (It) Name ( ") ( ") 5,224.00 3,545.57 9 5/8" 9 -5/8 12 -1/4 12,830.00 6,673.19 2 -3/8" 2 -3/8 3 2/25/2010 8:58:11AM Page 4 COMPASS 2003.16 Build 69 f ConocoPhillips • ConocoPhillips • Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 Q Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1Q-03 Q 90.00ft (Nordic 1) Site: - Kuparuk 10 Pad North Reference: True Well: 1Q - 03 Survey Calculation Method: Minimum Curvature Weilbore: _ 1Q - 03AL1 Design:- 1Q 03AL1_wp02 - - I Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/.S +e -W (ft) (ft) (ft) (ft) Comment 11,825.00 6,674.63 6,324.60 5,802.39 TIP / KOP 11,855.00 6,674.91 6,348.14 5,783.80 2 11,895.00 6,672.14 6,380.41 5,760.36 3 11,975.00 6,667.25 6,442.00 5,709.77 4 12,075.00 6,665.52 6,503.07 5,630.97 5 12,225.00 6,661.88 6,551.65 5,490.12 6 12,375.00 6,658.01 6,600.23 5,349.27 7 12,475.00 6,656.72 6,661.28 5,270.44 8 12,725.00 6,663.35 6,770.97 5,050.84 9 12,830.00 6,673.19 6,798.57 4,950.35 TD 2/25/2010 8 :58.11AM Page 5 COMPASS 2003.16 Build 69 ■ e Azimuth. to True North WELLBORE DETAILS: 1Q -03AL1 REFERENCE INFORMATION - -- -- y Project: Kuparuk River Unit Magn.e� North zt.7z° Site: Kuparuk 1Q Pad Co-ordmate (N /E) Reference. Well 10 - 03, True North Mag5 raw Parent Wellbore: 10 -03A ,' Well: 1Q-03 strength 57861 ten Tie on MD: 11825.00 Vertical (TVD) Reference Mean Sea Level BAKER C�^�r7f1 f� Wellbore: 1 Q -03AL7 od El GM20 VO ocoP�� Plan: 1Q -03AL1 02 1Q -03 /1Q -03AL7 Oats 5/1/2010 Measured Depth Reference: 10 -03! 90.00ft(Nordic 1) HUGHES Calculation Method: Minimum Curvature 7070 - WELL DETAILS: 10 -03 7000 Ground Level: 47.50 ' +14/-S +E / -W Northing Easting Lahttude Longitude Slot 6930- - - 0.00 0.00 5984656.79 528507.43 70° 22'8.996 N 149° 46'6.028 W - n SECTION DETAILS ANNOTATIONS 6860- -- - -- - TD ' '' l over Sec MD Inc Azi TVDSS +NI -S +E / -W DLeg TFace VSec Target Annotation 6790_ - - __ N EB ° R 'N 1 11825.00 87.24 321.30 6674.63 6324.60 5802.39 0.00 0.00 - 2153.99 TIP / KOP 2 11855.00 91.67 322.08 6674.91 6348.14 5783.80 15.00 10.00 - 2126.52 2 . 9 - 3 11895.00 96.26 325.95 6672.14 6380.41 5760.36 15.00 40.00 - 2090.68 3 .6720 4 11975.00 90.74 315.28 6667.25 6442.00 5709.77 15.00 243.00 - 2017.09 4 G 5 12075.00 91.23 300.28 6665.52 6503.07 5630.97 15.00 272.00 - 1918.84 5 w6650 6 12225.00 91.52 277.78 6661.88 6551.65 5490.12 15.00 271.00 - 1771.67 6 0 8 7 12375.00 91.40 300.28 6658.01 6600.23 5349.27 15.00 90.00 - 1624.50 7 • 8 12475.00 90.06 315.23 6656.72 6661.28 5270.44 15.00 95.00 - 1526.24 8 ,_,6580 1Q o:r1 Q - 03A 7 6 ' 9 12725.00 87.01 277.83 6663,35 6770.97 5050.84 15.00 265.00 - 1280.85 9 .,. 10 12830.00 82.30 292.93 6673.19 6798.57 4950.35 15.00 108.00 -1179.17 TD 6510 5 0 76440 a 56370- 0 IA 6300 - TIP / KOP 6230- 6160- - - 6090 4620 4690 4760 4830 4900 4970 5040 5110 5180 5250 5320 5390 5460 5530 5600 5670 5740 5810 5880 West( -) /East( +) (70 ft /in) 6540 - 6s7o O 6600 . 1Q-03/1Q-03A I TIP / KOP w 6630 4 5 6 7 8 q - - -- O 3 ' ' • 6660- F-^ t 0 ? 6690 . . - - - -. - TD J 01 N 6 720 ' •^ IQ- (13/IQ -(13 10°03/1Q- (13ALI X6750- • 6780 6810- . 6840 6870 ' -2190 -2160 -2130 -2100 -2070 -2040 •2010 -1980 -1950 -1920 -1890 -1860 -1830 -1800 -1770 -1740 -1710 -1680 -1650 -1620 -1590 -1560 -1530 -1500 -1470 -1440 -1410 -1380 -1350 -1320 -1290 -1260 -1230 -1200 -1170 -1140 -1110 -1080 -1050 Vertical Section at 298.00° (30 ft/in) Azinreeto True North WELLBORE DETAILS: 1Q -03A REFERENCE INFORMATION "'° Project: Kuparuk River Unit Magnetic Noa.21.72 Site: Kuparuk 1Q Pad M.9 O Fekl Parent Wellbore: 1 Q -03 Co-ordinate (N /E) Reference: Well 10 -03, True North ,- Well: 1Q -03 SlrergM-5/661.1enT Tie on MD: 10500.00 Vertical(TVD)Reference• 10- 03 @90.00ft(Nordic 1) BAKER * Wellllore: 1Q oe .07' Section (VS) Reference. Slot - (000N, 0.00E) R CanacoPh�IfipS Plan: 1Q -03A wp03j1Q - 03A) l ° Model a l BGGPA Measured Depth Re 10- 03 @90.00ft(Nordic l) Calculation Method: Minimum Curvature HUGHES 8800- 8600 8400 ' 8200- 8000- 1 7800 ' 7600 - - - - 7400- - - - - - - .. 7200- ' 7000 Vi m'' 1Q- 01 /1Q -03ALI • • I■ 2IIp -21 6800 — � o,�,0 t +e__ C r'on 6600- fin,,,, • 6000 IQ 03/lQ4ilA ' \ + Cd ` 6200 - ` p 6000 ' ■ 1 5800 / ' 10413/1Q-03 5600 Io -ot to -ol / Y a / - ' - - %�1'/2 j • 5400 - fi , N/ • fir/ /i • Jo, f 5200 �'oo • / ' 5000 / \ ;40770 ' ' tQ -02/1Q -021 1 48001 4600 1 / 4400 1 4200 / 0 t 7 1�'o2/tQ . 02B 4000 / 1 • ' 10414/1Q-0-3 IQ-22 10 -\' - 3800 i 7.6ZI4 / 3600. % / - / - - -- - - - - • - -- 10 -02 i0- 020,'131_ 3400 - / r�><d / 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 11600 8800 9000 1Q -03 ti 90.00ft (Nordic 1) West( -) /East( +) (200 ft/in) 0 • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser r 7 Annular/ Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator 4 �< � L ><>< 7 r% .■■■ IN above BHA rams • 1 r Choke 1 'I 2 -3/8" Pipe / Slip (BHA) I' Choke Equalize Manifold ' 2 -3/8" Pipe / Slip (BHA) ' I Kill ►V V J L i/ ci > —L 1111111V 1 r Blind / Shear IN 2" Pipe / Slip (CT) I' II x Choke 2 I :Swab Valves .,,, • Wing Valves 41 4 I : L--(_>-J Tree Flow Cross 4 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 CHECKLIISST WELL NAME /4 L' /-/ ( PTD# 210 Oz- 7(Z 1/ Development Service Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK I ADD -ONS ! TEXT FOR APPROVAL LETTER WHAT (OPTIONS) • APPLIES j MULTI LATERAL I The ermit is fora new wellbore segment of existing P g o well LC--{ /4) — �� (If last two digits in Permit AP[ No. 50 -g / - �Z /9 API number are Production should continue to be reported as a function of the between 60 -69) � original API number stated above. PLOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both i I 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 Commission to obtain advance approval of such water well testing program. Rev: 1 25/06 C.`jody\transmittal_checklist ry .: Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1Q -03AL1 Program DEV Well bore seg 0 PTD#: 2100270 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 of prod interval and TD in ADL 25634. 3 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 3 miles 1 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes op 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 AS31.05.0300.1.A),(j.2.A -D) NA 118 Conductor string provided NA Conductor set in 1Q-03 Engineering 119 Surface casing protects all known USDWs NA Surface casing set in 1Q -03 120 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 in 1Q-03 1 1 22 CMT will cover all known productive horizons No OH slotted liner planned 23 Casing designs adequate for C, T, B & permafrost Yes 1 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 125 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. Nearest well in pool 3C -13 is 1100' ft 27 If diverter required, does it meet regulations NA Wellhead in place. Will place BOP stack on top of tree. Appr Date 1 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 0 S 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 131 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 1Q pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 1 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 borehole stability. 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P • Date: Date Date Commissioner: Commissioner: C. a'j'y, J er O /— 3-/c16 c.?'1S = /a