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Home My WebLink About210-049MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-16A KUPARUK RIV UNIT 3N-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3N-16A 50-029-21593-01-00 210-049-0 N SPT 3562 2100490 1500 2015 2710 2660 2655 270 270 266 267 REQVAR P Bob Noble 8/17/2024 MIT-T per 2B.057, Plug set at 8145' 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-16A Inspection Date: Tubing OA Packer Depth 440 460 460 460IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240818154632 BBL Pumped:0.5 BBL Returned:0.4 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 999 9 9 9 9 99 9 9 9MIT-T per 2B.057, James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:28:48 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-16A KUPARUK RIV UNIT 3N-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3N-16A 50-029-21593-01-00 210-049-0 N SPT 3562 2100490 1500 2080 2250 2270 2270 262 264 264 264 REQVAR P Bob Noble 8/17/2024 MIT-IA per AIO 2B-057 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-16A Inspection Date: Tubing OA Packer Depth 450 2800 2670 2660IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240818155121 BBL Pumped:1.4 BBL Returned:1.4 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 999 9 99 9 9 9 9 9 AIO 2B-057 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:26:42 -08'00' New Plugback Esets 6/24/2024 Well Name API Number PTD Number ESet Number Date 1E-15AL2 PB1 50-029-20769-70-00 210-015 T38990 6-17-2010 1E-15AL2 PB2 50-029-20769-71-00 210-015 T38991 6-17-2010 1E-15AL2 PB3 50-029-20769-72-00 210-015 T38992 6-17-2010 3N-16A PB1 50-029-21593-70-00 210-049 T38993 7-8-2010 3N-16A PB2 50-029-21593-71-00 210-049 T38994 7-8-2010 3N-16A PB3 50-029-21593-72-00 210-049 T38995 7-8-2010 CD4-27 PB1 50-103-20644-70-00 211-146 T38996 6-14-2012 CD4-27 PB3 50-103-20644-72-00 211-146 T38997 6-14-2012 ODST-46 PB1 50-703-20631-70-00 210-183 T38998 5-10-2011 ODST-46 PB2 50-703-20631-71-00 210-183 T38999 5-10-2011 ODST-46 PB3 50-703-20631-72-00 210-183 T39000 5-10-2011 W-19AL1 PB1 50-029-22006-70-00 202-235 T39001 6-10-2003 W-19AL1 PB2 50-029-22006-71-00 202-235 T39002 6-10-2003 3N-16A PB1 50-029-21593-70-00 210-049 T38993 7-8-2010 3N-16A PB 2 50-029-21593-71-00 210-049 T38994 7-8-2010 3N-16A PB 3 50-029-21593-72-00 210-049 T38995 7-8-2010 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-16A KUPARUK RIV UNIT 3N-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 3N-16A 50-029-21593-01-00 210-049-0 N SPT 3562 2100490 1500 2920 3830 3770 3750 290 290 290 290 REQVAR P Kam StJohn 8/10/2022 MIT-T every 2 years against plug set within 200'of liner top per AIO 2B.057 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-16A Inspection Date: Tubing OA Packer Depth 170 190 190 190IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220810182546 BBL Pumped:0.3 BBL Returned:0.1 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 MIT-T every 2 years AIO 2B.057 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 12:20:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-16A KUPARUK RIV UNIT 3N-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 3N-16A 50-029-21593-01-00 210-049-0 N SPT 3562 2100490 1500 2900 3180 3170 3170 290 290 290 290 REQVAR P Kam StJohn 8/10/2022 MIT-IA every 2 years to verify casing integrity per AIO 2B.057 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-16A Inspection Date: Tubing OA Packer Depth 170 1800 1720 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220810182906 BBL Pumped:1 BBL Returned:0.7 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 MIT-IA every 2 years AIO 2B.057 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 12:23:14 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, August 13, 2020 P.I. Supervisor I 71 1(�i�TcCi7_4� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3N -16A FROM: Bob Noble KUPARUK RIV UNIT 3N -16A Petroleum Inspector Sre: Inspector Reviewed By: P.I. SupryJ Z NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N -16A API Well Number 50-029-21593-01-00 Inspector Name: Bob Noble Permit Number: 210-049-0 Inspection Date: $/9/2020 Insp Num: mitRCN200811140602 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N -16A _ Type Ind N TVD 3562 - Tubing 3100 - 3100 3400 - 3450 ' PTD 2100490 - Type Test SPT- Test psi 1500 IA 170 1725 - 1640 - 1630 - BBL Pumped: 0.9 BBL Returned: 0.8 I'i OA 300' 300 - 300 - 300 ' Interval REQVAR 'PIF — P ! - - - ----L-- _._ Notes: MIT -IA every 2 years to 1500 pis as per AIO 2B.057 Notes: Thursday, August 13, 2020 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 13, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3N -16A KUPARUK RIV UNIT 3N -16A Src: Inspector Reviewed By: P.I. Supry J Comm Well Name KUPARUK RIV UNIT 3N -16A API Well Number 50-029-21593-01-00 Inspector Name: Bob Noble Permit Number: 210-049-0 Inspection Date: 8/9/2020 InSp Num: mitRCN200811135832 Rel Insp Num: Packer Well 3N -16A !Type Inj N iTVD PTD 2100490 -'Type Testi SPT (Test psi BBL Pumped: 03 -BBL Returned: Interval - REQVARL P/F - Notes: MIT -T every 2 years as per AIO 2B.057 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3562 - Tubing 2950 _ 3760 - 3700 - 3690 - 1500 IA 150 180 - 180- 180 - 0.1 - OA 300300 - 300 - 300 Thursday, August 13, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 10,2016 TO: Jim Regg P.I.Supervisor jet �(I 0(I L SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-16A FROM: Jeff Jones KUPARUK RIV UNIT 3N-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J��t NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-16A API Well Number 50-029-21593-01-00 Inspector Name: Jeff Jones Permit Number: 210-049-0 Inspection Date: 8/7/2016 Insp Num: mitJJl60809072327 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weli 3N-16A - Type Inj W -TVD I 3562 Tubing 2520 3330 - 3280 -i 3270 - PTD 2100490 Type Test SPT Test psi 1500 - IA 825 850 - 850 = 850 - Interval REQvAR P/F P - OA 190 180 - 186 - 185 , Notes: 2 Year MIT-T to demonstrate continued injection string integrity required by AA AIO 2B.057.A plug was set in the tubing @ 8160'MD to facilitate test. 1 well inspected,no exceptions noted. ., SCANNED MAY 0 20 1.7 Wednesday,August 10,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,August 08,2016 Jim Regg SUBJECT: Mechanical Integrity Tests P.I.Supervisor '��' �� I to CONOCOPHILLIPS ALASKA INC 3N-I 6A FROM: Bob Noble KUPARUK RIV UNIT 3N-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry+J — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-16A API Well Number 50-029-21593-01-00 Inspector Name: Bob Noble Permit Number: 210-049-0 Inspection Date: 8/1/2016 Insp Num: mitRCN160801173906 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-16A -[Type Inj I W'I TVD 3562 . Tubing 2850 - 2850 . 2850 . 2840 . PTD 2100490 -Type Test SPT Test psi 1500 IA 1 470 1800 - 1750 - 1730 . Interval REQVAR P/F P */ OA j 210 * 210 . 210 210 - Notes: MIT-IA per AIO 2B.057 to a min of 1500 psi %AWED MAY 0 rte`.i i Monday,August 08,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg DATE: Wednesday,January 07,2015 P.I.Supervisor�e7 l/Z'Z/IS' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-16A FROM: Matt Herrera KUPARUK RIV UNIT 3N-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-16A API Well Number 50-029-21593-01-00 Inspector Name: Matt Herrera Permit Number: 210-049-0 Inspection Date: 12/13/2014 Insp Num: mitMFH141220143401 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 3N-16A - 'Type Inj W TVD J 3562 - Tubing 2840 - 2840T j 2840 2840 PTD I 2100490 ' Type Test SPT,Test psi 1500 _ IA 348 - 2015 - 1930- 1914 Interval REQVAR / P/F P - OA 200 - 200 - 200 200 Notes: 1 BBL Diesel to pressure up IA k Z-3.06-7 Wednesday,January 07,2015 Page 1 of 1 i • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J Q - 0 ti-y' Well History File Identifier Organizing (done) ❑ Two -sided 111 IIIIHIIIII 11111 ❑ Rescan Needed 1111 111111 7 Co AN DIGITAL DATA OVERSIZED (Scannable) r Items: ❑Diskettes, No. ❑Maps: Greyscale Items: ❑Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: . BY: Date: /s/ i nD Project Proofing IIIIIIIIIIIII I IIIII BY: AIM Date: / a . /s/ Y ' F P Scanning Preparation J x 30 = / ` + 6 = TOTAL PAGES 1 U l (Count does not include cover sheet) BY: Maria Date: �./ tgotg._ / s/ f if 1 Production Scanning Ilillirillirlill ill Stage 1 Page Count from Scanned File: /5 7 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO D BY: CMaria Date: (o/ &7 1 /s/ V1, 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. Ill 1111111111111111 ReScanned Ifl lIIlIIHI 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111'111111111111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 6/21 /2012 Permit to Drill 2100490 Well Name /No. KUPARUK RIV UNIT 3N -16A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21593 -01 -00 MD 8190 TVD 6478 Completion Date 7/1/2010 Completion Status SUSP Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Surve� 4 DATA INFORMATION �k - - Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED' C Lis 19928 Induction /Resistivity 4857 8190 Open 7/28/2010 OH LIS and PB1, PB2, PB3 GR, RPD, RPM, RPS, RPX, FET, ROP plus TIFF, CGM, PDF graphics o• Induction /Resistivity 25 Col 4882 8190 Open 7/28/2010 MD ROP, DGR, EWR og Induction /Resistivity 25 Col 4882 8190 Open 7/28/2010 TVD ROP, DGR, EWR o Induction /Resistivity 25 Col 4932 8260 Open 7/28/2010 PB1 MD ROP, DGR, EWR [L'og Induction /Resistivity 25 Col 4932 8260 Open 7/28/2010 PB1 TVD ROP, DGR, EWR V' Induction /Resistivity 25 Col 4932 7833 Open 7/28/2010 PB2 MD ROP, DGR, EWR . og Induction /Resistivity 25 Col 4932 7833 Open 7/28/2010 PB2 TVD ROP, DGR, EWR og Induction /Resistivity 25 Col 4932 8180 Open 7/28/2010 PB3 MD ROP, DGR, EWR og Induction /Resistivity 25 Col 4932 8180 Open 7/28/2010 PB3 TVD ROP, DGR, EWR Log Cement Evaluation 5 Col 0 8154 Case 8/11/2010 CBL, GR, CCL • ED j.,--C Las 19985 Cement Evaluation 4496 8172 Case 8/11/2010 CBL, Ten, GR, CCL plus TIFF graphics ED Dls 20573 See Notes 4600 8100 Case Spectra Flow Log Multi SPFL DLIS data •g See Notes 25 Col 4600 8100 Case 12/27/2010 SpectraFlow, Oxygen Activation Eval jg See Notes 25 Col 4600 8144 Case 12/27/2010 SpectraFlow *FIELD* Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/21/2012 Permit to Drill 2100490 Well Name /No. KUPARUK RIV UNIT 3N -16A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21593 -01 -00 MD 8190 TVD 6478 Completion Date 7/1/2010 Completion Status SUSP Current Status 1WINJ UIC Y ADDITIONAL INFORMATION Well Cored? ¥(91 N Daily History Received? ©/ N Chips Received? •Y / N Formation Tops Y Analysis ��Ftid Received? Comments: — — Compliance Reviewed By: �� Date: ( 1 Z- r • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 29, 2010 TO: Jim Regg I (Z1 '4 P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N -16A FROM: Bob Noble KUPARUK RIV UNIT 3N -16A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Z T NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3N -16A - API Well Number: 50- 029 - 21593 -01 -00 Inspector Name: Bob Noble Insp Num: mitRCN101212161527 Permit Number: 210 -049 -0 • Inspection Date: 12/12/2010 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N -16A - Type Inj. W ' TVD l 3562 • IA 660 2040 ' 1970 1970 • P.T.D 2100490 ' TypeTest SPT Test psi 1 1500 ' OA 200 200 200 200 Interval INITAL ' p/F P , Tubing 1060 1060 1060 1060 Notes: Wednesday, December 29, 2010 Page 1 of 1 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 17, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile / Water Flow Log: 3N -16A Run Date: 12/14/2010 The technical data listed below is being submitted herewith. Please address any g Yp roblems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -16A Digital Data in DLIS /LAS format, Digital Log file, Interpretation Report 1 CD Rom 50- 029 - 21593 -01 Water Flow Log 1 Color Log 50- 029 - 21593 -01 Injection Profile Log 1 Color Log 50- 029 - 21593 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. -0q9 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wooda li b, rXon. Lam ' 25 E 47 Date: Signed: Asska c.; ay . ! • � nil 7a ft SEAN PARNELL, GOVERNOR d �J ALASKA OIL AND GAS 333 W. 71hAVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL Area Injection Order 2B.057 Mr. Martin Walters Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 3N -16A (PTD 2100490) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to inject water in the subject well. 3N -16A is a redrill of 3N -16. The new bottom -hole location was accessed by plugging the original well and exiting the production casing at about 4932' measured depth ( "md ") and drilling new hole to 8190' md. Hole problems were encountered and it was not possible to set the 5 -1/2" liner and a 3 -1/2" liner was set from 8190' - 4666' md. The liner was cemented to provide required formation isolation. The well is equipped with a 3 -1/2" tubing string that is stung into the liner top with a packer set at 4666' md. The formation is accessed via two horizontal wellbores subsequently drilled with coil tubing. The shallowest slotted liner top is at 8144' md. As constructed, 3N -16A does not meet the requirements of 20 AAC 25.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length via the casing tubing annulus for possible leakage. As constructed, nearly 3500' of this wellbore cannot be monitored. Where fresh water is not affected, 20 AAC 25.450 gives the Commission authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the Commission has exercised this discretionary authority and approved injection operations with the fluid limited to water only. AOGCC's administrative approval to continue WATER INJECTION ONLY in KRU 3N -16A is conditioned upon the following: I. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates and volumes; • A10 2B.057 October 27, 2010 Page 2 of 2 3. CPAI shall perform a water flow log after injection is initiated and stabilized to verify isolation and shall submitted results and interpretation to the Commission; 4. CPAI shall demonstrate the continued integrity of the injection string every 2 years. An MIT -T employing a deep plug set within 200' and of the shallow liner top at 8144' md, or water flow and caliper logs may be performed; 5. CPAI shall perform a mechanical integrity test of the inner annulus ( "MIT -IA ") to a minimum of 1500 psi every 2 years to demonstrate continued integrity of production casing; 6. CPAI shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 7. After well shut in due to a change in the well's mechanical condition, Coma -:+.�. approval shall be required to restart injection; DONE at Anchorage, Alaska • • • ed •c . . r 27, 2010. - ``'' ( :1 : ;;;:f.4 . mama 44/IL At ' --k-' • Daniel T. Seamo . t o `* 'o. an Cathy Pl Foerster Chair, Commissioner : missioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision. or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days alter it is filed Failure to act on it within 10 -days is a denial of reconsideration, If the Commission denies reconsideration. upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration. UNLESS the denial is by inaction. in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was tiled - if the Commission grants an application for reconsideration, this order or decision does not become final, Rather. the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distnbutes. the order or decision on reconsideration. As provided in AS 31.05,080(1:9, " [tjhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period. the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5 :00 p in on the next day that does not tall on a weekend or state holiday. • • ConocoPh ll Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 11, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 3N -16A (PTD 210 -049) to be online in water only injection service with a packer set greater than 200 feet measured depth above the top of the perforations. If you need additional information, please contact myself or Brent Rogers at 659 -7224, or MJ Loveland / Perry Klein at 659 -7043. Sincerely, Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Cc: Working Well File, Legal Well File • • ConocoPhillips Alaska, Inc. Kuparuk River Unit 3N -16AL1 (PTD# 210 -107) & 3N- 16AL1 -01 (PTD# 210 -108) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request for an exception to 20 AAC 25.412 regarding casing, cementing, and tubing of injection wells for enhanced recovery, disposal, and storage standards for Kuparuk injection well 3N -16A. Well History and Status Kuparuk River Unit well 3N-16 (PTD# 186 -091) was drilled in 1986 and completed in 1987 as a development well. 3N -16A (PTD# 210 -049) was a sidetrack of the original wellbore to allow coiled tubing access to sidetrack laterals 3N -16AL1 (PTD #210 -107) and 3N- 16AL1 -01 (PTD #210 -108). In the course of the 3N -16A sidetrack, the packer was not installed as prescribed in 20 AAC 25.412(b). During the rotary sidetrack which set up the CTD laterals, repeated attempts to run 5'/2" casing failed which would have allowed a packer to be set within 200' of the kickoff point. Ultimately a 3'12" liner was run which forced placement of the liner -top packer substantially greater than 200' away from the planned kick -off point of the CTD laterals. ConocoPhillips drilling engineers kept AOGCC staff apprised of the problems and subsequent changes in the completion plan. As directed in the permit to drill, we are requesting administrative approval to establish water injection in well 3N-16A. The following tests have been completed to date: Date Test Result Comment 08/07/10 MITT Passed Witnessed by Bob Noble 07/11/10 MITIA Passed 07/11/10 MITT Passed 05/10/10 TxIA CMIT Passed 05/07/10 MITT Passed 04/06/10 TxIA CMIT Passed 04/01/10 IC POTs Passed 10/18/08 MITOA Passed NSK Problem Well Supervisor 10/12/2010 1 • • Barrier and Hazard Evaluation Tubing: The 3 -1/2 ", 9.3 ppf, L -80 tubing has integrity to the top of the ZXP liner top packer at 4666' MD (3562' TVD) based upon a passing MITT and MITIA as outlined above. Production casing: The well is completed with 7 ", 26 ppf, J -55 casing set at 5000' MD (3752' TVD) with an internal yield pressure rating of 4980 psi. The 7" casing has integrity to the packer at 4666' MD (3562' TVD) based upon a passing MITIA as outlined above. Surface casing: The well is completed with 9 -5/8 ", 40 ppf, J -55 surface casing set at 4797' MD (3638' TVD) with an internal yield pressure rating of 3950 psi. The 9 -5/8" casing has integrity based upon a passing MITOA as outlined above. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /I /O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan P A g g 1. The well will be used for water injection only (no gas injection is allowed); 2. Perform an MITT every 2 -years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 3. The MITT must be tested against a tubing plug set as deep as possible above the uppermost liner top at 8144' MD. 4. Perform an MITIA to a minimum of 1500 psi to the existing packer @ 4666' MD. 5. Perform a water flow log after injection is initiated and stabilized to verify isolation. 6. Submit monthly reports of daily tubing & IA pressures and injection volumes; 7. Shut -in the well should MIT's or injection rates and pressures indicate problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 10/12/2010 2 • • v' if KUP 3N -16A ConoeoPhiliips '; Well Attributes Max Ang & MD TD Alaska, Inc. 1'/elibore APW al WI Field Name Weil Stes Intl P) ( MD (11%51) Act Blrn (N(e) n coeePhOpe 503292159301 KUPARUK RIVER UNIT INJ 56.10 4692.29 8,190.0 Comment H29 (ppml Dote Annotation End Data KBGrd (2) Rig Release Dale weu Cunt SN - ts . 10,11/20 0 10 127 SSSV:TRDP 140 12/152008 Last WO: 7/3/2010 39.49 520/1986 Scnemat.c• Auval Annotation Depth WS) End Date Annotation Last Mod ... End Data Last Tag: SLM 8,143.0 7/13/2010 Rev Reason: GLV C /O, CONVERT TO INJECTOR Imosbor 10/102010 L - Casing Strings MAN/ER 25 - Casing Descripron String 0... String ID .. Top IRKS) Set Depth(0... Set Depth (TVO).. SVing WL.. Stang ... String Top Thrd - 7 --- CONDUCTOR 16 15.062 37.0 115.0 115.0 I 62.50 H WELDED Casing Description Stang 0... String ID...' 109 /020) Set Depth (1... Set Depth (TVO)... String Wt.. String ... String Top Thrd SURFACE 95/8 8.765 370 4,797.5 3,635.1 36.00 J - 55 BTC Casing Description String 0... String ID... Top (2X8) Set Depth (L.. Set Depth (IVO)... String Wt.. String ... Stang Top Thrd WINDOW 'A' (Rotary) 8 6.500 4,872.0 4,882.0 3,681.4 i .s,,,.4 Casing Description String 0... String ID... Top NINE) Set Depth (0... Sol Depth (TVD) ... String Wt.. String... 'String Top Thrd _ PRODUCTION - post 7 6.151 36.8 5,000.0 3,751.5 26.00 J -55 BTC Sidetrack Casing Description String 0... SVing ID... Top IRKS) Set Depth (t... Set Depth (TVO) ... String Wt.. String... String Top Thrd LINER'A' 312 2.992 4,665.8 8,1900 9.30 L-80 IBT -Mod Liner Details 509 Dep CONDUCTOR. (NO) lop loci Nomi... 57.115 799 /229) (RKB) 1•) Item Description Comment ID (thl 4 ,665.8 3,561.5 56.06 PACKER BAKER C -2 ZXP LINER TOP PACKER 5.250 4,686.1 3,572.8 56.09 HANGER BAKER FLEXLOCK LINER HANGER 4.400 SAFETY V.v, C. 4,695.9 3,577.9 55.77 PBR • SBE 2.950 2100 4,7162 3,589.4 55.80 X0 BUSHING CROSSOVER BUSHING 2.992 4,725.0 3,594.3 55.81 NIPPLE HES'X'NIPPLE 2.813 Casing Description String 0... String ID... Top /11)03) Set Depth (t... Set Depth (TVD)._ String Wt... String.., String Top Thr4 Window 'AL1-01' 312 2.800 8,147.0 8,152.8 6,450.7 Tubing Strings Tubing Description String 0... String 10... Top NIKE) Set Depth /1... Set Depth (NO)... String Wt... String ... String Top Thrd SAS Lo- . TUBING 312 2.992 23.3 4,717.4 3,590.1 9.30 L -80 EUEBrdABMOD 5 Completion Details r ILL Top Depth 1190) Topincl `NOmi.., al Top MB) IMO) (•) Item Description Comment IID (in) 23.3 23.3 -0.01 HANGER FMC 3-1/2 Gen IV Tubing Hanger 3600 2,102.6 1,991.7 39.01 SAFETY VLV CAMCO TRMAXX -CMT SCSSV rq 2.813' X profile 2.812 ens 4 4,695.81 3,577.91 x.77 SEAL ASSY JBake x60.40 Bonded Seal Assembly 2.890 O ther In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (160) Top Intl 70912X8) M B) / 1 D00Mption Common) Run Date ID (in) " N I 8,147.0 6,446.5 42.97 Whipstock 25-deg ROHS orientation n 8252010 'Alt -01' I II I 8,170.0 6,463.3 42.97 Whipstock 10 -deg ROHS orientation 8/25/2010 LOCATOR, Ell ,'ALT 4,011° �, - di Notes: General & Safety End Date Annotation 7/32010 NOTE: WELL SIDETRACKED & NEW TUBING COMPETION SET, PRE•CTD MULTI -LAT DRILL I I J I 7/14/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemalic9.0 5EAL0,4688 55Y. 1 lt:::L) 7/14/2010 NOTE: •^•TUBING COMPLETION DEPTHS NOT CONFIRMED•"" s 9/12/2010 NOTE: DRILLED LATERALS AL1 & AL1.01 (AL7 -02 & AL1-03 NOT DRILLED) 1019120)0 NOTE: CONVERT TO INJECTOR (PRE- PRODUCED) I i I 1I SURFACE, . • 574,707 WINDOW'A' (Rotary), a 5724,592 PRODUCTION - past soma. 37 -5.500 Whipstock AL1- 01'.8.141 WOdOW 'AL1,t'. 5,1414,155 Mandrel Details Top Depth Top Port (TV0) Intl OD Valve Latch 8)25 TRO Run Stn Top IRKS) (KK 11 Make Model )in) San Type Type (In) (psi) Run Data Con... 1 3,033.6 2,607.2 52.22 CAMCO KBG -2.9 1 GAS LIFT DMY INT 0.000 0.0 10/9/2010 I I 2 4,593.7 3,521.2 55.95 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 10/9/2010 1 15T1pnb.1 ALT, 5.170 - 21569 10. 46584109 70 (3N-15A), 5.100 it KO 3N- 16T.1 -01 Co nocoPhillips Well Attributes Max Angle & MD TD A1a5ka, Inc. Wellbore APUUWI Field Name Well Status 1nc1 (') 13D («KB) Act Btm («KB) Co.... tllpa 500292159361 KUPARUK RIVER UNIT PROD 102.06 8,815.49 9,580.0 , 'Comment H2S (ppm) Date Annotation End Dale KB -Grd (ft) Rig Release Date Wee CoolO .3N- i6AL1 -Di, 103/20108:87; 17 AM SSSV: TRDP 140 12/15/2008 Last WO: 39.49 5/20/1986 Srhema6c -Ao0aI Annotation Depth («KB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: SIDETRACK, GLV CIO Imosbor 10/3/2010 - - Casing Strings HANGER, 23 L-2- -- - Casing Description String 0... String ID .., Top (RKB) Set Depth (L. Sal Depth (ND)... String Wt... String ... String Top Thrd AL1 -01 LINER 23/8 1,995 8,143.6 9,561.2 6,439.1 4.60 L -80 STL Liner Details Top Depth (ND) Top Intl Nomi... ? P Top f9KB) (RKB4 () Rem Description Comment ID (in) - 8 , 14 3.6 6,444.0 42.97 DEPLOY 2 318 Torq TWa Deployment Sleeve 1.995 Perforations & Slots shot Top (ND) Btm (ND) Dena Top (l /KB) Btm OMB) (nKB) (fIKB) Zone Dale Oh— Type Comment 8,145.0 8,176.0 6,445.0 6,466.2 UNIT B, 9/11/2010 32.0 SLOT Alternating sad/slotted pipe - CONDUCTOR, 3N- 1KAL1 -01 0,125 "x2.5" @ 4 circumferential 37 ns — " - " adjacent rows, 3' centers staggered 18 deg, 3' non - slotted ends • 8,246.0 9,558.0 6,500.4 6,439.2 A, 3N- 16AL1 -01 9/11/2010 32.0 SLOT Alternating solid /slotted pipe - 4 circumferential • SAFE Y r a adjacent ent rows, 3* en centers staggered 2,103 L 18 deg, 3' non - slotted ends Notes: General & Safety End Date Annotation 9/12/2010 NOTE: DRILLED LATERALS AL1 8 AL1 - 01 (AL1 8 AL1 NOT DRILLE GAS _lg 3834 H GAS F, 4,5°4 1117111 I-r fr..- ,, LOCATOR, 4,54'1 i SEAL ASSY, 1 }/ 4,693 4 L J 1 1 ! f • SURFACE, i 1 37.4,797 WINDOW'A' • (Rotary), 4,872 -9,892 PRODUCTION • post Sidetrack 37.5,0 00 WNpstoc 'AL1.01', 8,147 7 Wald. '-011-01', 8,1478,153 E SLOT, 8,145.817' LINER 'A 4.868-8190 Mandrel Details )I e � Top Depth Top Port ' (ND) Inc< OD Valve Latch Size TRO Run Stn Top (nKB) («1913) () Make Model (in) Sery Type Type (in) (psi) Run Dale Corn... 1 3,033.6 2,607.2 52.22 CAMCO KBG -2 -9 1 GAS LIFT GLV 114T 0.156 1,350.0 9114/2010 2 4,593.7 3,521.2 55.95 CAMCO KBMG 1 GAS LIFT 'OV BK -5 0.250 0.0 9/14/2010 SLOT, 8,2409,558 a 1 1 j At1•01 11NER, 8,1449,561 TO (3N- 18411 -01 9,580 KA) 3AL1 ConocoPhillips if- Well Attributes Max Angle & MD TD Alaska, Inc Wellbore APl /UWI Field Name Well Status !nci(3 170 (1)60) Act Btm (MB) yl � 500292159360 KUPARUK RIVER UNIT PROD 101.59 8,620.51 9,755.0 Comment 825 (ppm) Dale Annotation End Date KB.Grd (N) Rig Release Dale ,.4 Wet /Cenfi9: •JN46AL1, 10/4rj0108;$754 AM SSSV: 140 12/15/2008 Last WO: 39.49 5/20/1986 Scaemaee ACtaal _ Annotation Depth (ft146) End Dale Annotation Last Mod ... End Date Last Tag: Rev Reason: SIDETRACK, GLV C/0 Imosbor 10/3)2010 HANGER, 23 — _ — Casing Casing Strings Casing Descdption String 0... String 10... Top (RKB) Sot Depth If... Set Depth (P/0)... String Wt... String ... String Top Thrd Window 'ALI' 2.800 8,170.0 i 8,175.3 6,464.4 Casing Description String 0... String l0... Top BUM iSel Depth (f... Set Depth (010) ... String Wt... String ... String Top Thrd 75 ALI LINER Top 23/8 1.995 8,166.3 I 8,682.0 6,502.0 4.60 L -80 STL Liner Details Top Depth (TVD) Topincl Nomi... Top (MB) (RK8) (') Item Description Comment ID (in) 8,166.3 6,460.5 42.15 DEPLOY 2 3/8 Torq Thru Deployment Sleeve 1.995 cc':DUC101 R, 111 Casing Description String 0... Siring 10... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd 37 "1 ALI LINER Btrn 2 3/8 1.000 8,607.3 9,755.0 4.60 L -80 STL Liner Details Top Depth SAFETY \1V.... _._..... J (N0) Top Intl Noml... 2,103 Top INKS) (RKB) (') item Description Comment ID tin) t 8,607.3 6,516.4 101.79 WHIPSTOCK WHIPSTOCK ANCHOR BILLET 1.995 8,618.2 6,514.2 101.63 BILLET Anchored billet 1.995 8,621.5 6,513.5 101.57 DEPLOY 2 3/8 Shorty Deployment Sleeve 1.995 GAS ig334 r Perforations & Slots 1111 Shot Top (P/0) Elm (ND) Dens Top (01(6) Btm (ftKB) MB) (RK6) Zone Dale (sh• • Type Comment 8,260.0 8,579.0 6,507.5 5,502.5 A3, A -2, A -3, 9/42010 32.0 SLOT Alternating solid /slotted pipe - 3N -16AL1 0.125 "x2.5' @ 4 circumferential GAS ( 18 deg, 3' non- slotted dslaggered 1 8,523.0 9,752.0 6,513.2 6,459.8 UNIT D, A, 8/302010 32.0 SLOT Altemating solid /slotted pipe - 3N -16AL1 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered i 18 deg, 3' non - slotted ends e LOCATOR. Notes: General & Safety 4,6E0 End Dale Annotation 9/12/2010 NOTE: DRILLED LATERALS ALI 8 AL1 -01 (AL1 -02 8 AL1 -03 NOT DRILLED) 33 SEAL ASSY, 4,693 0 1 S 1 URFACE 1 274797 V✓NDOW'A' (Rotary),- - 4,872 -4,882 E1 e PRODUCTION - post Sidetrack, 373,000 Whipstock 'AL1 -01', 8,147 W bo Wodo 8,147 6853 r WISpslor2 'ALT, 8170 Window ALT. 8,1709,175 UNER'2,'. 4.6668.150 SLOT, 8,260-8,879 Mandrel Details Top Depth Top Pon (1V0) Inc! OD Valve Latch Size TRO Run Stn Top(11KB) MB) 1'1 Make Model (in) Sery Typo Type lint (psi) Run Dale Corn... 1 3,033.6 2,607.2 52.22 CAMCO KBG -2.9 1 GAS LIFT GLV INT 0.156 1,350.0 9/14/2010 2 4,593.7 3,521.2 55.95 CAMCO KBMG 1 GAS LIFT OV BK•5 0.250 0.0 9/14/2010 AL1 LINER Top, -. ` 8,1668,682 SLOT. 8,6239,752 ALt UREA 8,6079,7 , TD (3N- 16AL1). 8,755 Last Updated: 13- Sep -10 3N -16A Final CTD Schematic 3 -1/2" Camco SSSV © 2103' MD (2.813" X- profile) 3-1/2" 9.3# L -80 EUE 8rd Tubing to surface ) 3-1/2" Camco KBG2 -9 gas lift mandrel @ 3034' 3 -1/2" Camco KBMG gas lift mandrel @ 4594' Baker 80-40 seal assembly at 4696' Muleshoe @ 4727' 9 -5/8" 40# J -55 shoe @ 4803' MD -- 3-1/2" Production Liner 3 -1/2" x 7" ZXP liner top packer @ 4666" MD • 3 -1/2' x 7" liner hanger @ 4686' MD 3-1/2" PBR @' MD j 3 -1/2" X- nipple @ 4725' MD (2.813" min ID) 7" TOW @ 4882 MD % , . KOP #2 @ 8147' MD AL1 -01 TD at 9580' MD Baker 3 -1/2" monobore WS .* . 2-3/8" slottedisolid liner 8144' - 9561' Liner top at 8144' MD KOP #1 @8170'MD//i Baker 3-1/2" monobore WS AL1 TD at 9755' MD 2 -3 /8" slotted liner 8607' - 9755' Anchor - Billet at 8607' 3-1/2", 9.3 ppf, L -80 Liner Shoe @ 8190' MD ,. - • ( AL1 -PB1 TD at 9240' MD 2 -3/8" slotted /solid liner 816V - 8682' Liner top at 8166' MD • Well Name 3N -16A Notes: Start Date 11/1/2009 Days 365 End Date 11/1/2010 Annular Communication Surveillance 1600 WHP - 70 1400 - 60 1200 - 50 • 1000 vakiLr -40 .a 800 y 30 600 I — 20 400 200 — 10 0 0 Nov -09 Dec -09 Jan -10 Feb -10 Mar -10 Apr -10 May -10 Jun - Jul - Aug - Sep - Oct -10 111111111111MI U3 • - ��SWI • ,".. U • 70 5 Jul -10 Aug -10 Sep -10 Oct - Date I • in) 2/0 — 40 4 / MECHANICAL INTEGRITY REPORT • DATE.: ' � � � - 1 , 3- /O OPER l FIELD o tA(-a l l UD uf.. �u G RELEASE: • ° r -'/ L - p WELL NUMER /CJ"16 A 1 E 1 `ELL DATA TD : .3O.. TVD ; P ETA : HD 1 V 1J Casing: Shoe: TVD; DV: `i • Shoe: TVD; TOP: MD TVD Tubing: Packer IX TVD; Set at A2-0 Hole Size and ; Perfs - to — 35I • O o M . Y - P 1 .N �Cr INTEGRITY PART _ • a le e %GC ZKP Annalus Pxess Test: IP ; 15 min ; 30 min Comments: ` ®« , • MECHANICAL INTEGRITY - PART i'2 Cement Voiuvcs r .mt. Liner Gag ; DV Ith 4 4 1 9-) crrit vol co t Mir- [1 fri 7 - --7( i- _ . sue_ 4 ZSba , on•.,. 7-1 6 ' l' Theoretical TOC S'"s /7 e -- 4- A . e- s s . Aci 7 - Sao' 4 c. Cement Bond Log (Y'es or No) ; In AOCCC File • . CBI, Evaluation, on above perfs , e 607 ___/m". __7::P . ru 0 , ex.)AJ lir 0 44: a \ T Evaluation • Pr ®ductiox� Log: Type N � CONCLUSIONS: ?art # 2 : es. M . 4 f 4 1 . 4 ... Za..c... 4` AAA • - STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell f Plug Perforations r Stimulate r Other Fr. Drill out liner Rill Tubing F New Pool Waive shoe Alter Casing �` 9 � � r Ti me Extension `- Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r r 210 - 049 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50- 029 - 21593 -01 7. Property Designation 8. Well Name and Nufnber: ADL 25521, 25520 ` 3N - 16A 9. Field /Pool(s): \., Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8190 feet Plugs (measured) None true vertical 6478 feet Junk (measured) None Effective Depth measured 8157' feet Packer (measured) 4666 true vertical 6453 feet (true vertucal) 3561 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 4760 9.625 4797 3638 PRODUCTION 4963 7 5000 3752 LINER 3524 3.5 8190 6478 RE Perforation depth: Measured depth: none r,icl, 0 i ZOO True Vertical Depth: none gh &Gas Cons. Corn Tubing (size, grade, MD, and TVD) 3.5, L -80, 4717 MD, 3590 TVD ., Anthentle Packers & SSSV (type, MD, and TVD) Baker C -2 ZXP liner top pkr @ 4666' MD and 3561' TVD SAFETY VLV - CAMCO TRMAXX -CMT SCSSV w/ 2.813" X profile @ 2103 MD and 1993 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation not completed Subsequent to operation _ not completed `v.,5 •Co 13. Attachments 14. Well Class after proposed work: ■.. Copies of Logs and Surveys run Exploratory r evelopment r Service P 15. Well Status after work: Oil r Gas E WDSPL r Daily Report of Well Operations XXX GSTOR E WAG r GASINJ r WINJ\j SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -236 Contact Ga E er • 263 -4172 Printed Nam Ga Ell, Title Wells Engineer Signature Phone: 263 -4172 Date OC - o e.-i 4 2_o1a R BDMS O CT 05 211 � 2 Form 10-404 Revised 7/2009 d/5 -- /r submit Original Only 3N -16A Well Work Summary DATE SUMMARY 7/11/ 10 SET CATCHER SUB @ 4598' SL1VI, PULLED SHEARED SOV @ 4590' RKB 1D SET DV. MIT IA TO 2500 PASS ). MIT TBG. TO 2500 PSI ( PASSED ON THIRD ATTEMPT ). ATTEMPT TO DRIFT TBG. W/ 19' OF 2 5/8 DUMMY WHIPSTOCK DRIFT, TOOLS FALLING VERY SLOW © 0-15' PER MIN. ONCE INSIDE LINER. 7/13/10 TAGGED WITH BAILER @ 8143' SLM. DRIFTED TBG & LINER WITH 19' x 2 5/8" DUMMY WHIPSTOCK TO SAME; TOOLS FELL SLOWLY, 50 FPM, THROUGH TOP 200' OF LINER. COMPLETE. 7/22/10 PERFORMED CEMENT BOND LOG FROM TAG DEPTH OF 8154' TO 4500'. PERFORMED JEWLERY LOG FROM 8154' TO SURFACE. TOP OF CEMENT IN LATERAL LINER FOUND AT A DEPTH OF 5564'. 7/23/10 PRE CTD PT SV, MV,SSV ( PASSED) DDT SV, MV, SSV ( PASSED) DDT SSSV ( FAILED ) 8/7/10 (PRE -RIG) STATE WITNESSED MITT- PASSED; (ROBERT NOBLE) 8/9/10 MILL CEMENT FROM WIPER PLUG TAG @ 8177 CTMD (8157' RKB) TO 8210 CTMD (8190' RKB), FP /3500 TO SURFACE, BACK TOMORROW FOR UNDER- REAM CEMENT SHEATH, 8/10/10 Under - reamed from 8170' to 8211' CTMD. Freeze protected with diesel. Ready for SL dummy whipstock run. 8/11/10 GAUGED TBG TO 2.68" TO 8174' SLM. DRIFTED TBG WITH 19' x 2.625" DUMMY WHIPSTOCK TO 8174' SLM. COMPLETE. KUP • 3N -16A Gonoct Well Attributes Max Angle & MD TD AI 1crS,1r . n'- Wellbore APVUWI I Field Name Well Status Inc! (3 MD (ftKB) Act Btm (ftKB) ft 500292159301 KUPARUK RIVER UNIT PROD 5610 4,69229 8,1900 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Welt consg - aK 1 8�8/1ip20144450;S7 PM srnzmOCK.- hra4at SSSV TRDP I 140 12/15/2008 Last WO 7/3/2010 I 3949 5/20/1986 - - -� An notation Depth (ftKB) End Date [Annotation Last Mod .. End Date _ -.. P f 1 Last Tag: SLM 8,143.0 7/13/2010 Rev Reason: Mill Liner CMT, above Shoe Imosbor 8/10/2010 Casing Strings HANGER 23 - - - -- J Casing Description 'String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (f KB) Set Depth (E.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 37.0 4,797.5 3,635.1 36.00 J - 55 BTC I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINDOW A 8 6.500 4,8720 4,882.0 3,681.4 ;I: ,.. ,^ -: Casing De cription String 0... Strt g ID... Top (ftKB) Set Depth (f... St Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION - post 7 6.151 36.8 50000 3,751.5 26.00 J -55 BTC Sidetrack sr:_ Casing De cription String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thad LINER 31/2 2.992 4,665.6 8,190.0 9.30 L -80 IBT-Mod Liner Details — I <., _._. Top Depth __ CONDUCTOR, (TVD) P ) (•) Item Description Comment T �I Nomi... 37 -115 Top fig) ( ftK ID (in) 4,665.6 3,561.3 56.06 PACKER BAKER C -2 ZXP LINER TOP PACKER 5.250 lilt 4,685.8 3,572.6 56.09 HANGER BAKER FLEXLOCK LINER HANGER 4.400 4111 I SAFETY VLV, 4,695.6 3,577.8 55.77 PBR SBE 2.950 2,103 4,716.0 3,589.3 55.80 XO BUSHING CROSSOVER BUSHING 2.992 l 4,724.7 3,594.2 55.81 NIPPLE HES 'X' NIPPLE 2.813 8,176.2 6,467.8 42.97 MILLED CMT CEMENT MILLED TO JUST ABOVE CASING SHOE PRE -CTD 3.000 I WINDOW Tubing Strings Tubing Description String 0 String ID ... Top (ft6B) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd GAS 3.11% UFT. _..._ ,, TUBING 31/2 2992 I 23.3 I 4,71/ 4 3,590.1 9.30 L -80 EUE8rdABMOD 1 it - Completion Details Top Depth (TVD) Top Inc! Nomi... Top (MB) (ftKB) (°) Item Description Comment ID(in) 23.3 23.3 -0.01 HANGER FMC 3 -1/2" Gen IV Tubing Hanger 3.500 2,102.6 1,991.7 39.01 SAFETY VLV CAMCO TRMAXX -CMT SCSSV w/ 2.813" X profile 2.812 GAS LIFT,__, _... � �! 4,679.9 3,569.4 56.08 LOCATOR Locator NO GO _ -- 2.992 4,594 _ 4,695 8 3.5779 55 77 SEAL ASSY Baker 80-40 Bonded Seal Assembly , 2.890 _ .1 _ __ __ ,, Notes: General & Safety End Date Annotation 7/3/2010 NOTE: WELL SIDETRACKED & NEW TUBING COMPETION SET, PRE -C1 D MULTI -LAT DRILL 7/14/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9 0 7/14/2010 NOTE: " "TUBING COMPLETION DEPTHS NOT CONFIRMED` ** LOCATOR, 4,680 t l SEAL ASSY, ' ta 4,696 2=4 9 I 1 SURFACE, 37 -4,797 WINDOW 'A', 4,872 -4,882 Mandrel Details PRODUCTION Top Depth Top Port PROD - pos[S'UCTIOI,- - - - - -- (TVD) Inc' 01) Valve Latch Size TRO Run 37 -5,000 Stn Top01KB) (ftKB) (1 Make Model (in) Sery Type Type (10) (pst) Run Date Com... LINER, 1 3,033.6 2,607.2 ® CAMCO KBG -2 -9 1 GAS LIFT OMY BK -5 0.000 0.0 5/30/2010 2 4,593.7 3,521.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/11/2010 j TD (3N-16A), \,.... 8,190 8,190 Last Updated: 13- Sep -10 3N -16A Final CTD Schematic 1 3 -1/2" Camco SSSV @ 2103' MD (2.813" X- profile) Z(0 — Q 4 3-1/2" 9.3# L -80 EUE 8rd Tubing to surface 3-1/2" Camco KBG2 -9 gas lift mandrel @ 3034' 3 -1/2" Camco KBMG gas lift mandrel ©4594' Baker 80 -40 seal assembly at 4696' Muleshoe © 4727 9 -5 /8" 40# J -55 shoe • ©4803' MD 3.1/2" Production Liner j 3-1/2" x 7" ZXP liner top packer ©4666" MD 3 -112" x 7" liner hanger @ 4686' MD �— 3 -1/2" PBR @' MD 3 -1/2" X- nipple @ 4725' MD (2.813" min ID) 7" TOW @ 4882 MD :: D o D ore WS AU TD at 9755' MD 2 -3/8" slotted liner 8607' - 9755' Anchor - Billet at 8607' 3 -1/2 ", 9.3 ppf, L -80 Liner I • Shoe @ 8190' MD — ______________________________--------- 31 i' AL1 -PB1 TD at 9240' MD i N (4 "' 2 -3t8" sbtted /solid liner 8166' - 8682' .................................... " Liner top at 8166' MD I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2010 TO: Jim Regg C , P.I. Supervisor � ) Ji �'�t v SUBJECT: Mechanical Integrity Tests t I CONOCOPHILLIPS ALASKA INC 3N -16A FROM: Bob Noble KUPARUK RIV UNIT 3N -16A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry :IX- NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3N -16A API Well Number: 50- 029 - 21593 -01 -00 Inspector Name: Bob Noble Insp Num: mitRCN100809153633 Permit Number: 210 -049 -0 Inspection Date: 8/7/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-16A - Type Inj. N ' TVD 7 3562 ' IA 0 0 0 0 P.T.D 2100490 ' TypeTest SPT I Test psi 2030 - OA 150 150 150 150 T Interval OTHER p/F P ' Tubing 380 2030 = 1980 1970 Notes: MIT -T pre CTU sidetrack. Wednesday, August 11, 2010 Page 1 of 1 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 30, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 3N -16A Run Date: 7/22/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -16A Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 21593 -01 Cement Bond Log 1 Color Log 50- 029 - 21593 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton A Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. n -U Anchorage, Alaska 99518 '63 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 rafael.barretoe • Date: AUG 1 1 2010 Signed: a ®ff - e Page 1 of 1 Schwartz, Guy L (DOA) From: Greener, Mike R. [ Mike .R.Greener @conocophillips.com] Sent: Thursday, July 29, 2010 11:03 AM To: Schwartz, Guy L (DOA) Subject: current status of 3N -16A 7/29/2010 PD Z (C -0(15 Attachments: Greener Mike.vcf 3N -16A has been turned over to our coiled tubing group. The pressure test of the 3 -1/2" liner indicates a suspected liner shoe leak. Coiled tubing plan is to drill out the liner shoe joints so they can get as deep as possible to initiate their sidetrack. They will place a plug in the bottom of the liner and perform a cement bond log before they cut their window to sidetrack. Expected start date is September 2010. Mike Greener 7/29/2010 • • SITAITE ALASEA 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 Gary Eller Wells Engineer � 0 41 ConocoPhillips Alaska, Inc. hh P.O. Box 100360, V Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -16A Sundry Number: 310 -236 Dear Mr. Eller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy. Foerster Commissioner DATED this 9 of August, 2010. Encl. STATE OF ALASKA LA— VI ALASI IL AND GAS CONSERVATION COMMISS• ,b ' (� ' �► 91 APPLICATION FOR SUNDRY APPROVALS 0,X" 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill f Perforate New Pool L Repair w ell r Change Approved Program Suspend r Rug Perforations r Perforate r Pull Tubing r Tirre Extension Operational Shutdown f! Re -enter Susp. Well [- Stimulate r Alter casing ......d Other: Drill out liner shoe .7 ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developrrent r Exploratory r 210 - 049 ' 3. Address: 6. API Number: Stratigraphic f" Service P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21593 - 01 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes T No F 3N -16A 9. Property Designation: 10. Field / Pool(s): ADL 25521, 25520. Kuparuk River Field / Kuparuk River Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8190 6478 ' 8157' 6453' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115' 115' SURFACE 4760 9.625 4797' 3638' PRODUCTION 4963 7 5000' 3752' LINER 3524 3.5 8190' 6478' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5 L -80 4717 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker C -2 ZXP liner top packer 4666' MD, 3562' TVD SAFETY VLV - CAMCO TRMAXX -CMT SCSSV MD= 2103 TVD= 1993 12. Attachments: Description Summary of Proposal pr 13. Well Class after proposed work: Operations Program BO P Sketch Exploratory T Development r Service F Detailed O P 9 IT 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/5/2010 Oil fl Gas T WDSPL r Suspended F' 16. Verbal Approval: yy.— Date: p -4,-/6 WNJ r- GINJ r WAG nl Abandoned Commission Representative: �,• •- SZAto / GSTOR fl SPLUG r 17. I hereby c- ify that the foregoing 's true and correct to the best of my knowledge. Contact: Gary Eller @ 263 -4172 Printed Nam \ Gary ler Title: Wells Engineer I Signature ^ p` Phone: 263 -4172 Date 'N � Commission Use Only • Sundry Numbers o g36 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r / Mechanical Integrity Test r' Location Clearance .: : ce � � -- r E VED � Other: A, /n; I C 4.S ih 1 5 /VO l cL.L.0 �10 L a. de . : ~ 2010 Ca , Colt$. Commission Subsequent Form Required: r 0 — Yoh ,.R}t"!r.1ae APPROVED BY Approved by: L COMMISSIONER THE COMMISSION Date: -t7__-_(., Form 10 -403 Revis d 1/2 O 9 �� 0R1GINAL ��Y -4O Submit in1 uplicate aro • • Wiling 6 3N -16A Pre -CTD Sidetrack Prep ConocoPhillips Wells network: 10272798 The anticipated spud date for Nabors CDR2 -AC to drill four CTD A -sand horizontal laterals from well 3N -16A is late August 2010. Objectives: Prep well for a CTD sidetrack out the 3 liner shoe o Coil: Drill out the 3 liner shoe with a 2.80" mill o Coil: Under -ream cement sheath from the 3%2" shoe o Other: Set BPV Procedure: Shoe Drill Out Note: The primary plan in 3N -16A is to exit out the shoe of the 3%2 " liner, but back -up kick -off points exist in the 3 1 /2" liner and shoe joint. This procedure will keep all of these options open. 1. MIRU 2" or 1 CT unit. PU Weatherford 2.80" mill and BHA for drilling out the wiper plug • and landing collar at 8157' plus the 3 shoe joint down to 8190'.'Do not drill out the float shoe at 8190'. There are indications that 3N -16A had a wet shoe, so the cement below the wiper plug might be pretty junky. Recommend the following on the BHA: • 2.80" 3- blade, concave, carbide mill • 2 /s" motor • Jars & accelerator • MHA including disconnect and ball -drop circ sub 2. PU Weatherford under - reamer dressed for 3 ", 9.3 ppf tubing. Under -ream cement sheath across the shoe joint from 8140' to 8190'. 3. When finished under- reaming, drop a ball to open the circ sub. Circulate bottoms -up at max rate while POOH. Freeze protect with diesel the last 2000'. RDMO coiled tubing. 4. Set BPV. Prep site for CTD rig. August 3, 2010 Page 1 of 2 3N -16A Pre -CTD Sidetrack P • re Casing OR Tubing OR Drilling Detail Well: 3N - 16A 3.5" Intermediate Liner Date: 6/27/2010 ConocoPhillips Rig: Doyon 16 wa Depth JE Number Joints Weii Equipment Description and Comments Length Tops Page 1 Top of String or Top of Flange Crossover XT39 box x 3 -112" IF pin- Does not stay in the hole 1.51 4657.72 Baker running tool 3 -1/2" IF- Does not stay in the hole 6.60 4659.23 Baker 5 "x 7 ", L -80 "C -2" ZXP Liner Top Packer 5.25" ID 12.55' PBR 20.24 4665.83 Baker 5" x 7 ",L -80 Flexlock Liner Hanger w/ 5" BTC Pin Down 9.84 4686.07 TKC Couplings w/ Seal Bore Extension 5" BTC Box x Pin 20.33 4695 91 Crossover Bushing 5" BTC Pin x 3 1/2" EUE Pin .47 4716.24 Pup Joint 3 1/2" EUE Box EUE Pin 8.25 4716.71 3 1/2" "X" Nipple EUE Box x Pin 2.81" 1.13 4724.97 Crossover Pup Joint 3 1/2" EUE Box x IBT Pin 1.73 4726.10 Jts 1 to 110 110 Jts 3 1/2" IBT Mod SCC 3428.94 4727.83 Baker Landing Collar Type I 1.14 8156.77 HES Float Collar 3 -1/2" IBT Box x IBT Pin (4.23" O.D.) 1.28 8157.91 3 1/2" IBT Mod 9.3# L -80 Collar OD = 3.87" 29.03 8159.19 V -Set Float Shoe 3 -1/2" IBT Box (4.25" O.D.) 1.78 8188.22 Bottom of Shoe = ___ >%= 8190.00 8190.00 8190.00 8190.00 Run 1 - 3 1/2" x 5 3/4" Spiral Rigid Centralizer on each joint "floating" 8190.00 from Jnt# 3 - Jnts# 102 8190.00 8190.00 8190.00 Total Centralizers here = 116. 8190.00 Total Centralizers ran = 99 8190.00 100 Extra Seal Rings in Pipe Shed. 8190.00 2- Bowspring Centralizers on the shoe joint and 1 installed above the LC. 8190.00 8190.00 7 ",26 #, J -55 BTC window A 4,882' MD / 3,682' TVD ( 6.276" I.D.) 8190.00 Top of liner (ti? 4666' MD/3570' TVD (56.1 Deg) 8190.00 Liner Lap = 212' 8190.00 Drilled to 8190' MD (6475' TVD) (42 Deg) 8190.00 8190.00 8190.00 8190.00 8190.00 Remarks. Torqued IBTC Mod Casing 0 2400 Ft -la Up Wt On Wt K Block Wt 40 K Supervisors: Scott Heim .1 Dinh Helm August 3, 2010 Page 2 of 2 Il KU Y P 3N -16A • C011CK0 [Y ilhip5 I ° Attributes Max Angle & MD TD Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Aiiasta,lw ca ><..vTimp. 500292159301 KUPARUK RIVER UNIT PROD 56.10 4,692.29 8,190.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• WelICOnflg: - 3N 16A,7/15/20101056:23 AM SSSV: TRDP 140 12/15/2008 Last WO: 7/3/2010 39.49 5/20/1986 Schematk - Actual Annotation Depth (ft813) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,143.0 7/ 13/ 2010 Rev Reason: WORKOVER, SIDETRACK Imosbor 7/14/2010 Casing Strings I t HANGER, 23 Casing Description String 0... String ID ... Top (ftKB) Set Depth (T... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 115.0 115.0 62.50 H WELDED Casing Description g String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 37.0 4,797.5 3,635.1 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd - s WINDOW'A' 8 6.500 4,872.0 4,882.0 3,681.4 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION - post 7 6.151 36.8 5,000.0 3,751.5 26.00 J -55 BTC Sidetrack Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 4,665.8 8,190.0 9.30 L-80 IBT -Mod Liner Details Top Depth (TVD) Top Inc' Nomi... CONDUCTOR,^ Top (ftKB) (ftKB) (°) Item Description Comment 10 (in) 3T - 115 - 4,665.8 3,561.5 56.06 PACKER BAKER C -2 ZXP LINER TOP PACKER 5.250 _ 4,686.1 3,572.8 56.09 HANGER BAKER FLEXLOCK LINER HANGER 4.400 4,695.9 3,577.9 55.77 PBR SBE 2.950 4,7162 3,589.4 55.80 XO BUSHING CROSSOVER BUSHING 2.992 SAFETY VLV, 2,103 1' 4,725.0 3,594.3 55.81 NIPPLE HES')CNIPPLE 2.813 Or 8,156.8 6,453.6 42.97 COLLAR BAKER LANDING COLLAR 2.950 8,159.2 6,455.4 42.97 COLLAR 2.992 a l l Tubing Strings Tubing Description String 0 .. String ID ... Top (ftKB) S Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd TUBING I 31/2 2.992 23.3 I et 4,717.4 3,590.1 I 9.30 L -80 EUE8rdABMOD GAS LIFT Completion Details 3.034 Top Depth all (TVD) Top Inc! Noml... Top (ftKB) (ftKB) (°) Kem Description Comment ID (in) 23.3 23.3 -0.01 HANGER FMC 3-1/2' Gen IV Tubing Hange 3.500 2,102.6 1,991.7 39.01 SAFETY VLV 'CAMCO TRMAXX -CMT SCSSV w/ 2.813" X profile 2.812 4,679.9 3,569.4 56.08 LOCATOR Locator NO_GO 2.992 4,695.8 3,577.9 55.77 SEAL ASSY Baker 80-40 Bonded Seal Assembly 2.890 GAS LIFT 4.594 Notes: General & Safety End Date Annotation I I 7/3/2010 NOTE: WELL SIDETRACKED & NEW TUBING COMPETION SET, PRE -CTD MULTI -LAT DRILL 7/14/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematc9.0 7/14/2010 NOTE: ""TUBING COMPLETION DEPTHS NOT CONFIRMED'"" LOCATOR, IR 4,680 • 1.._..1 SEAL ASSY, 4,896 1 1 I I .. SURFACE, A • 37 -4,797 WINDOW 'A', vs 4,872-4,882 Mandrel Details Top Depth Top Port PRODUCTION (TVD) Incl OD Valve Latch Size TRO Run - post Sidetrack. Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery TYPe Type (in) (Pei) Run Date Com... 37 1 3,033.6 2,6072 52.22 . CAMCO KBG -2 -9 1 GAS LIFT DMY BK -5 0.000 0.0 5/30/2010 2 4,593.7 3,5212 55.95 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 7/11/2010 LINER, 4,6668,190 TD (3N -16A). 8,190 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 06, 2010 11:08 AM To: 'Eller, J Gary' Cc: Foerster, Catherine P (DOA) Subject: RE: Verbal Approval of 10-403 on 3N -16A Gary, You have verbal approval to execute the work scope of 10-403 sundry (310 -236). As stated below the scope includes drilling out and underreaming the shoe track with service Coil tubing but does not authorize anything deeper past the float shoe into the OH. Hopefully the MIT on the liner will go as planned also. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Eller, J Gary [ mailto: J.Gary.Eller @conocophillips.com] Sent: Friday, August 06, 2010 11:00 AM To: Schwartz, Guy L (DOA) Subject: Verbal Approval of 10 -403 on 3N -16A Guy — Greetings! Since we're heading into the weekend, I wanted to see if 1 can get verbal approval on the 10- 403 I submitted to drill out the 3 %" shoe track of KRU 3N -16A. Good chance we'll get that started this weekend, but we won't do so until we get the State - witnessed MIT -T under our belt. That's scheduled to happen today or tomorrow. Sound OK? 1 Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907 - 263 -4172 cell: 907 - 529 -1979 fax: 907 - 265 -1535 8/6/2010 • • WELL LOG TRANSMITTAL To: State of Alaska July 13, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: LWD Logs: 3N- 16A +PB1 +PB2 +PB3 AK -MW- 0007142377 3N -16A 50- 029 - 21593 -01 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 3N -16A PB1 50- 029 - 21593 -70 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 3N -16A PB2 50- 029 - 21593 -71 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 3N -16A PB3 50- 029 - 21593 -72 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. o (j' Anchorage, Alaska 99518 010 - 9gda Office: 907 -273 -3536 Fax: 907 - 273 -3535 Bryan.Burinda@hdlihurton.com RECEIVED Date: 1 ;;; Signed: J !. a Cif & Gas Coo. Ceram" s' Anchorage P • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION a ❑ ❑ h a OR RECO ❑ MPLETIO u Nended Well PORT AND LOG la. Well Status: oil ❑ 20AAC 25.105 20AAC 25.110 ,go') Development ❑ Exploratory ❑ GINJ ❑ WINJ WAG ❑ WDSPL ❑ No. of Completions: 1 Oa 'I I1 Service El Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: July 1, 2010 210 - 0490 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 20, 2010 50 029 - 21593 - 01 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1561' FSL, 30' FEL, Sec. 29, T13N, R9E, UM June 27, 2010 3N - 16A Top of Productive Horizon: 8. KB (ft above MSL): 60' RKB 15. Field /Pool(s): 568' FNL, 2019' FEL, Sec. 33, T13N, R9E, UM GL (ft above MSL): 34' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 573' FNL, 1925' FEL, Sec. 33, T13N, R9E, UM 8157' MD / 6453' 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 518371 y 6013799 Zone 4 8190' MD / 6478' TVD ADL 25521, 25520 TPI: x - 521672 y - 6011679 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 521767 y 6011675 Zone 4 2103' MD / 1992' TVD 2560 18. Directional Survey: Yes Q No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700' MD / 1700' 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 4882' MD / 3682' 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. 115' Surf. 115' 24" 249 sx CS II 9.625" 36# J -55 Surf. 4797' Surf. 3638' 12.25" 1350 sx AS III, 350 sx Class G 7" 26.0# J -55 Surf. 5000' Surf. 3752' 8.5" 300 sx Class G, 175 sx AS 1 3.5" 9.3# L -80 4666' 8190' 3570' 6478' 7" 600 sx Class G 24. Open to production or injection? Yes ❑ No Ei 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" 4717' 4666' MD / 3562' TVD perfs not completed yet / / C� si 4-- " �o ba/G ,,,� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. C - / /f COMpL�O . DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4 1M2l i eyement retainer @ 4900' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable waiting on completion rig Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 2 . IVED NONE JUL 2 7 2010 RBDMS JUL 2 71010. *m Alaska Dil & Gas Carta. Commission Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and markerssuntered): 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 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C sand 8051' 6376' 3N- 16APB1 TD 8260' 6478' N/A 3N- 16APB2 TD 7833' 6249' 3N- 16APB3 TD 8180' 6472' Formation at total depth: Kuparuk C 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: , eener @ 263 - 4820 • Printed Name / Alvord Title: Alaska Drilling Manager - 7 /Z� ry Signature . • Ll ( (Z . Phone 265 - 6120 Date 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 f w KUP 3N -16A � Phil$i Ws11 A4tributes Max Angle & MD TD Aiasica. lc Wellborn APYUWI Field Name Well Status Inc! (') MD (9013) Act Btm (ftKB) - - 500292159301 KUPARUK RIVER UNIT I PROD 56 10 4,692 29 8,190.0 `""` Comment 'H25 (ppm) Date An olalion End Date KB -Gad (ft) Rig Release Dab Las SSSV IRDP 140 12/15/2008 t WO' 7/3/2010 39.49 5/20/1986 .l.X„} ..7�1` . k 23 AM _ - ___ Sohernedc AoWei .. Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag. SLM 8,143.0 7/13/2010 Rev Reason WORKOVER, SIDETRACK Imosbor 7/14/2010 a Casing Strings t HANGER. 23 - - - - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String _. String Top Thrd CONDUCTOR 15.062 37.0 115.0 115.0 62.50 H-40 WELDED -- -.. Casing Description String 0... String ID... Top (MB) Set Depth (f.. Set Depth (TVD) .. String Wt... String ... String Top ThN SURFACE 9 5/8 8.765 37.0 4,797.5 3,635.1 36.00 J - 55 BTC ' . Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thad WINDOW'A' 8 6.500 4,872.0 4,882.0 3,681.4 p Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ;'/iTT PRODUCTION - post 7 6.151 36.8 5,000.0 3,751.5 26.00 J -55 BTC 1 Sidetrack Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 3 1/2 2.992 4,665.8 8,190 0 9 30 L-80 IBT-Mod Liner Details _ sr s a 'ef )_',- rte' Top Depth (TVD) Top lml Komi... CONDUCTOR, Top (ftKB) (ftKB) ("1 Item Description CPmment ID(in) 37 - 11s 4,665.8 3,561.5 56.06 PACKER BAKER C-2 ZXP LINER TOP PACKER 5.250 4,686.1 3,572.8 56.09 HANGER BAKER FLEXLOCK LINER HANGER 4.400 4,695.9 3,577.9 5 PBR SBE 2.950 4,716.2 3,589.4 55.80 XO BUSHING CROSSOVER BUSHING 2.992 SAFETY VLV, 2,103 — 4,725.0 3,594 3 55 81 NIPPLE HES 'X' NIPPLE 2.813 8,156.8 6,453.6 42.97 COLLAR r BAKER LANDING COLLAR 2.950 , , . 8,159.2 6,455.4 42.97 COLLAR _ - - -- 2.992 7 Tubing Strings Tubing Description Str ng O . Str g ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . Str g Wt... , String Stri g Top Thrd l UBING __ - 3 1/2 2.992 23 3 4,717 4 3 590.1 I 9 30 d L-80 EUE8rdABMOD GAS UET, Completion Details _ 3,034 Top Depth (TVD) Top Inc/ Nomi... Top (8KB) (ftKB) C) Item Description _. - ._ Comment - .. - ID(in) 23.3 23.3 -0.01 HANGER FMC 3-1/2" Gen IV Tubing Hanger 3.500 2,102.6 1,991.7 39.01 SAFETY VLV CAMCO TRMAXX -CMT SCSSV w/ 2.813" X profile 2.812 4,679.9 3,569.4 56.08 LOCATOR Locator NO_GO 2.992 3,577.9 55 77 SEAL ASSY Baker 80 -46 Bonded Seal Assembly 2.890 GAS LIFT. 4,594 - ' Note a,6ss. s: General &Safety ,. Date Annotation 7/3/2010 NOTE: WELL SIDETRACKED & NEW TUBING COMPETION SET, PRE -CTD MULTI -LAT DRILL 7/14/2010 NOTE' VIEW SCHEMATIC w /Alaska Schematic9.0 I 7/14/2010 NOTE: " "" "TUBING COMPLETION DEPTHS NOT CONFIRMED***** I 1 LOCATOR, 4,680 1 '1 N l „ I _lI SEAL ASSY, -...- 4,696 �' NOM n' I I' 1 / 1 I 1 " SURFACE, • 37-4,797 WINDOW 'A', 4,872 -4,882 Mandrel Details — __ Top Depth Top __. .._ Pod PRODUCTION (TVD) Inc/ OD Valve Latch Size TRO Run - post Sidetrack, _______ Stn Top (ftKB) (ftKB) (1 Kelm Model NO Sew TYpe Type (i0 (Psi) Run Date Co..... 37 - 5,000 1 3,033.6 2,607.2 52.22 CAMCO KBG -2 -9 1 GAS LIFT DMY 1310-5 0.000 0.0 5/30/2010 2 4,593.7 3,521.2 55.95 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/11/2010 l LINER, 4,668 -8,190 TO (3N -18A), i 11 8,190 3N -16A Pre and Post Rig Summary DATE SUMMARY 3/21/10 TAGGED TD @ 8953' SLM ( EST. 1' OF RAT HOLE / OBTAINED SAMPLE). ST 2.25 CA -2 PLUG W/ DUAL PANEX GAUGES ( 173.5" OAL) @ 8841' RKB. (( NOTE: NEED SHORT AXELSON FUSIBLE CAP )). 4/1/10 (PR) IC -POT - PASSED. IC -PPPOT - PASSED. FUNCTION TEST LDS's. 4/2/10 MEASURED BHP @ 8800' RKB: 2034 PSI. SET 2.29" CATCHER @ 8832' SLM. BRUSHED & FLUSHED TBG TO 8810' SLM. IN PROGRESS. 4/3/10 PULLED CVs @ 8811', 8739' RKB. REPLACED WITH DVs. IN PROGRESS. 4/4/10 PULLED CV @ 8671' RKB, REPLACED WITH DV. ATTEMPTED PULL GLV @ 7857' RKB. IN PROGRESS. 4/5/10 PULLED GLVs @ 7857', 7048', 5020', 2502' RKB. SET DVs @ 2502', 5020' RKB. IN PROGRESS. 4/6/10 SET 1" DV'S @ 7048', 7857' RKB, PULL 1.5" OV @8579' RKB, LOAD I/A W/ 300 BBLS DIESAL, PERFORM GOOD CMIT TO 2500 PSI. JOB IN PROGRESS 4/7/10 BAIL SAND FROM 8826' SLM TO 8832' SLM TO GET TO CATCHER SUB. JOB IN PROGRESS 4/8/10 PULL CATCHER SUB @ 8832' SLM, BAIL TO 2.25" CA -2 PLUG, LATCH PRONG IN 2.25" CA -2 PLUG @ 8836' SLM, UNABLE TO PULL OR SHEAR OFF AFTER COUPLE HOURS OF JARRING, HAD TO DROP CUTTER BAR, POOH W/ ALL WIRE. JOB IN PROGRESS. 4/9/10 PULL CUTTER W/ STEM @ 8800' SLM, RUN 2" LIB, GOOD IMP OF CLEAN ROPE SOCKET. JOB IN PROGRESS 4/10/10 ATTEMPT TO FISH TOOLSTRING @ 8788' SLM W/ 2" RB & RS, LATCH A 2" 52 GO W/ 2.5" G BAIT SUB TO F/N ON TOOLSTRING. JOB IN PROGRESS 4/11/10 FISH 1.5" TOOLSTRING W/ CA -2 PRONG, ATTEMPT TO PULL 2.25" CA2 PLUG. JOB IN PROGRESS 4/13/10 PULLED CA -2 w/ DUAL PANEX GAUGES @ 8841' RKB. A -ONLY BHP @ 8841' = 2049 PSI. COMPLETE. 4/25/10 PULLED C SAND DVs @ 8811', 8739', 8671' RKB. READY FOR E/L SET RETAINER. 4/29/10 SET WEATHERFORD 2 7/8" CEMENT RETAINER AT A DEPTH OF 8656'. CCL STOP DEPTH AT 8642.2'. CCL TO MID ELEMENT OFF SET AT 13.83'. 5/3/10 PERFORMED WEEKLY BOPE -TEST. PERFORMED CT CEMENT SQUEEZE PUMPING TOTAL OF 30 -BBL CL 'G' CEMENT: 22 -BBL THROUGH CEMENT RETAINER AT 8656'; 6 -BBL CEMENT INTO IA THROUGH OPEN POCKET AT 8579'; AND 2 -BBL CMT IN TUBING ON TOP OF RETAINER. DURING SQUEEZE AT RETAINER, STARTED BUILDING PRESSURE AT 12 -BBL AWAY AND REACHED 1500 -PSI SQ.PRESS. AT 15 -BBL AWAY: ESTIMATE 6 -BBL OUT PERFS. ESTIMATE TOP OF CEMENT AT 8400' IN TUBING. FREEZE - PROTECTED TUBING TO 3500' MD. [CEMENT REPORT SAVED AS ATTACHMENT.] ** *Note: AOGCC rep. Jeff Jones waived State Witness of the cement plug over the telephoone at 13:30 -hrs on 30Apr10. * ** 5/6/10 TA CEMENT PI UG SLM IRS TO PERFORM MITT TO 2500 #. IN PROGRESS. 5/7/10 PERFORMED MITT. RESULTS CHARTED. PASSED. LOCATED GLM #7 @ 8214' SLM WITH 2.5" OK -1 ZEROED @ FINGER. ATTEMPT TO CUT TBG @ 8255' RKB. SLB E -FIRE TOOL DID NOT DETONATE. TOOL APPEARED TO BE FLOODED. IN PROGRESS. 5/8/10 ATTEMPT TO CUT TBG @ 8254' RKB. DATA FROM E -FIRE TOOL INDICATES ARMING & FIRE SEQUENCE NEVER INITIATED. IN PROGRESS. 5/9/10 RAN SLB 2.125" JET CUTTER ON E -FIRE TOOL & CUT TBG @ 8255' RKB. DHD CREW TO VERIFY COMMUNICATION IN THE AM. 5/10/10 CMIT- T X IA POST TUBING CUT ( PASSED ) 7/11/10 SET CATCHER SUB @ 4598' SLM, PULLED SHEARED SOV @ 4590' RKB AND SET DV. MIT IA TO 2500 ( PASS ). MIT TBG. TO 2500 PSI ( PASSED ON THIRD ATTEMPT ). ATTEMPT TO DRIFT TBG. W/ 19' OF 2 5/8 DUMMY WHIPSTOCK DRIFT, TOOLS FALLING VERY SLOW @ 0 -15' PER MIN. ONCE INSIDE LINER. 7/13/10 TAGGED WITH BAILER @ 8143' SLM. DRIFTED TBG & LINER WITH 19' x 2 5/8" DUMMY WHIPSTOCK TO SAME; TOOLS FELL SLOWLY, 50 FPM THROUGH TOP 200' OF LINER. COMPLETE. • • Conoc ©Phillips Time Log & Summary Wellview Web Reporting Report Well Name: 3N - 16 Rig Name: DOYON 16 Job Type: DRILLING SIDETRACK Rig Accept: 5/16/2010 12:01:00 AM Rig Release: 7/2/2010 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/14/2010 24 hr Summary PJSM, Rig down floor equipment, rig down compnsators, bridal up derrick, PJSM, lay down derrick w/ 340k max weight on indicator, secure derrick, raise cellar doors, PJSM, move rig 20' off well, heard loud pop, stop and inspect moving system. Cover of the front axle on the off driller's side (inside tire) broken. Set rig down on mats.PJSM, Remove front axle cover plate, inspect planetary gears. Plug lines, trim axle. Con't to move off of 2L -310 well and stage rig on the level pad. Pull BOP's from rig and install in traveling skid. Install rear booster wheels. Clean up equipment in cellar area and behind well 2L -310. Move rig from 2L pad to 2G pad road at midnight. Note: 12.5 miles moved today, avg 1 -1/4 mile per hour. 00:00 00:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on preparing floor to lay down derrick. 00:15 01:00 0.75 MIRU MOVE RURD P Rig down floor equipment, rig down compensators. Bridal up the traveling blocks. Move surface stack in the cellar. 01:00 01:30 0.50 MIRU MOVE SFTY P PJSM on lowering derrick. 01:30 01:45 0.25 MIRU MOVE RURD P Lower derrick. Final weight before on rack 340k. Lowered 0135 to 0141 hrs. Secure derrick. 01:45 02:15 0.50 MIRU MOVE RURD P Raise cellar doors. 02:15 02:30 0.25 MIRU MOVE SFTY P PJSM 02:30 02:45 0.25 MIRU MOVE MOB P Move rig off well about 20'. Heard a loud pop. Stop and inspect moving system. Cover on the inside tire- Off Driller's side, had 4 sheared bolt heads. 02:45 03:45 1.00 MIRU RIGMNT RURD T Lay mats and shim material to set rig down on pad. Set rig down. 03:45 04:00 0.25 MIRU RIGMNT SFTY T Pre job safety meeting. 04:00 10:00 6.00 MIRU RIGMNT RGRP T Trouble shoot moving system problem: Remove cover plate f/ the axle to inspect axle. Trim axle with torch. Plug lines. Inspect planetarty gears. 10:00 10:30 0.50 MIRU MOVE MOB P Continue to move off well to level part of pad. 10:30 11:00 0.50 MIRU MOVE RURD P Remove BOP's from cellar, install on traveling skid.. 11:00 13:00 2.00 MIRU MOVE RURD P Install rear boosters for moving system. 13:00 14:00 1.00 MIRU MOVE MOB P Move to end of 2L pad, prep to move off pad. Page 1 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 00:00 10.00 MIRU MOVE MOB P Move from 2L pad to 2G road /Spine road. Note: 12.5 miles moved today, avg 1 -1/4 mile per hour. Note: Rig was released f/ 2L -310 @ 2359 hrs 5/13/2010. 05/15/2010 Move from 2G road /Spine road. to Oiltok Road/ IQ pad wide spot in the road. Wait on CFP3 and STP crew change out. Take on a little water f/ boilers. Continue to move Rig f/ Oiltok Road/ IQ pad wide spot in the road to 3N pad. Preparing 3N -16A well w/ secondary containment and matting boards. Stage equipment behind cellar area. Prepare rig for removing rear boosters, install BOP in cellar. Install safety cables on tugger lines in crown of derrick. Preparing 3N -16A well w/ secondary containment and matting boards. Install tugger safety lines, install cellar doors. Move rig over the hole (3N -16A). Double mat, shim rig. Vlave shop pull VR plug in the IA valve. Pre job safety meeting on raising and pinning derrick. Raise and pin the derrick. Remove bridal lines. Rig up floor. Double valve the 7" x 2 -7/8" annulus. Start putting a truck load (290 bbls) of seawater in the pits. Rig up to pull the FMC back pressure valve w/ lubricator. Pits, pump and 3516 engine comming from 2N pad. Note: OA has 100 psi, IA 20 psi, after pulling back pressure valve: tubing on vacuum. Note Rig floor to upper LDS= 23.23', Rig floor to lower lock down screws 25.10, Ground level 26.18'. Original tally upper LDS was noted at 35.00'. 00:00 05:15 5.25 MIRU MOVE MOB P Move from 2G road /Spine road. to Oiltok Road/ IQ pad wide spot in the road. 05:15 06:30 1.25 MIRU MOVE OTHR P Wait on CFP3 and STP crew change out. Take on a little water f/ boilers. 06:30 11:00 4.50 MIRU MOVE MOB P Continue to move Rig f/ Oiltok Road/ IQ pad wide spot in the road to 3N pad. Preparing 3N -16A well w/ secondary containment and matting boards. Stage equipment behind cellar area. 11:00 13:00 2.00 MIRU MOVE RURD P Prepare rig for removing rear boosters, install BOP in cellar. Install safety cables on tugger lines in crown of derrick. Preparing 3N -16A well w/ secondary containment and matting boards. 13:00 16:00 3.00 MIRU MOVE RURD P Install tugger safety lines, install cellar doors. 16:00 19:00 3.00 MIRU MOVE MOB P Move rig over the hole (3N -16A). Double mat, shim rig. Vlave shop pull VR plug in the IA valve. 19:00 19:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on raising and pinning derrick. 19:15 20:00 0.75 MIRU MOVE RURD P Raise and pin the derrick. 20:00 23:00 3.00 MIRU MOVE RURD P Remove bridal lines. Rig up floor. Double valve the 7" x 2 -7/8" annulus. Page 2 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 MIRU MOVE RURD P Start putting a truck load (290 bbls) of seawater in the pits. Rig up to pull the FMC back pressure valve w/ lubricator. Pits, pump and 3516 engine comming from 2N pad. Note: OA has 100 psi, IA 20 psi, after pulling back pressure valve: tubing on vacuum. Note Rig floor to upper LDS= 23.23', Rig floor to lower lock down screws 25.10, Ground level 26.18'. Original tally upper LDS was noted at 35.00'. 05/16/2010 Pull the FMC back pressure valve w/ lubricator. Pits, pump and 3516 engine comming from 2N pad. Note: OA has 100 psi, IA 20 psi, after pulling back pressure valve: tubing on vacuum. Note Rig floor to upper LDS= 23.23', Rig floor to lower lock down screws 25.10, Ground level 26.18'. Original tally upper LDS was noted at 35.00'. Rig accepted 0001 hrs 5/ 16/2010. RD the lubricator. RU bleed tank, choke skid, hard lines. RU circ lines & hard line to bleed tank. Con't to take on 8.5 ppg seawater to the pits. Press test lines w/ air to 120 psi. Test lines to 2500 psi w/ mud pump - OK. PJSM on circ seawater. Pump 320 bbls sewater dnwn tiihin0 taking frpp7P prntert fluid to hiaAd tank Pumping 1.5 bpm, preesured to 1200 psi then broke back to 990 psi, increased rate to 3 bpm w/ 1600 psi, watching press f/ 65 bbls total, then increased to 4 bpm w/ 1800 psi to 2300 psi. Shut down after 320 bbls pumped. Strapped tank— 320 bbls gain. Blow down lines to the tank. AES vac truck suck off the fluid from the tank. Pump down the 7" x 2 -7/8" ann taking returns up the tubing. Pump 4 bpm w/ 1900 psi. Pump 40 bbls seawater w/ a drum of Safe Surf 0, followed w/ 320 bbls of 8.5 ppg seawater. Press on the OA increased a total of 20 psi. Install FMC BPV, bleed off control line press & tubing hanger void. Check SBMS port for pressure. ND FMC 2- 9/16" tree and 7- 1/16" 5m x adapter.,Prep wellhead, install blanking plug, Function LDS on the tubing head. NU 13 5/8" x 7- 1/16" 5m adapter spool, 13 -5/8" Hydril BOP stack (Hydril GK annular, 2 -7/8" x 5" VBR (top), blinds, 3 -1/2" x 6" VBR (bottom). Change bottom pipe rams from 3 -1/2" x 6 to 2 -7/8" x 5 ". Change back to 3 -1/2" x 6 ". Not enough above the blanking plug to test lower pipe rams. AOGCC inspector Bob Noble gave waiver to test lower pipe after 2 -7/8" tubing is pulled. Test BOPE to 250 psi low and 3500 psi high. Annular to 250/2500 psi. Gas alarms tested. Witness of tests waived by AOGCC inspector Bob Noble. 00:00 01:00 1.00 SLOT WHDBO OTHR P Pull the FMC back pressure valve w/ lubricator. Pits, pump and 3516 engine comming from 2N pad. Note: OA has 100 psi, IA 20 psi, after pulling back pressure valve: tubing on vacuum. Note Rig floor to upper LDS= 23.23', Rig floor to lower lock down screws 25.10, Ground level 26.18'. Original tally upper LDS was noted at 35.00'. Rig accepted 0001 hrs 5/ 16/2010. Rig down the lubricator. Rigging up bleed tank, choke skid and hard lines. 01:00 03:00 2.00 SLOT DRILL RURD P Rig up circulating lines and hard line to bleed tank (Rain f/ Rent 500 bbl). Continue to take on 8.5 ppg seawater to the pits. 03:00 03:30 0.50 SLOT DRILL PRTS P Pressure test lines w/ air to 120 psi. Change out froze hose. Re pressure to 120 psi to the tank. Test lines to 2500 psi w/ mud pump- OK. 03:30 03:45 0.25 SLOT DRILL SFTY P Pre job safety meeting on circulating seawater. Page 3 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 05:45 2.00 SLOT DRILL CIRC P Pump 320 bbls sewater down tubing taking freeze protect fluid to bleed tank. Pumping 1.5 bpm, preesured to 1200 psi then broke back to 990 psi, increased rate to 3 bpm w/ 1600 psi, watching pressure f/ 65 bbls total, then increased to 4 bpm w/ 1800 psi to 2300 psi. Shut down after 320 bbls pumped. Strapped tank— 320 bbls gain. 05:45 06:45 1.00 SLOT DRILL OTHR P Blow down lines to the tank. AES vac truck suck off the fluid from the Rain f/ Rent tank. 06:45 09:00 2.25 SLOT DRILL CIRC P Pump down the 7" x 2 -7/8" annulus taking returns up the tubing. Pump 4 bpm w/ 1900 psi. Pump 40 bbls seawater w/ a drum of Safe Surf 0, followed w/ 320 bbls of 8.5 ppg seawater. Pressure on the OA increased a total of 20 psi. 09:00 10:00 1.00 SLOT WHDBO OTHR P Install FMC BPV, bleed of control line pressue and tubing hanger void. Check SBMS port for pressure. 10:00 13:00 3.00 SLOT WHDBO NUND P Nipple down FMC 2- 9/16" tree and 7- 1/16" 5m x adapter. 13:00 14:00 1.00 SLOT WHDBO OTHR P Prep wellhead, remove seized up studs, check and install blanking plug, Function lock down screws on the tubing head. 14:00 16:30 2.50 SLOT WHDBO NUND P Nipple up 13 5/8" x 7- 1/16" 5m adapter spool, then the 13 -5/8" Hydril BOP stack (Hydril GK annular, 2 -7/8" x 5" VBR (top), blinds, 3 -1/2" x 6" VBR (bottom). 16:30 18:30 2.00 SLOT WHDBO NUND P Change bottom pipe rams from 3 -1/2" x 6 to 2 -7/8" x 5 ". Change back to 3 -1/2" x 6 ". Not enough above the blanking plug to test lower pipe rams. AOGCC inspector Bob Noble gave waiver to test lower pipe after 2 -7/8" tubing is pulled. 18:30 19:30 1.00 SLOT WHDBO BOPE P Rig up to test BOPE. 19:30 00:00 4.50 SLOT WHDBO BOPE P Test BOPE. Gas alarms tested. Witness of tests waived by AOGCC inspector Bob Noble. Test upper pipe rams (2 -7/8" x 5" VBR) and all valves on the choke manifold, kill line, choke line and mud line to the kill line to 250 psi low and 3500 psi, hold each test f/ 5 minutes, chart all tests. Test top drive IBOP manual and automatic to 250 psi low and 3500 psi high. Tested floor safety valve and IBOP to 250 psi low and 3500 psi high. Tested the accumulator. Tested the annular to 250 psi low and 2500 psi high. Page 4 of 58 Time Logs Date - From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/17/2010 24 hr Summary Finish testing BOPE. Witness of tests waived by AOGCC inspector Bob Noble. Test upper pipe rams (2 -7/8" x 5" VBR) and all valves on the choke manifold, kill line, choke line and mud line to the kill line to 250 psi low and 3500 psi, hold each test f/ 5 minutes, chart all tests. Test top drive IBOP manual and automatic to 250 psi low and 3500 psi high. Tested floor safety valve and IBOP to 250 psi low and 3500 psi high. Tested the accumulator. Tested the annular to 250 psi low and 2500 psi high. RD testing equipemnt, blow down choke and kill lines. Back out FMC blanking plug. RU to pull tubing. Screw into the hanger 9 rounds and 5000 ft lbs of torque. Back out LDS's on the tubing hanger. PU on hanger, Pull to 87k with 2' 6" of movement at the rotary table. Continue to pull with free movement at 87k to 85k. Lay down FMC (.5' length) 6.98" OD hanger w/ 3.59' pup PxP below hanger. Lay down Joint of 4" drill pipe. RU to circulate. Circulate 800 bbls while loading 4" drill pipe into the pipe shed. RU spooler for the control line. Monitor well- static. Pump a 15 bl dry job., blow down circ lines. LD a 16.45' pup under the hanger, then 56 joints of 2 -1/8" 6.5 ppf J -55 tubing from 8252' to 6480'. LD Baker FVL sub surface safety valve. Removed 31 stainless bands. Removed 1/4" control line. Continue to lay down 2 -7/8" 6.5 ppf J -55 EUE tubing from 6480' to surface. Rig down tubing handling equipment. Clean and clear rig floor. Rig up, then set FMC upper test plug. Pickup 4" donut test joint. Fill stack with water. Using a 4" test joint, test upper and lower pipe rams to 250 psi low and 2500 psi high. Test annular to 250 psi low and 2500 psi high. Hold each test 5 minutes. Chart tests. Witness of tests waived by AOGCC inspector Bob Noble. Pull test plug. Install FMC wear bushing (6 -3/8" ID). PU BHA #1 Clean out. (7" Scraper and 6- 1/16" mill). Baker 6- 1/16" mill, 7" scraper, bit sub, x -o, 3 joints of 4" drill pipe, con't PU pipe f/ shed to 647'. 00:00 01:15 1.25 SLOT WHDBO BOPE P Finish testing BOPE. Witness of tests waived by AOGCC inspector Bob Noble. Test upper pipe rams (2 -7/8" x 5" VBR) and all valves on the choke manifold, kill line, choke line and mud line to the kill line to 250 psi low and 3500 psi, hold each test f/ 5 minutes, chart all tests. Test top drive IBOP manual and automatic to 250 psi low and 3500 psi high. Tested floor safety valve and IBOP to 250 psi low and 3500 psi high. Tested the accumulator. Tested the annular to 250 psi low and 2500 psi high. 01:15 01:45 0.50 SLOT WHDBO RURD P Rig down testing equipemnt, blow down choke and kill lines. 01:45 02:45 1.00 SLOT WHDBO OTHR T Attempt to back out blanking plug, left in hole. Rig up w/ joint of 4" dp and crossover to running retrieving tool. 02:45 03:00 0.25 SLOT WHDBO OTHR P Back out FMC blanking plug using 4" dp and crossover to retieving tool. 03:00 03:15 0.25 SLOT WHDBO OTHR P Pull FMC backpressure valve. 03:15 04:00 0.75 SLOT DRILL RURD P Rig up to pull tubing. Install 4" elevators and use joint of 4" drill pipe with a crossover to 2 -7/8" EUE. Screw into the hanger 9 rounds and 5000 ft lbs of torque. 04:00 04:15 0.25 SLOT DRILL OTHR P Back out lockdown screws on the tubing hanger. Page 5 of 58 • ! Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:00 0.75 0 8,224 SLOT DRILL PULL P PU on hanger to 60k, then 70k, then 75k. At 75k there was 10 -1/2" movement at the rig floor. Pull to 87k with 2' 6" of movement at the rotary table. Continue to pull with free movement at 87k to 85k, pulling hanger to the floor. Break joint of drill pipe and crossover f/ hanger, break and lay down FMC (.5' length) 6.98" OD hanger w/ 3.59' pup PxP below hanger. Lay down Joint of 4" drill pipe. 05:00 05:30 0.50 8,224 8,224 SLOT DRILL RURD P Rig up to circulate. 05:30 07:30 2.00 8,224 8,224 SLOT DRILL CIRC P Circulate 800 bbls while loading 4" drill pipe into the pipe shed and to clean up the hole. Initial 4 bpm w/ 900 psi, 6 bpm w/ 1840 psi, 7 bpm w/ 2480 psi. Final 6.5 bpm w/ 2160 psi. Rig up spooler for the control line. 07:30 07:45 0.25 8,224 8,224 SLOT DRILL OWFF P Monitor well- static. 07:45 08:00 0.25 8,224 8,224 SLOT DRILL CIRC P Pump a 15 bl dry job., blow down circulating lines. 08:00 10:30 2.50 8,224 6,480 SLOT DRILL PULL P Lay down a 16.45' pup under the hanger, then 56 joints of 2 -1/8" 6.5 ppf J -55 tubing from 8252' to 6480'. Lay down Baker FVL sub surface safety valve. Removed 31 stainless bands. Removed 1/4" control line. 10:30 17:00 6.50 6,480 0 SLOT DRILL PULL P Continue to lay down 2 -7/8" 6.5 ppf J -55 EUE tubing from 6480' to surface. Note: Total recovery: 31 stainless bands, FMC hanger (.5' length, 6.98" OD), pxp pup (3.59', space out pup 15.11', Cut joint flared to 3 -1/8" OD (16.45' long), Baker FVL SSSV, 1/4" control line, 265 joints of 2 -7/8" 6.5 ppf J -55 EUE tbg, (7) Merle TMPD 2 -7/8" x 1" GLM's. 17:00 17:45 0.75 SLOT DRILL RURD P Rig down tubing handling equipment. 17:45 18:30 0.75 SLOT DRILL OTHR P Clean and clear rig floor. 18:30 19:15 0.75 SLOT WHDBO NUND P Rig up, then set FMC upper test plug. Pickup 4" donut test joint. Fill stack with water. 19:15 21:00 1.75 SLOT WHDBO BOPE P Using a 4" test joint, test upper and lower pipe rams to 250 psi low and 2500 psi high. Test annular to 250 psi low and 2500 psi high. Hold each test 5 minutes. Chart tests. Witness of tests waived by AOGCC inspector Bob Noble. 21:00 21:30 0.50 SLOT WHDBO BOPE P Pull FMC upper test plug. 21:30 21:45 0.25 SLOT WHDBO NUND P Install FMC wear bushing (6 -3/8" ID). Page 6 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:15 0.50 SLOT DRILL PULD P Measure BHA components. Caliper OD's and ID's and ser#'s. 22:15 23:00 0.75 0 117 SLOT DRILL PULD P PU BHA #1 Clean out. (7" Scraper and 6- 1/16" mill). Baker 6- 1/16" mill, 7" scraper, bit sub, x -o, 3 joints of 4" drill pipe, x -o, Baker jars, x -o to 117.66'. 23:00 00:00 1.00 117 647 SLOT DRILL TRIP P Pick up/ makeup 4" drill pipe from the pipe shed and run in the hole f/ 117.66' to 647'. Rabbit pipe to 2 -3/8 ". 05/18/2010 Continue to P/U 4" DP to 8227', Taq Tbq stump a, 8227', Pump sweep around & POOH to 8227', Slip & cut drlg line 95', POOH & UD Scraper, Rig Halliburton, RIH w/ 7" CIBP, Attempt to set @ 4940' (Firing head failed), POOH, Rig new firing head, RIH & Set CIBP (a7 4940' - OK, POOH & Rig Down Halliburton, Rig & Test 7" casing to 2500 psi f/ 15 min on chart - OK, M/U mule shoe, Pick up 3 jts 4 -3/4" Flex collars, 14 jts HWDP, 1 jt 4" DP, RIH w/ 4" DP to 4756', M/U 7" Storm packer & Set same (a7 4839'. 00:00 08:00 8.00 647 6,245 SLOT DRILL PULD P Pick up/ makeup 4" drill pipe from the pipe shed and run in the hole f/ 647' to 6245'. Rabbit pipe to 2 -3/8 ". 08:00 09:30 1.50 6,245 8,227 SLOT DRILL PULD P Pump Hi -vis sweep at 12 bpm @ 2600 psi, Monitor well, Blow down top drive, POOH to 8,227'. 09:30 10:30 1.00 8,227 8,227 SLOT RIGMNT SLPC P PJSM, Slip & cut drilling line 95'. 10:30 14:00 3.50 8,227 0 SLOT DRILL TRIP P POOH & Lay down scraper assembly, Clear rig floor. 14:00 17:30 3.50 0 4,940 SLOT DRILL PACK P Spot Halliburton E -line truck, PJSM, Bring equipment to rig floor & rig up, Kake up 7" CIBP, RIH & set top at 4,940', Attempt to fire - No Good, POOH. 17:30 19:30 2.00 4,940 4,940 SLOT DRILL PACK T Trouble shoot firing head. 19:30 20:00 0.50 4,940 4,940 SLOT DRILL PACK P Make up CIBP, RIH & set plug top @ 4,940'. Good indication of firing. POOH. Rig down Hallibuton E -line. 20:00 20:30 0.50 4,940 4,940 SLOT DRILL PRTS P Rig & test 7" casing to 2500 psi f/ 15 min on chart - OK. 20:30 00:00 3.50 4,940 4,940 SLOT DRILL TRIP P PJSM, Make up mule shoe, Pick up 3 jts 4 -3/4" Flex collars, 14 jts 4" HWDP, 1 jt 4" DP, RIH to 4,756', Make up 7" Storm packer, RIH & set same @ 4,839' w/ top of packer @ 63' Up 105K, Dn 95K. 05/19/2010 Release from storm pkr @ 63' & POOH, Pull wear bushing, N/D BOP & tbg spool, Change out pack offs and test to 3000 psi, N/U BOP, Install test plug & Test break between BOP & Tbg spool to 250/3500 psi, Pull test plug & Install wear bush, Run over shot & Retrieve storm pkr, UD same, POOH, Make up whipstock BHA & Orient to MWD, RIH to 4815, Orient whipstock to 28 deg to highside, Taq CIBP (n7 4950' & Set anchor & shear off whipstock, C/O to 8.9 Flo -Pro mud, Cut window f/ 4932' to 4945', Cut guaged hole to 4965', Rig & preform FIT to 11.1 ppg EMW, Rig do & blow dn. 00:00 00:30 0.50 63 0 SLOT DRILL PULD P release running tool from storm packer, POOH & lay down same. 00:30 02:00 1.50 0 SLOT WHDBO NUND P Rig & pull wear bushing, Nipple down BOPE & Tubing spool. 02:00 04:30 2.50 SLOT WHDBO NUND P Remove pack off & Install new pack off, Nipple up new tubing spool & test to 3000 psi f/ 10 min - OK. Page 7 of 58 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:30 1.00 SLOT WHDBO NUND P Install & Nipple up BOP. 05:30 06:30 1.00 SLOT WHDBO BOPE P Install test plug & test break between well head and BOP against blind rams to 250 psi low and 3500 psi high, Rig down & blow down, Pull test plug & Install wear bushing. 06:30 07:30 1.00 0 0 SLOT DRILL PULD P Make up storm packer over shot, RIH & Retrieve storm packer & lay down same. 07:30 09:30 2.00 4,839 0 SLOT DRILL TRIP P POOH & stand back HWDP & Flex collars. 09:30 12:30 3.00 0 18 SLOT WHPST PULD P PJSM, Make up whipstock BHA & orient MWD, Make up whip stock. 12:30 14:30 2.00 18 4,815 SLOT WHPST TRIP P RIH w/ whipstock to 4,815', Shallow tested MWD w/ 250 gpm @ 620 psi. 14:30 16:00 1.50 4,815 4,950 SLOT WHPST WPST P Make up top drive, Establish parameters 105K Up, 95K Dn, Orient whipstock at 29 deg right of high side, RIH & Tag CIBP @ 4,950', set p £ anchor & shear off whipstock. 16:00 16:30 0.50 4,950 4,932 SLOT WHPST CIRC P Displace to 8.9 ppg Flo -Pro at rate of 6 bpm @ 860 psi, Begin Milling - Top of whistock @ 4,932' & Bottom @ 16:30 20:30 4.00 4,932 4,969 SLOT WHPST MILL P Mill window f/ 4,932' to 4,969' (Guage hole to 4,965') at rate of 321 gpm @ 1560 psi, 100 rpm w/ 3 to 8K Tq & 4 to 5K WOB. P 20:30 22:30 2.00 4,969 4,969 SLOT WHPST CIRC P Ream out window, Pump 15 bbl super sweep & Circ 3 times bottoms �4,� up at rate of 325 gpm @ 1380 psi, 3 a Obtain SPR's, Monitor well. 22:30 00:00 1.50 4,969 4,920 SLOT WHPST FIT P Rig & perform FIT of 11.1 ppq w/ 415 psi, 3,710' TVD & 8.9 ppq mud, Rig down & Blow down. 05/20/2010 POOH & UD Milling Assembly, Wash metal f/ stack, M/U 6 -1/8" BHA, RIH to 4969', Time drill & trough to get seperation from original well f/ 4969' to 5082', Directional drill f/ 5082' to 5525'. 00:00 02:30 2.50 4,920 0 SLOT WHPST TRIP P POOH & Lay down Whipstock BHA. 02:30 03:30 1.00 0 INTRMI DRILL PULD P Clear & Clean rig floor. 03:30 04:00 0.50 INTRMI DRILL PULD P Make up stack washer & wash metal cuttings out of stack, Lay down waher, Blow down top drive. 04:00 06:30 2.50 0 671 INTRMI DRILL PULD P PJSM, Pick up 6 -1/8" BHA #3. 06:30 09:00 2.50 671 4,874 INTRMI DRILL TRIP P RIH to 4,874' Up 105K, Dn 95K. 09:00 09:30 0.50 4,874 4,966 INTRMI DRILL TRIP P Continue to RIH to 4,966', Obtain SPR's ( No problems going thru window) 09:30 18:00 8.50 4,966 5,082 INTRMI DRILL DDRL P Trouble getting seperation from original well, Time drill & Trough to get seperation f/ 4,969' to 5,082'. Page 8 of 58 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T. Comment 18:00 00:00 6.00 5,082 5,525 INTRMI DRILL DDRL P Directional drill 6 -1/8" hole f/ 5,082' to 5,525' (4,094' TVD) 325 gpm A 2020 psi, WOB 5 -6K, 60 rpm, Tq 5K, Up 117K, Dn 98K, Rot 101K, Ave. ECD10.28 ppg. 05/21/2010 Cont. to slide in attempt drop angle f/ 5525' to 5617', Trough hole f/ 5577' to 5617', Slide f/ 5617' to 5639', Monitor well, POOH to 4967', Monitor well, Pump dry job, POOH to BHA, Chip ice out of derrick, UD Rhino reamer, Bit & Motor, Wait on motor, repair low drum clutch on drawworks, P/U BHA #4 & RIH to 5626', Orient motor & Directional drill f/ 5639' to 5649'. 00:00 02:30 2.50 5,525 5,617 INTRM1 DRILL DDRL P Continue to Slide & Attempt to Drop Angle f/ 5,525' to 5,617' MD / 4176' TVD at rate of 325 gpm @ 2030 psi, WOB 2/7K, Up 120K, Dn 105K, Rot 98K, Tq 5K, Ave ECD 10.28 ppg. 02:30 04:00 1.50 5,617 5,617 INTRMI DRILL OTHR P Trough with 180 Toolface at same perameters in attempt to drop angle. 04:00 06:00 2.00 5,617 5,639 INTRMI DRILL DDRL P Continue to Slide & Attempt to Drop Angle f/ 5,617' MD to 5,639' at rate of 325 gpm @ 2030 psi, WOB 2/3K, Up 120K, Dn 105K, Rot 98K, Tq 5K, Ave ECD 10.28 ppg. 06:00 07:30 1.50 5,639 4,967 INTRM1 DRILL TRIP T Obtain SPR, Monitor well, POOH to 4,967', Monitor well, Pump dry job. 07:30 09:30 2.00 4,967 65 INTRM1 DRILL TRIP T POOH to 4,874', Blow down top drive, POOH & stand back BHA. 09:30 10:30 1.00 65 65 INTRM1 DRILL SFTY P Large chunks of ice falling out of the derrick - Shut down and had derrick man remove as much ice as he could find. 10:30 12:00 1.50 65 0 INTRMI DRILL PULD P Pull up & Break Bit- OK, Break Rhino Reamer (Several broken PDC's from running along side original well), Down load MWD, Check motor - (Loose bearings), Lay down mud motor. 12:00 15:00 3.00 0 0 INTRMI DRILL OTHR T Wait on mud motor w/ ABI. 15:00 17:00 2.00 0 0 INTRM1 RIGMNT RGRP T Change out low drum clutch on drawworks. 17:00 19:30 2.50 0 772 INTRM1 DRILL PULD T PJSM, Make up BHA #4, Orient MWD & Mud motor, Upload MWD, RIH w/ DC's & HWDP to 772'. 19:30 20:00 0.50 772 772 INTRM1 DRILL DHEQ T Shallow test MWD -OK. 20:00 20:30 0.50 772 772 INTRM1 RIGMNT SVRG P Service rig floor equipment. 20:30 23:00 2.50 772 5,639 INTRMI DRILL TRIP T Continue to RIH f/ 772' to 5,626' filling pipe @ 3,014', 4,974', Orient motor & Slide thru window - No problems going thru window @ 4,932'. 23:00 00:00 1.00 5,639 5,649 INTRMI DRILL DDRL P Obtain SPR's, Orient motor & Directional drill f/ 5,639' to 5,649' MD / 4,183' TVD, ART= .05 hrs, AST= .09 hrs. 05/22/2010 Directional Drill f/ 5649' to 6199', Back ream f/ 6199' to 5813' to clean up BHA, RIH to 6199', Drill f/ 6199' to 6244', Pump Hi -vis sweep around, Monitor well, Back ream out to 5620', Monitor well, Dry pipe, POOH on elevators to 5000'. Page 9 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 17:00 17.00 5,649 6,199 INTRMI DRILL DDRL P Directional drill f/ 5,649' to 6,199' MD / 4,673' TVD, 320 gpm @ 2450 psi, 60 rpm w/ 5K tq, Up 130K, Dn 107K, Rot 113K, WOB 5/25K, Ave ECD's 10.33 ppg, ART= 4.50 hrs, AST= 7.32 hrs. Note; Very slow ROP, Decision made to back ream 5 stands to possibly clean up BHA. 17:00 18:30 1.50 6,199 6,199 INTRM1 DRILL REAM P Back Ream out of hole f/ 6,199' to 5,813' at drilling rate perameters to possibly clean up BHA due to very slow RPM, RIH to bottom. 18:30 21:30 3.00 6,199 6,244 INTRMI DRILL DDRL P Directional drill f/ 6,199' to 6,244' MD / 4,717' TVD, 320 gpm @ 2450 psi, 60 rpm w/ 5K tq, Up 130K, Dn 107K, Rot 113K, WOB 5/40K, Ave ECD's 10.33 ppg, ART= .85 hrs, AST= .74 hrs. 21:30 22:00 0.50 6,244 6,244 INTRMI DRILL CIRC P Pump Hi -vis sweep & circ out of hole at rate of 320 gpm @ 2380 psi. 22:00 23:00 1.00 6,244 5,620 INTRM1 DRILL REAM P Monitor well - OK, Back Ream out f/ 6,244' to 5,620' at drilling rate (Above 7" x 6 -1/8" shoulder). 23:00 00:00 1.00 5,620 5,000 INTRM1 DRILL TRIP P Monitor well - OK, Pump dry job, POOH on elevators f/ 5,620' to 5,000' (Hole in good shape). 05/23/2010 POOH & Stand back BHA, Break & Check Bit- OK, M/U Rhino reamer & Bit, Check scribe on Motor & MWD, Down Toad & Upload MWD, RIH w/ BHA & RIH to 4418', Slip & cut drlg line 47', RIH to 5628', Ream 6 -1/8" hole to 7" f/ 5628' to 6244', Drill f/ 6244' to 6746'. 00:00 02:30 2.50 5,000 0 INTRMI DRILL TRIP P POOH f/ 5,000' to BHA, Stand back HWDP & Jars, Flex Collars, Break & Check Bit. 02:30 04:30 2.00 0 65 INTRMI DRILL PULD P Make up Rhino Reamer & Bit, Check scribe on Motor & MWD, Down load & Upload MWD. 04:30 07:30 3.00 65 4,418 INTRM1 DRILL TRIP P Make up Flex Collars & HWDP, RIH to 4,418' filling pipe every 20 stands. 07:30 08:30 1.00 4,418 4,418 INTRMI RIGMNT SLPC P Slip & Cut Drlg line 47', Service rig. 08:30 09:00 0.50 4,418 5,628 INTRMI DRILL TRIP P Continue to RIH to 5,628' (No problem going thru window), Obtain SPR's. 09:00 13:30 4.50 5,628 6,244 INTRM1 DRILL REAM P Ream 6 -1/8" hole to 7" with Rhino reamer starting f/ 5,628' to btm @ 6,244' at rate of 320 gpm @ 2150 psi, 60 rpm w/ 4K tq. 13:30 00:00 10.50 6,244 6,746 INTRMI DRILL DDRL P Diretional Drill f/ 6,244' to 6,746' MD / 5,215' TVD, 320 gpm @ 2230 psi, 10K WOB, 60 rpm w/ 4/5K Tq, Up 130K, Dn 110K, Rot 120K, ART= 5.05 hrs, AST= 1.5 hrs, Ave ECD's 10.7 ppg. 05/24/2010 Directional Drill f/ 6,746' to 7,415' MD / 5,874' TVD, Circ btu, Monitor well, Pull 2 std's, Monitor well, Pump dry job, POOH to 4,307'. Page 10 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 21:00 21.00 6,746 7,415 INTRMI DRILL DDRL P Directional Drill f/ 6,746 to 7,415' MD / 5,874 TVD, 320 gpm @ 2400 psi, 10K WOB, 60 rpm w/ 4/5K Tq, Up 155K, Dn 120K, Rot 123K, ART= 6.39 hrs, AST= 6.92 hrs, Ave ECD's 10.8 ppg. ROP Extremely slow - Decision made to POOH and check Bit & Rhino reamer. And to lay down Rhino reamer. 21:00 21:30 0.50 7,415 7,415 INTRM1 DRILL CIRC T Circ BTU at rate of 320 gpm @ 2400 psi. 21:30 22:00 0.50 7,415 7,308 INTRM1 DRILL TRIP T Monitor well, Pull 2 stands to check for possible swabbing, Monitor well, Pump dry job, Blow down top drive. 22:00 00:00 2.00 7,308 4,307 INTRM1 DRILL TRIP T POOH on elevators f/ 7,308' to 4,307'. 05/25/2010 Continue POOH, Change out Mud motor, dropping Rhino Reamer. Bit gauged at 0 /01 /CT /G/X /N /NO /PR. Will rerun. Make up assembly, and trip back through window with no issues, continuing to 7415' MD. Continune direcyional drill 6 1/8" hole form 7415' - 7816'. 00:00 01:00 1.00 4,307 680 INTRM1 DRILL TRIP T Continue POOH with BHA #5 from 4307' to 680;' 01:00 02:00 1.00 680 100 INTRMI DRILL TRIP T Rack Back HWDP, Jars and DC's 02:00 02:30 0.50 100 100 INTRM1 DRILL PULD T Plug in and download MWD assembly. 02:30 04:30 2.00 100 0 INTRMI DRILL PULD T Breakout & lay down Motor ,assembly. bit. and Rhino reamer. Inspect and grade bit to 0 /1 /CT /G/X /N /NO /PR. Make up new motor with ABI, adjusting bend to 1.5 Deg. 04:30 05:00 0.50 0 100 INTRM1 DRILL PULD T Plug in , upload MWD assembly. 05:00 05:30 0.50 100 200 INTRMI DRILL TRIP T Trip in hole with 1 stand of drill collars. 05:30 06:00 0.50 200 200 INTRMI DRILL DHEQ T Perform shallow pulse test with 320 GPM's - 1000 PSI Good test. 06:00 07:00 1.00 200 100 INTRMI DRILL TRIP T Decision to POOH to change out upper stabilizer to 5.93" OD, and verify strap on mud motor.Re- orient motor to MWD. 07:00 12:00 5.00 100 7,415 INTRM1 DRILL TRIP T Continue trip in hole performing shallow pulse test again, good test. Trip to 4887'.Orient toolface to high side for window exit. Continue with assembly through window with no issues, and tripping into open hole to 7400' MD. Wash down to 7415' MD, with 60 RPM's - 320 GPM's - 2300 PSI. UP WT = 175K, SO WT = 125K, with ROT WT = 155K. Obtain SPR's. Orient toolface to 80 Deg Left. Page 11 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 7,415 7,816 INTRMI DRILL DDRL P Continue directional drilling from 7,415' to 7,816' MD / 6,231' TVD, 320 gpm @ 2500 psi, 10/15K WOB, 60 rpm w/ 6/7K Tq, Up 160K, Dn 125K, Rot 130K, Ave. ECD's = 10.5 ppg, ART= 1.31 hrs, AST= 5.73 hrs, Observed Sliding ROP from 40 -80 ft/hr, and rotating ROP held to 150 ft/hr initially. 05/26/2010 Drill f/ 7816' to 8260', Circ 4 times btu, POOH to 7900', Back ream out to 7856' (Packing off), Ream down to 7944' to clean up well (Monitor well- OK), Back ream out to 7400', POOH to 6932' (Improper fill) Monitor well - OK, Circ btu 2 times, POOH to 6375, Monitor well- OK, Back ream out to 6088'. 00:00 16:00 16.00 7,816 8,260 INTRMI DRILL DDRL P Continue directional drilling from 7,816' to TD of 8,260' MD / 6,478' TVD, 320 gpm @ 2530 psi, 10/12K WOB, 60 rpm w/ 6/7K Tq, Up 175K, Dn 135K, Rot 135K, Ave. ECD's = 10.5 ppg, ART= 4.08 hrs, AST= 6.69 hrs. 16:00 17:30 1.50 8,260 8,144 INTRM1 DRILL CIRC P Circ 4 time btu at rate of 320 gpm @ 2430 psi, Stand back 1 stand. 17:30 18:00 0.50 8,144 7,900 INTRMI DRILL TRIP P Blow down top drive, POOH f/ 8,144' to 7,900'. 18:00 19:30 1.50 7,900 7,944 INTRM1 DRILL REAM P Begin back reaming out of hole f/ 7,900' to 7,856' at rate of 320 gpm @ 2430 psi, 60 rpm, Hole packed off w/ 3000 psi, ECD's spiked to 12.3 ppg, Lost 4 bbls mud (Well gave the 4 bbls back), Regain circ & ream down to 7,944'. 19:30 21:30 2.00 7,944 7,400 INTRM1 DRILL REAM P Back ream out of hole slow at rate of 320 gpm @ 2330 psi (Still minor packing off - No mud lost) f/ 7,944' to 7,400', Monitor well - OK, 21:30 22:00 0.50 7,400 6,932 INTRM1 DRILL TRIP P POOH on elevators f/ 7,400' to 6,932' (Improper fill -1.8 bbls short), Monitor well - Static. 22:00 23:00 1.00 6,932 6,838 INTRM1 DRILL CIRC P Circ 2 times btu at rate of 325 gpm @ 2480 psi (Large amount of cuttings on first bottoms up). 23:00 23:30 0.50 6,838 6,373 INTRM1 DRILL TRIP P POOH on elevators f/ 6,838' to 6,373' (Improper fill - 1.4 bbls short), Monitor well - Static. 23:30 00:00 0.50 6,373 6,088 INTRM1 DRILL REAM P Back ream out of hole slow at rate of 320 gpm @ 2200 psi f/ 6,373' to 6,088'. 05/27/2010 Back ream out f/ 6088' to 5720' (Improper hole fill), Monitor well - Observed slight flow, RIH to 8148', Circ btu - Had gas cut mud f/ 9.1 to 7.4 ppg, Circ until 9.1 ppg in & out, Monitor well - Static, RIH to 8241', Circ btu - No gas observed, Back ream out of hole f/ 8241' to 5125 (Packing off), Circ 4 times btu to clean up well, Cont. to back ream out f/ 5125' to 1500' (Had 15K pull coming thru window - Work out same), POOH on elevators w/ good fill to BHA. 00:00 01:30 1.50 6,088 5,720 INTRMI DRILL REAM P Continue to back ream out of hole slow at rate of 320 gpm @ 2200 psi f/ 6,088' to 5,720', Hole not taking proper fill, Monitor well - Observed Slight flow. Page 12 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 5,720 8,148 INTRM1 DRILL TRIP P RIH f/ 5,720' to 8,148' (Up 175K, Dn 120K), Tagged & washed thru bridges @ 6,608' & 7,805' w/ 320 gpm @ 2400 psi & 60 rpm. 02:30 04:00 1.50 8,148 8,241 INTRMI DRILL CIRC P Circ bottom's up at rate of 320 gpm @ 2500 psi, Had 5% flow increase & 4 bbls gain on bottom's up Mud cut f/ 9.1 ppg to 7.4 ppg, Contine to circ until mud balanced out to 9.1 ppg in & out, RIH to 8,241', Circ bottom's up w/ no mud cut or noticable gas, Monitor well - Static. 04:00 13:00 9.00 8,241 5,125 INTRMI DRILL REAM P Back ream out of hole f/ 8,241' to 5,125' at rate of 325 gpm @ 2460 psi, 60 rpm w/ 4K tq, Had packing off @ 7,836' & 7,711'. 13:00 15:00 2.00 5,125 5,125 INTRMI DRILL CIRC P Circ 4 times bottom's up due to packing off to clean up hole, Had excess amount of cutting coming over shakers, ECD's f/ 11.3 to 11.7 Ppg. 15:00 00:00 9.00 5,125 678 INTRMI DRILL REAM P Monitor well - OK, Continue to back ream out of the hole f/ 5,125' to 1,500', Had 15K over pull when pulling stab thru window - worked thru several time to clean up window, No issues pulling Bit thru window, POOH to BHA on elevators w/ Good fill. 05/28/2010 Down load MWD & UD Bit, Motor & MWD, M/U & Test Rhino reamer, M/U BHA & RIH to 4,392', Service rig, RIH to 7280' (Had to work thru window @ 4932'), Ream out hole f/ 6 -1/8" to 7" f/ 7280' to 8260', Circ 4 x btu while back reaming slow f/ 8260' to 7750', RIH & Tag for fill - OK, Back ream out of hole f/ 8260' to 7844'. 00:00 01:30 1.50 678 0 INTRMI DRILL PULD P Down load MWD, Break out Bit, Lay down MWD & Mud motor. 01:30 02:00 0.50 0 0 INTRMI DRILL DHEQ P Make up Rhino reamer & Bit to stand of HWDP, Function test Rhino reamer - Reamer opened w/ 140 psi - OK. 02:00 05:00 3.00 0 4,392 INTRM1 DRILL PULD P RIH w/ BHA & RIH to 4,392'. 05:00 05:30 0.50 4,392 4,392 INTRMI RIGMNISVRG P Service rig. 05:30 09:00 3.50 4,392 7,280 INTRMI DRILL TRIP P RIH f/ 4,392' to 7,280' (Had trouble going thru window - Tried turning bit 1/4 turns with up to 8K bit weight - Finally fell thru w/ 15K bit weight). 09:00 20:00 11.00 7,280 8,260 INTRMI DRILL REAM P Ream out hole w/ Rhino reamer f/ 6 -1/8" hole to 7" f/ 7,280' to 8,260' at rate of 325 gpm @ 2520 psi, 80 rpm w/ 5K tq. 20:00 23:00 3.00 8,260 8,260 INTRMI DRILL CIRC P Circ 4 times bottom's up at rate of 340 gpm @ 2600 psi f/ 8,260' to 7,750' while back reaming & standing back 1 every 30 min., Pump 20 bbls Low torque - Nut plug sweep around to clean hole. Page 13 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 8,260 7,844 INTRMI DRILL REAM P RIH & Tag for fill @ 8,260' (No fill), Back ream out of hole f/ 8,260' to 7,844' at rate of 340 gpm @ 2600 psi w/ 60 rpm & 6K tq, Pulling speed of 25 to 30 ft/min. 05/29/2010 Back ream out to 4982', POOH to 4920' (Had 10K over pull thru window), Drop Circ sub ball & Open same, Circ 4 x btu at rate of 620 gpm @ 2150 psi, POOH & UD BHA, Rig & run 5 -1/2 ", 15.5# liner to 2808'. 00:00 07:00 7.00 7,844 4,982 INTRMI DRILL REAM P Continue to Back ream out of hole f/ 7,844' to 4,982' at rate of 340 gpm @ 2340 psi w/ 60 rpm & 4K tq, Pulling speed of 25 to 30 ft/min, . 07:00 08:00 1.00 4,982 4,920 INTRMI DRILL TRIP P POOH f/ 4,982' to 4,920' w/ No pump or Rotation, Pulled 10K over coming thru window. 08:00 10:30 2.50 4,920 4,920 INTRM1 DRILL CIRC P Monitor well, Drop 1.76" Ball, Pump down & Open Circ sub w/ 2350 psi, Circ casing clean w/ 4 times bottom's up at rate of 500 to 620 gpm 1350 to 2150 psi, Pump dry job. 10:30 14:00 3.50 4,920 678 INTRM1 DRILL TRIP P POOH on elevators f/ 4,920' to BHA @ 678' w/ good fill. 14:00 16:30 2.50 678 0 INTRMI DRILL PULD P Rack back HWDP, Lay down Jars w/ 2 jts HWDP & BHA. 16:30 18:30 2.00 0 INTRM1 CASING RURD P Clear & Clean rig floor, Rig to run 5 -1/2" liner. 18:30 00:00 5.50 0 2,808 INTRM1 CASING RUNL P PJSM, Pick up Float Shoe jt, Float Collar jt & Landing Collar jt, Fill liner w/ Mud & Check Float equipment - OK, Pick up & Run 5 -1/2 ", 15.5#, L -80, STL liner to 2,808', Filling pipe every joint on fly & Topping off pipe every 10 jts. 05/30/2010 Continue to P/U 5 -1/2" liner f/ 2808' to 3667', P/U Baker liner hangers, CBU at 3 bpm @ 530 psi (Lossing 31 bph- w/ Hangers out of hole), RIH to 4881', CBU at 3 bpm @ 600 psi (Loss rate 56 bph), RIH to 6375', CBU at 3 bpm @ 600 psi (Loss rate 24 bph), RIH to 7310', Circ hole vol. at 3 bpm @ 620 psi (Loss rate 22 bpm), RIH to 7668' working thru tight spots & pumping 3 bpm @ 900 psi, Work down to 7740' & n- a - • • - • - 7740', Pump out of hole to 3653', Rig & UD liner hangers, Pump out liner due to swabbing f/ 3653 to 3529'. 00:00 02:00 2.00 2,808 3,667 INTRM1 CASING RUNL P Continue to run 5 -1/2" Liner f/ 2,808' to 3,667' filling pipe on every jt & Topping off on every 10 jts, Make up liner hangers, Change elevators. 02:00 03:00 1.00 3,667 3,667 INTRMI CASING CIRC P Circ bottom's up with hanger out of hole at rate of 3 bpm @ 530 psi - Loss rate 32.2 bph w/ 83% returns. 03:00 05:30 2.50 3,667 4,881 INTRMI CASING RUNL P Run liner on Drill pipe f/ 3,667' to 4,881', Drop drift on each stand, Filling drill pipe w/ mud between stands. 05:30 06:00 0.50 4,881 4,881 INTRM1 CASING CIRC P Circ bottom's up at 3 bpm @ 600 psi, loss rate 56 bph w/ 69% returns, Monitor well- static, Blow down top drive. Page 14 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:30 1.50 4,881 6,375 INTRM1 CASING RUNL P Continue to Run liner on Drill pipe f/ 4,881' to 6,375', Drop drift on each stand, Filling drill pipe w/ mud between stands. 07:30 09:00 1.50 6,375 6,375 INTRM1 CASING CIRC P Circ bottom's up at 3 bpm @ 600 psi, loss rate 24 bph, Monitor well - static, Blow down top drive. 09:00 10:00 1.00 6,375 7,310 INTRMI CASING RUNL P Continue to Run liner on Drill pipe f/ 6,375' to 7,310', Drop drift on each stand, Filling drill pipe w/ mud between stands. 10:00 10:30 0.50 7,310 7,310 INTRM1 CASING CIRC P Circ Open hole volume at 3 bpm @ 600 psi, Toss rate 22 bph, Monitor well- static, Blow down top drive. 10:30 12:00 1.50 7,310 7,668 INTRM1 CASING RUNL P Continue to Run liner on Drill pipe f/ 7,310' to 7,668', Work thru tight spots, Setting down w/ 38K, Pulling 45K over, Pumping at rate of 3 bpm P 9 @ 900 psi. 12:00 13:00 1.00 7,668 7,740 INTRM1 CASING RUNL T Continue to Run liner on Drill pipe f/ 7,668' to 7,740', Work thru tight spots, Setting down w/ 38K, Pulling 45K over, Pumping at rate of 4 bpm @ 1010 psi, Unable to work past 7,740'. 13:00 19:00 6.00 7,740 3,653 INTRM1 CASING TRIP T Pump out of hole w/ liner f/ 7,740' to 3,653' at rate of 3 bpm @ 540 psi, No problem coming thru window. 19:00 20:00 1.00 3,653 3,653 INTRM1 CASING PULD T Rig up casing tongs, Break & lay down Baker Liner hangers. 20:00 23:00 3.00 3,653 3,571 INTRMI CASING RURD T Monitor well - Static, Rig up & pull 1 joint 5 -1/2" csg and check for swabbing ( "Swabbing" -Hole staying full - Not dropping at all), Rig up to pump casing out of hole using top drive, Hold PJSM on pulling casing wet, Pump 1 joint out using top drive - Decide this was not safe enough (Requires to much work over head), Re -rig using cement line, pump in sub & swivel. 23:00 00:00 1.00 3,571 3,529 INTRMI CASING PULD T Pump out of the hole f/ 3,571' to 3,529'. 05/31/2010 Pump 5 -1/2" line out of hole due to swabbing, Heat & break out crossover joint, UD shoe track, Clear & clean rig floor, Rig & wash out stack, Rig & test BOPE w/ 5 -1/2" & 4" test joints to 250/3500 psi, Annular to 250/2500 psi, Test witnessed by AOGCC Chuck Scheve.. 00:00 16:00 16.00 3,529 80 INTRM1 CASING TRIP T PJSM, Pump out of hole w/ 5 -1/2" liner due to swabbing f/ 3,529' to 80' at rate of 3 bpm © 540 / 220 psi. Observed nose cone on float shoe knocked off. 16:00 17:30 1.50 80 0 INTRM1 CASING PULD T Blow down cement line, Heat & Break crossover joint, Lay down Shoe track. 17:30 18:30 1.00 0 0 INTRMI CASING PULD T Clear & clean rig floor. Page 15 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:00 0.50 0 0 INTRMI WHDBO BOPE P Make up stack wash tool & wash BOP stack w/ 5.5 bpm & 50 rpm. 19:00 21:00 2.00 0 0 INTRMI WHDBO BOPE P Pull wear bushing, Set test plug, PJSM, Open ram doors & run 5 -1/2" test joint in hole to verify lower rams will clean do -nut on test joint, p 21:00 00:00 3.00 0 0 INTRMI WHDBO BOPE P Test BOPE w/ 5 -1/2" & 4" test joints lo to 250 low & 3500 High, Annular to 250 low & 2500 psi, Test witnessed by AOGCC Chuck Scheve. Note; Well breathing extremly small stream (Pencil lead size stream) of mud while testing BOPE, No change in amount thru out time period, 13 gal. in the 5 hours from setting test plug & testing. 06/01/2010 Continue to test BOPE w/ 5 -1/2" & 4" test joints to 250/3500 psi, Annular to 250/2500 psi, Test witnessed by AOGCC Chuck Scheve. Rig down testing equipment, blow down lines, pull test plug, instaltwear bushing. Make up bha, drop ball to close circ sub, pump to test rhino reamer (3 bpm w/ 140 psi), continue to make up BHA to 598', run in the hole to 4886', go through window w/ 10k drag @ 4932', set down 12k @ 5238'. Wash down f/ 5238' to 5267' pumping 250 gpm w/ 1260 psi, continue to trip in to 6200', circulate 45 bbls pumping 6 bpm w/ 1570 psi, continue trip in from 6200' to 7133'. Ream in the hole from 7133' to 7226'. PU wt 160k, SO wt 113k, Rot wt 125k. Pumping 8 bpm w/ 2660 psi. Rotate 150 rpm w/ 6k ft ibs of torque. Continue to ream in the hole from 7226' to 7756'. PU wt 160k, SO wt 115k, Rot wt 127k. Pumping 8 bpm w/ 2660 psi, then while reaming @ 7617' presure dropped to 2330 psi (plugged jet unplugged). Rotate 150 rpm w/ 6k ft ibs of torque. Noted tight spots: 7653', 7664', 7668', 7725', 7729'. Packed off at 7664' and 7725'. Appeared to be on the broken nose of the float shoe © 7742', drilled w/ 6 -10k weight on bit and up to 10k ft lbs of torque. Taking constant weight while reaming at 7756'. Attempted to get past 7756' twice with no pump and no rotation, twice w/ no pump and 35 rpm rotation -- no go. Note: Appears that we have sidetracked hole between 7682' and 7746'. Survey at 7746' shows 2.65 deg lower inclination than original surveys. Backream from 7756 to 7503'. Monitor well- slight flow- out of balance. Backream from 7503' to 7070'. Pull out of the hole on the trip tank from 7070' to 4885'. Observed 1 to 2k flickers on weight indicator pulling through window. Pipe came dry once in casing. Monitor well- slight drop in fluid. Pull out of the hole on the trip tank from 4885' to 2317'. 00:00 02:00 2.00 INTRMI WHDBO BOPE P Continue to test BOPE w/ 5 -1/2" & 4" test joints to 250 low & 3500 High, Annular to 250 low & 2500 psi, Test witnessed by AOGCC Chuck Scheve. Note; Well breathing extremly small stream (Pencil lead size stream) of mud while testing BOPE, No change in amount thru out time period, 23 gal. in the 7 hours from setting test plug & testing. 02:00 02:30 0.50 INTRMI WHDBO BOPE P Rig down testing equipment, blow down kill and choke lines. Pull test plug, set 6 -3/8" wear ring. 02:30 03:45 1.25 0 598 INTRMI DRILL PULD P Make up BHA. 03:45 05:00 1.25 598 598 INTRMI DRILL DHEQ P Drop ball to close commander sub, pressure up to 2000 psi. Function test Smith Rhino Reamer. Circ 3 bpm w/ 140 psi. 05:00 07:45 2.75 598 4,886 INTRMI DRILL TRIP P Trip in the hole from 598' to 4886'. Page 16 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:00 0.25 4,886 5,238 INTRMI DRILL TRIP P Obtain parameters: PU wt 105k, SO wt 93k, 10k drag going thru window, continue to run in the hole from 4886' to 5238'. Set down 12k wt @ 5238'. 08:00 08:30 0.50 5,238 5,267 INTRMI DRILL WASH P Wash down from 5238' to 5267'. Work through tight spot at 5238' several times. Pumping 250 gpm w/ 1260 psi. 08:30 09:15 0.75 5,267 6,200 INTRMI DRILL TRIP P Continue trip in the hole from 5267' to 6200'. 09:15 09:45 0.50 6,200 6,200 INTRMI DRILL CIRC P Circulate, pumping 6 bpm w/ 1570 psi, circulate 45 bbls. 09:45 10:30 0.75 6,200 7,133 INTRMI DRILL TRIP P Continue trip in the hole from 6200' to 7133'. 10:30 12:00 1.50 7,133 7,226 INTRMI DRILL REAM P Ream in the hole from 7133' to 7226'. PU wt 160k, SO wt 113k, Rot wt 125k. Pumping 8 bpm w/ 2660 psi. Rotate 150 rpm w/ 6k ft Ibs of torque. 12:00 17:30 5.50 7,226 7,756 INTRMI DRILL REAM P Continue to ream in the hole from 7226' to 7756'. PU wt 160k, SO wt 115k, Rot wt 127k. Pumping 8 bpm w/ 2660 psi, then while reaming @ 7617' presure dropped to 2330 psi (plugged jet unplugged). Rotate 150 rpm w/ 6k ft lbs of torque. Noted tight spots: 7653', 7664', 7668', 7725', 7729'. Packed off at 7664' and 7725'. Appeared to be on the broken nose of the float shoe @ 7742', drilled w/ 6 -10k weight on bit and up to 10k ft lbs of torque. Taking constant weight while reaming at 7756'. Attempted to get past 7756' twice with no pump and no rotation, twice w/ no pump and 35 rpm rotation- no go. Note: Appears that we have sidetracked hole between 7682' and 7746'. Survey at 7746' shows 2.65 deg lower inclination than original surveys. 17:30 18:00 0.50 7,756 7,756 INTRMI DRILL CIRC T Circulate, pumping 5.5 bpm w/ 2700 psi (plugged jet) to even out mud weight in and out. Rotate 40 rpm. 18:00 18:45 0.75 7,756 7,503 INTRMI DRILL REAM T Backream from 7756 to 7503'. Circulate to even out mud weight 18:45 19:00 0.25 7,503 7,503 INTRMI DRILL OWFF T Monitor well- slight flow- out of balance. 19:00 20:30 1.50 7,694 7,070 INTRMI DRILL REAM T Backream from 7503' to 7070'. Circulate to even out mud weight 20:30 22:30 2.00 7,070 4,885 INTRMI DRILL TRIP T Pull out of the hole on the trip tank from 7070' to 4885'. Observed 1 to 2k flickers on weight indicator pulling through window. Pipe came dry once in casing. 22:30 22:45 0.25 4,885 4,885 INTRMI DRILL OWFF T Monitor well- slight drop in fluid. Page 17 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 4,885 2,317 INTRMI DRILL TRIP T Pull out of the hole on the trip tank from 4885' to 2317'. Pipe came dry once in casing. Calculated fill to this point 21.6 bbls, actual 19 bbls. 06/02/2010 Continue to pull out of the hole on the trip tank from 2317' to 568' w/ rhino reamer BHA to PU drilling BHA. Monitor well- static. continue POOH, UD BHA, clean floor, PJSM on PU /MU BHA. PU BHA to 92', upload MWD, continue BHA to 255', shallow test, continue w/ BHA to 656', trip in to 4859' filling pipe at 1592' & 3459'. Circ string volume at 3459'. Service rig. Slip 662' and cut 633' of 1 -1/4" drilling line, inspect brakes, adjust kick -back rollers for brake bands. Continue trip in from 4859' to 7481' (Tagged up). Ream from 7481' to 7740'. Trough f/ sidetrack from 7700' to 7740'. Drill w/ 1.5 deg bend motor from 7740' to 7788',packed off (hung up), work to free pipe, backream 7740' to 7650', slide 7740' to 7788', rotate 7788' to 7800', slide 7800' to 7808' (ABI inclination showing in old hole). Tight hole at 7808', work free, backream 7751' to 770', slide f/ 7700' to 7740' toughing hole. 00:00 00:45 0.75 2,317 568 INTRM1 DRILL TRIP T Pull out of the hole on the trip tank from 2317' to 568'. Note: Total trip f/ drill pipe, calculated displacement 40.2 bbls, actual 40 bbls. 00:45 01:00 0.25 568 568 INTRMI DRILL OWFF T Monitor well- static. 01:00 02:15 1.25 568 0 INTRM1 DRILL TRIP T Continue to pull out of the hole on the trip tank from 568' to sufrace. Layed down BHA. 02:15 03:15 1.00 0 0 INTRM1 DRILL PULD T Clean and clear rig floor. 03:15 03:30 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on picking up /make up BHA. 03:30 05:00 1.50 0 92 INTRM1 DRILL PULD T MU BHA to 92' 05:00 06:45 1.75 92 92 INTRM1 DRILL PULD T Upload Sperry Sun MWD. Dress the saver sub on the top drive. 06:45 07:30 0.75 92 255 INTRMI DRILL PULD T Make up BHA to 255'. 07:30 08:00 0.50 255 255 INTRM1 DRILL DHEQ T Shallow test MWD- OK. 08:00 08:30 0.50 255 656 INTRM1 DRILL TRIP T Continue to make up BHA from 255' to 656' 08:30 11:30 3.00 656 4,859 INTRMI DRILL TRIP T Trip in the hole from 656' to 4859'. Filled pipe at 1592', circulated a pipe volume at 3459' (Mud was aired up). 11:30 12:00 0.50 4,859 4,859 INTRM1 RIGMNT SVRG T Service rig floor equipment. 12:00 13:30 1.50 4,859 4,859 INTRMI RIGMNT SLPC T Slip 662' and cut 633' of drilling line. Inspect brake componenets, measure kick back rollers to be 1/8" f/ brake bands. 13:30 14:00 0.50 4,859 4,859 INTRMI RIGMNT SVRG T Inspect and service top drive. Grease swivel packing. 14:00 15:30 1.50 4,859 7,481 INTRMI DRILL TRIP T Trip through window @ 4932 to 4945', then in 7" open hole, tagged up at 7481'. Note: Between 7417' and 7461' is a 14.43 deg dog leg. 15:30 16:30 1.00 7,481 7,740 INTRMI DRILL REAM T Obtain parameters: PU wt 158k, SO wt 116k, Rot wt 127k. Pumping 320 gpm w/ 2690 psi. Rot w/ 60 rpm w/ 5k ft Ibs of torque. Ream f/ 7481' to 7740'. Page 18of58 • • Time Logs Date From To. Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:00 1.50 7,700 7,740 INTRMI DRILL DDRL T Trough hole at 7700' to 7740' to ensure sidetrack of 3N -16A original hole. A hard spot at 7740'. 18:00 18:45 0.75 7,740 7,756 INTRMI DRILL DDRL T Drill from 7740' to 7756', sliding 30 left. Hanging up w/ poor weight transfer. 18:45 21:00 2.25 7,756 7,788 INTRMI DRILL DDRL T Rotate 7756' to 7766', trying to clean up hole. Slide 7766' to 7788' at 45 left. 21:00 21:30 0.50 7,788 7,788 INTRM1 DRILL REAM T Work pipe free after packing off at 7788'. Jar free w/ 200k. reestablish circulation, pumping 304 gpm w/ 2300 psi. 21:30 22:30 1.00 7,788 7,788 INTRM1 DRILL REAM T Pull up, rack back a stand , then backream from 7740' to 7650'. Orient 180 deg at 7740', slide from 7740' to 7788'. 22:30 23:15 0.75 7,788 7,808 INTRMI DRILL DDRL T Rotate 7788' to 7800', trying to clean up hole, then orient 180. Slide 7800' to 7808'. ABI inclinations showing in old hole. Tight hole at 7808'. 23:15 00:00 0.75 7,800 7,700 INTRMI DRILL REAM T Work free at 7808', backream from 7751' to 7700'. Orient to 180 deg, slide back from 7700' to 7740', toughing hole on low side. 06/03/2010 Sidetracking hole from 7740' to 7759', trough 7700' to 7740', time drill 7740' to 7743' @ 1' /hr, time drill 7743' to 7745' @ 2' /hr, time drill 7745' to 7747' @ 3' /hr, slide 170 right from 7747' to 7758', rotate from 7758' to 7773', slide high side f/ 7773' to 7803', rotate f/ 7803' to 7813', slide high side f/ 7813' to 7833', work pipe whjile circulating to discuss dropping tendency observed at ABI. Decision to pull out and check BHA. Monitor well - static, POOH f/ 7833' to 6152', monitor well- static. Pump a 18 bbl dry job. Trip out to MWD tools. Pull bit above floor, check scribe on the motor to MWD. MWD had tightened 101.4 deg to the right. Motor had a bend approx 6' down f/ the top of the box. Download MWD, finish la ing down BHA. 00:00 02:30 2.50 7,740 7,759 INTRMI DRILL DDRL T Drill - Sliding 7740' to 7759'. ABI indicates probably in the original hole. Pull up to trough again. 02:30 04:30 2.00 7,700 7,740 INTRM1 DRILL REAM T Trough from 7700' to 7740'. Pumping 304 gpm w/ 2330 psi. 0 to 2k weight on bit. Oriented 180. 04:30 07:30 3.00 7,740 7,743 INTRM1 DRILL DDRL T Time drill (sliding 180 deg) from 7740' to 7743' at 1' /hr. Pumping 325 gpm w/ 2490 psi. Weight on bit 0 to 1 k. 07:30 08:30 1.00 7,743 7,745 INTRMI DRILL DDRL T Time drill (sliding 180 deg) from 7743' to 7745' at 2' /hr. Pumping 325 gpm w/ 2490 psi. Weight on bit 0 to 1k. 08:30 09:15 0.75 7,745 7,747 INTRMI DRILL DDRL T Time drill (sliding 180 deg)) from 7745' to 7747' at 3' /hr. Pumping 325 gpm w/ 2490 psi. Weight on bit 0 to 1 k. 09:15 12:00 2.75 7,747 7,758 INTRM1 DRILL DDRL T Drill (sliding 170 right) 7747' to 7758' . Pumping 330 gpm w/ 2660 psi. Weight on bit 3 to 5k. 12:00 13:15 1.25 7,758 7,773 INTRMI DRILL DDRL T Directional drilling from 7758' to 7773' . Pumping 324 gpm w/ 2530 psi. Weight on bit 10 to 15k. Rotate 60 rpm. Page 19 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 14:15 1.00 7,813 7,803 INTRMI DRILL DDRL T Drill (sliding high side) from 7773' to 7803' . Pumping 330 gpm w/ 2660 psi. Weight on bit 10 to 15k. 14:15 14:30 0.25 7,803 7,813 INTRMI DRILL DDRL T Directional drilling from 7803' to 7813' . Pumping 324 gpm w/ 2530 psi. Weight on bit 10 to 15k. Rotate 60 rpm. 14:30 15:45 1.25 7,813 7,833 INTRMI DRILL DDRL T Drill (sliding high side) from 7813' to 7833' . Pumping 324 gpm w/ 2530 psi. Weight on bit 10 to 15k. 15:45 16:45 1.00 7,833 7,833 INTRM1 DRILL CIRC T Working pipe, circulating while discussing options w/ rig team on a dropping tendency observed w/ ABI. Pumping 324 gpm w/ 2630 psi. Rotating 60 rpm. Will POOH, check BHA. 16:45 17:00 0.25 7,833 7,833 INTRM1 DRILL OWFF T Monitor well- static. 17:00 18:00 1.00 7,833 6,152 INTRMI DRILL TRIP T Trip out to check BHA. Pull from 7833' to 6152'. 18:00 18:15 0.25 6,152 6,152 INTRM1 DRILL OWFF T Monitorwell- static. 18:15 18:30 0.25 6,152 6,152 INTRMI DRILL CIRC T Pump a 18 bbl dry job. 18:30 21:00 2.50 6,152 656 INTRMI DRILL TRIP T Trip out to check BHA. Pull from 6152' to 656' (BHA). Calculated displ 45.5 bbls, actual 45 bbls. No problem pulling through window at 4945' to 4932'. 21:00 21:30 0.50 656 96 INTRM1 DRILL TRIP T Stand back 3 stands of HWDP, jars, stand of flex collars and 1 more stand of HWDP. 21:30 22:00 0.50 96 60 INTRMI DRILL PULD T Pull bit to the floor. Check scribe on mud motor to MWD. MWD turned to the right 101.4 deg from initial orientation. Also the motor was bent at approx 6' down from the box. After looking over tools, run in the hole to download. 22:00 22:30 0.50 60 60 INTRMI DRILL PULD T Download MWD. 22:30 00:00 1.50 60 0 INTRM1 DRILL PULD T Lay down BHA. Break off bit. 06/04/2010 Clean floor, pull wear bushing, drain stack, set test plug, test top pipe rams w/ 2 -7/8" test joint to 250 psi low and 3500 psi high, PJSM, change saver sub on the top drive, service top drive, PJSM, PU/MU 30 jts of 2 -7/8" 6.5ppf L -80 EUE tubing stinger (955'), run in the hole on 4" drill pipe to 4932', continue to run past window to 5046', work through a tight spot taking 3k wt, work to 5203', set down 5k, work pipe, decide to POOH and change up mule shoe joint. Pull out of the hole f/ 5203' to 5066', monitor well- static, continue to pull out f/ 5066' to 4880', circulate a string volume at 3 bpm w/ 420 psi, monitor well, blow down the top drive. Pull out of the hole w/ 4" dp, RU, then lay down 30 jts of 2 -7/8" tbg, modify the mule shoe ( shorten 4', orange peel end w/ 1 -1/2" hole, add (9) 1/2" holes on the side the last 4 -1/2' of joint), MU /RIH w/ 30 jts of 2 -7/8" 6.5 ppf L -80 EUE tbg, crossover to 4" dp, RIH f/ derrick from 951' to 5806', break circulation. 00:00 00:30 0.50 INTRMI DRILL OTHR T Clean and clear rig floor. 00:30 02:00 1.50 INTRM1 WHDBO BOPE T Pull wear bushing, drain stack, set FMC test plug. Rig up 2 -7/8" test equipment. PJSM. Test upper pipe rams (2 -7/8" x 5 ") w/ 2 -7/8" test joint. Page 20 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:30 2.50 INTRM1 WHDBO BOPE T Test upper pipe rams (2 -7/8" x 5 ") w/ 2 -7/8" test joint. Test to 250 psi low and 3500 psi high. Chart test. Test plug leaked, pull test plug, drain stack, dress test plug, clean up "O" ring seals on test plug, install test plug. Test to 250 psi low and 3500 psi high. Good test. Pull test plug, drain stack set 6 -3/8" ID FMC wear ring. 04:30 04:45 0.25 INTRM1 RIGMNT SFTY T Pre job safety meeting on changing saver sub on the top drive. 04:45 07:30 2.75 INTRM1 RIGMNT SVRG T Change out the 4" XT -39 saver sub on the top drive. Calibrate block height f/ TOTCO, service top drive. 07:30 07:45 0.25 INTRM1 CEMEN" SFTY T Pre job safety meeting on picking up 2 -7/8" cementing stinger. 07:45 10:15 2.50 0 955 INTRMI CEMEN" PULD T Pick up/ Make up 30 joints of 2 -7/8" 6.5 ppf L -80 EUE tubing to 955'. Average MU torque 2200 ft lbs. First joint is bent 6.4' from pin end, outside to outside measaures 6.75" with a mule shoe end. 10:15 10:30 0.25 955 955 INTRMI CEMEN' RURD T Rig down tongs. 10:30 10:45 0.25 955 955 INTRMI CEMEN" PULD T Make up two crossovers (4" XT39 x 3 -1/2" IF and 3 -1/2" IF x 2 -7/8" EUE) 10:45 12:00 1.25 955 2,730 INTRMI CEMEN "TRIP T Trip in the hole w/ 2 -7/8" sting on 4" drill pipe from the derrick from 955' to 2730'. 12:00 12:30 0.50 2,730 4,932 INTRM1 CEMEN" TRIP T Continue trip in the hole w/ 2 -7/8" sting on 4" drill pipe from the derrick from 2730' to 4932'. PU wt 91k, SO wt 83k. 12:30 13:30 1.00 4,932 5,203 INTRM1 CEMEN ' TRIP T Continue past whipstock at 4932', tag up at 5046' w/ 3k. Work pipe 1/2 turns several times, work past 5046' and run in to 5203'. Set down at 5203' w/ 5k. Work around several times. 13:30 13:45 0.25 5,203 5,066 INTRMI CEMEN" TRIP T Pull out of the hole from 5203' to 5066'. 13:45 14:00 0.25 5,066 5,066 INTRMI CEMEN" OWFF T Monitor well- static. 14:00 14:15 0.25 5,066 4,880 INTRMI CEMEN' TRIP T Pull out of the hole from 5066' to 4880'. 14:15 14:30 0.25 4,880 4,880 INTRMI CEMEN CIRC T Circulate a pipe volume, pumping 3 bpm w/ 420 psi 14:30 14:45 0.25 4,880 4,880 INTRMI CEMEN OWFF T Monitor well- static. Blow down the top drive. 14:45 16:15 1.50 4,880 955 INTRMI CEMEN TRIP T Pull out of the hole from 4880' to 955'. 16:15 16:30 0.25 955 955 INTRMI CEMEN' RURD T Rig up to lay down 2 -7/8" tubing stinger. 16:30 17:45 1.25 955 0 INTRM1 CEMEN" PULD T Lay down 30 jts of 2 -7/8" 6.5 ppf L -80 EUE tubing. Page 21 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 19 :15 1.50 0 0 INTRM1 CEMEN" OTHR T Welder modify the mule shoe ( shorten 4', orange peel end w/ 1 -1/2" hole, add (9) 1/2" holes on the side the last 4 -1/2' of joint). 19:15 19:30 0.25 0 0 INTRM1 CEMEN "SFTY T PJSM on picking up 2 -7/8" stinger. 19:30 21:00 1.50 0 951 INTRM1 CEMEN" PULD T PU /MU /RIH w/ 30 joints of 2 -7/8" 6.5 ppf L -80 EUE tubing to 951'. Average MU torque 2200 ft lbs. 21:00 21:30 0.50 951 951 INTRM1 CEMEN" PULD T Make up two crossovers (4" XT39 x 3 -1/2" IF and 3 -1/2" IF x 2 -7/8" EUE. 21:30 23 :30 2.00 951 5,806 INTRM1 CEMEN "TRIP T Trip in the hole w/ 2 -7/8" stinger on 4" drill pipe from 951' to 5806'. No problems going through the window @ 4932' to 4945'. 23:30 00:00 0.50 5,806 5,806 INTRM1 CEMEN" CIRC T Kelly up and break circulation at 5810'. Pumped 25 bbls. Pumping at 20 spm w/ 480 psi, 30 spm w/ 560 psi and 17% flow on TOTCO. 06/05/2010 Continue to run in the hole w/ 2 -7/8" cement stinger f/ 5806' to 6830', break circulation, continue from 6830' to 7492' (Tagged up), break circulation, continue to wash in the hole f/ 7492' to 7833', stand back a stand, then pick up to 7670', rotate pipe a quarter turn, slacking off to attempt to go into original hole w/ TD @ 8260', no -go, attempt 6 more times, no -go past 7752', pickup w/ heavy overpull and packoff, working pipe to free up, worked free, wash with higher pump rates to clean hole. Finally got back to 7833', circulate to clean hole - packed off again- worked free, spot 15 bbl gel pill, Pull out of the hole f/ 7738' to 7735'. Circulate bottom's up, PJSM, Dowell pump 7 bbis water, test to 2500, pump 26 bbis 16.5 ppq class "G" cement w/ additives, follow w/ 1 bbl water in the pipe, rig displace w/ 69 bbis mud. POOH f/ 7735' to 7300', install wiper ball in drill pipe, circulate hole volume (267 bbls) @ 6bpm w/ 1350 psi, Dowell pump 7 bbls water, pressure test to 2500 psi, mix and pump 28 bbls 16.5 ppg class "G" w/ additives, follow w/ 1 bbl water in the drill pipe. Rig pump 65 bbis of mud to balance cement. Pumping 4 bpm w/ 710 psi. PU wt 135k, SO wt 100k. Pull 2 -7/8" stinger out of cement from 7300' to 6367' (Pull 10 stands). Install wiper ball in the 4" drill pipe. Rig up, then circulate and condition mud. Circulate at 60 spm w/ 1330 psi while reciprocating pipe. PU wt 112k, SO wt 87k. Monitor well- static. Pump a dry job. Rig down lines, blow down. Pull out of the hole w/ 2 -7/8" cement stinger from 6367' to 951'. Rig up to lay down 30 jts of 2 -7/8" 6.5 ppf L -80 EUE tbg. Pull out of the hole, laying down 30 jts of 2 -7/8" tbg from 951'. The first 4 jts in the hole were bent badly. The orange peel jt had the original bend, the 1 -1/2" hole in bottom- and 7 of the 9 holes on the side were plugged with formation. R/D handling equipment. Clean and clear rig floor. PJSM, PU/MU BHA to 94', upload MWD, continue to MU BHA f/ 94' to 380'. Shallow test MWD. Good. 00:00 00:45 0.75 5,806 6,832 INTRMI CEMEN" TRIP T Trip in the hole w/ 2 -7/8" stinger on 4" drill pipe from 5806' to 6832'. 00:45 01:00 0.25 6,832 6,926 INTRM1 CEMEN" CIRC T Circulate while washing down f/ 6832' to 6926'. Pumping 17 spm ( 72 gpm) w/ 500 psi, 20 spm (84 gpm) w/ 520 psi. Pumped 25 bbls. 01:00 01:45 0.75 6,926 7,492 INTRM1 CEMEN" TRIP T Trip in the hole w/ 2 -7/8" stinger on 4" drill pipe from 6926' to 7492'. Tagged up w/ 5k wt at 7492'. PU wt 132k, SO wt 102k. 01:45 02:00 0.25 7,492 7,492 INTRM1 CEMEN" CIRC T Make a top drive connection. Pumping 15 spm, pressured up to 2000 psi. Bleed off, Pressure back up to 2500 psi before broke free. Then circulate 30 spm (127 gpm) w/ 700 psi- 19% TOTCO flow out. 02:00 02:15 0.25 7,492 7,583 INTRM1 CEMEN" WASH T Wash through 7492' to 7583', tagged up at 7583'. Pumping 30 spm (127 gpm) w/ 855 psi. Page 22 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 03:00 0.75 7,583 7,833 INTRMI CEMEN' WASH T Continue to wash in the hole f/ 7583' to 7768', continue to wash to bottom of sidetracked hole @ 7833', where it again took weight. PU wt 137 to 140k, SO wt 104k. Pumping 30 spm (127 gpm) w/ 700 psi. 03:00 03:30 0.50 7,833 7,738 INTRM1 CEMEN" WASH T Stand back a stand, pickup to 7665'. Turn pipe 1/4 turn then work down while pumping 40 spm (169 gpm) w/ 720 psi -20% flow out, stage up to 50 spm (211 gpm) w/ 900 psi -21 % flow out. tagged up @ 7738'. 03:30 04:15 0.75 7,665 7,739 INTRMI CEMEN" WASH T Continue to repeat picking up then turning a quarter turn, tagged at 7708'. Repeat picking up and turning. When at original spot able to go down to 7765 with no problems. Pick up, then another attempt to get in original hole w/ TD @ 8260' - -- tagged at 7739'. 04:15 04:45 0.50 7,739 7,752 INTRM1 CEMEN" WASH T Washed from 7739' to 7752'. Pumping 50 spm (211 gpm) w/ 890 psi. 04:45 05:15 0.50 7,752 7,739 INTRM1 CEMEN" WASH T Picked up from 7752'. Tight hole, packed off. Pulled to 175k with pressure increase to 1860 psi while pumping 50 spm (211 gpm). 05:15 05:45 0.50 7,739 7,665 INTRM1 CEMEN "CIRC T Working pipe, to clean hole. Increase pump rate to 72 spm ( 304 gpm) w/ 1350 psi- 25% flow out, then to 82 spm ( 346 gpm) w/ 1580 psi -30% flow out. Turn pipe a quarter turn to orient same as first time. 05:45 06:15 0.50 7,665 7,765 INTRM1 CEMEN" WASH T Wash down from 7665' to 7765', pumping 30 spm (127 gpm) w/ 510 psi 06:15 06:30 0.25 7,765 7,833 INTRM1 CEMEN" WASH T Make a connection, then continue to wash to 7765' to 7833' tagging up in the sidetrack hole. Pumping 30 spm ( 127 gpm) w/ 560 psi -18% flow out. 06:30 07:00 0.50 7,833 7,833 INTRM1 CEMEN' CIRC T Circulate while reciprocating pipe from 7833'. Pumping 80 spm (338 gpm) w/ 1680 psi. Packed off to 2675 psi at 7812'. Work pipe free, establish circulation, stage pumps up f/ 3 bpm ( 127 gpm) w/ 850 psi to 80 spm w/ 1680 psi. 07:00 07:30 0.50 7,833 7,833 INTRM1 CEMEN" CIRC T Circulate at 80 spm ( 338 gpm) w/ 1680 psi to clean up hole. Reciprocate pipe. 07:30 08:00 0.50 7,833 7,833 INTRMI CEMEN" CIRC T Spot 15 gel pill out of the 2 -7/8" stinger with bottom at 7833'. Pumping 75 spm (317 gpm) w/ 1570 psi, chase with 79 bbls of mud. 08:00 08:30 0.50 7,833 7,735 INTRM1 CEMEN T Pull out from 7833' to 7735'. 08:30 09:00 0.50 7,735 7,735 INTRM1 CEMEN "CIRC T Circulate bottom's up, pumping 80 spm (338 gpm) w/ 1570 psi. Page 23 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:15 0.25 7,735 7,735 INTRM1 CEMEN "SFTY T Pre job safety meeting on pumping cement. 09:15 09:45 0.50 7,735 7,735 INTRMI CEMEN" PUCM T Dowell pump 7 bbls water, test lines to 2500 psi, mix and pump 26 bbls 16.5 ppg class "G" w/ additives (1.06 cuft/sx ield 4.362 gal/sx mix water, Y 9 , 2 hr 54 min thickening time), pump 1 bbl water into pipe. 09:45 10:15 0.50 7,735 7,735 INTRMI CEMEN" DISP T Rig pump 69 bbls of mud to balance cement. Pumping 4.2 bpm (42 spm) w/ 590 psi. 10:15 10:45 0.50 7,735 7,300 INTRMI CEMEN "TRIP T Pull 2 -7/8" stinger out of cement from 7735' to 7300'. Pull 5 stands. 10:45 12:15 1.50 7,300 7,300 INTRMI CEMEN "CIRC T Drop pipe wiper ball in the 4" drill pipe. Rig up, then circulate hole volume of 267 bbls. Circulate at 60 spm (253 gpm) w/ 1350 psi while reciprocating pipe. Circulated a small amount of ceemnt to surface. PU wt 130k, SO wt 97k. 12:15 12:30 0.25 7,300 7,300 INTRMI CEMEN "SFTY T Pre job safety meeting on pumping cement 12:30 12:45 0.25 7,300 7,300 INTRMI CEMEN" PUCM T Dowell pump 7 bbls water, pressure test to 2500 psi, mix and pump 28 bbls 16.5 ppg class "G" w/ additives (1.06 cuft/sx yield, 4.362 gal /sx mix water, 2 hr 54 min thickening time), follow w/ 1 bbl water in the drill pipe. 12:45 13:00 0.25 7,300 7,300 INTRM1 CEMEN" DISP T Rig pump 65 bbls of mud to balance cement. Pumping 4 bpm (40 spm) w/ 710 psi. PU wt 135k, SO wt 100k. 13:00 13:30 0.50 7,300 6,367 INTRMI CEMEN "TRIP T Pull 2 -7/8" stinger out of cement from 7300' to 6367'. Pull 10 stands. 13:30 15:00 1.50 6,367 6,367 INTRMI CEMEN" CIRC T Drop pipe wiper ball in the 4" drill pipe. Rig up, then circulate and condition mud. Circulate at 60 spm ( 253 gpm) w/ 1330 psi while reciprocating pipe. PU wt 112k, SO wt 87k. 15:00 15:15 0.25 6,367 6,367 INTRMI CEMEN" OWFF T Monitor well- static. 15:15 15:45 0.50 6,367 6,367 INTRM1 CEMEN" CIRC T Pump a dry job. Rig down lines, blow down. 15:45 17:45 2.00 6,367 951 INTRMI CEMEN" TRIP T Pull out of the hole w/ 2 -7/8" cement stinger from 6367' to 951' 17:45 18:00 0.25 951 951 INTRMI CEMEN" RURD T Rig up to lay down 30 jts of 2 -7/8" 6.5 ppf L -80 EUE tbg 18:00 19:15 1.25 951 0 INTRM1 CEMEN" TRIP T Pull out of the hole, laying down 30 jts of 2 -7/8" tbg from 951'. Note: the first 4 joint in the hole were bent badly. The orange peel joint already had a bend. The bottom 1 -1/2" hole was plugged, as well as seven of the nine 1/2" holes in the bottom 4 -1/2' of the bent joint was plugged with formation. 19:15 19:45 0.50 INTRMI CEMEN" RURD T Rig down handling equipment f/ 2 -7/8 ". Page 24 of 58 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:15 0.50 INTRMI DRILL PULD T Clean and clear rig floor. 20:15 20:30 0.25 INTRMI DRILL SFTY T Pre job safety meeting on picking up BHA. 20:30 22:30 2.00 0 94 INTRMI DRILL PULD T Pickup/ Make up BHA. Orient 1.5 deg bend motor w/ MWD, make up bit. 22:30 23:00 0.50 94 94 INTRMI DRILL OTHR T Pickup, then, Upload MWD. 23:00 23:30 0.50 94 380 INTRMI DRILL PULD T Continue to make up BHA to 380'. 23:30 00:00 0.50 380 380 INTRMI DRILL DHEQ T Shallow test MWD. Pumping 65 spm (274 gpm) w/ 1275 psi. Good. Blow down 06/06/2010 Continue PU/MU BHA f/ 380' to 656', trip in the hole to 2524', H2S unannounced drill w/ post review, fill pipe, con't in the hole to 4394', continue to 4932' (set down 5k on top of window), pickup, orient to 30 right, slack off through window taking 10k wt, con't trip in to 6537', wash in the hole from 6537', set down 5k © 6594', Ream in the hole f/ 6537' to 6225', circulate hole while reciprocating, con't reaming in the hole to 7128', set back a stand, circulate bottom's up @ 7097, con't reaming 7097' to 7690' (tagged cement). Pull out of the hole f/ 7690' to 7658', mix and pump a 20 bbl hi vis sweep to surface, monitor well, pump a dry job, pull out of the hole f/ 7658' to 94'. Break the bit, check the scribe of motor to MWD. Note: Appears that the orientation of the MWD and motor again changed. MWD moved to the right 30 degrees (30 deg less offset to the motor than when went in the hole). Download MWd, stand back motor and MWD. Clean and clear floor, rig up to PU 2 -7/8" 6.5 ppf L -80 EUE tbg stinger, PJSM, Pick up/ Make up cement stinger (orange peeled joint w/ (20) 3/4" holes on the side up to 5' from the bottom end), plus 40 joints. Total length 1294.77' + two crossovers 2.5= Total length 1297.27' 00:00 01:15 1.25 380 2,524 INTRM1 DRILL TRIP T Continue to Make up BHA from 380' to 656', then run in the hole to 2524'. Drift 4" drill pipe with a 2 -1/4 "+ rabbit. 01:15 01:45 0.50 2,524 2,524 INTRM1 DRILL SFTY T Unannounced H2S drill with rig evacuation, followed with post review. 01:45 02:15 0.50 2,524 2,524 INTRM1 DRILL CIRC T Fill pipe @ 2524', pumping 126 gpm w/ 520 psi. 02:15 03:15 1.00 2,524 4,394 INTRMI DRILL TRIP T Continue to run in the hole. Drift 4" drill pipe w/ 2 -1/4" + rabbit. 03:15 03:45 0.50 4,394 4,394 INTRM1 DRILL CIRC T Fill pipe @ 4394', pumping 126 gpm w/ 520 psi. 03:45 04:30 0.75 4,932 4,932 INTRM1 DRILL TRIP T Run in the hole f/ 4394' to tag top of window at 4932' w/ 5k set down. Orient motor to 30 right. Slack off w/ 10k loss of weight while going across window. 04:30 05:30 1.00 4,950 6,537 INTRM1 DRILL TRIP T Continue to run in the hole from 4950' to 6537'. Drift 4" drill pipe w/ 2 -1/4" + rabbit. 05:30 06:15 0.75 6,537 6,594 INTRM1 DRILL WASH T Make a top drive connection and begin washing in the hole from 6537' to tag w/ 5 to 7k at 6594'. Obtain slow pump rates. Wash w/ 84 gpm w/ 487 psi. PU wt 145k, SO wt 99k. Rotate 40 rpm w/ 6 to 7k ft Ibs of torque. Pumping 317 gpm w/ 2580 psi. Rotate down f/ 6594' to 6630'. PU wt 145k, SO wt 105k, Rot wt 121k. ECD's 11.3 to 11.14 ppg. 06:15 06:45 0.50 6,625 6,625 INTRMI DRILL CIRC T Reciprocate from 6625' to 6537'. Circulate to clean up hole. Pumping 325 gpm w/2600 psi. Page 25 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 10:15 3.50 6,625 7,128 INTRM1 DRILL REAM T Continue to rotate in the hole from 6625' to 7128'. Pumping 321 gpm w/ 2740 psi. PU wt 160k, SO wt 108k, Rot wt 124k. ECD's 11.3 to 11.14 ppg. Taking surveys. 10:15 10:45 0.50 7,128 7,097 INTRM1 DRILL CIRC T Circulate bottom's up, pumping 320 gpm w/ 2850 psi, rotate 60 rpm w/ 8k ft Ibs of torque. Pulled a stand to 7097', then reciprocate. 10:45 12:15 1.50 7,097 7,284 INTRMI DRILL REAM T Continue to rotate in the hole from 7097' to 7284'. Rotating 60 rpm w/ 8k ft Ibs of torque, pumping 260 gpm w/ 1920 psi. PU wt 160k, SO wt 109k, Rot wt 125k. Taking surveys. 12:15 14:15 2.00 7,284 7,690 INTRMI DRILL REAM T Continue to rotate in the hole from 7284' to 7690'. Rotating 60 rpm w/ 8.5k ft Ibs of torque on bottom, 8k off bottom., pumping 307 gpm w/ 1920 psi on bottom, 2470 psi off bottom. PU wt 195k, SO wt 112k, Rot wt 132k. ECD's 10.86 ppg @ 7690'. Taking surveys. 14:15 14:30 0.25 7,690 7,658 INTRM1 DRILL TRIP T Pull out of the hole from 7690' to 7658'. 14:30 16:15 1.75 7,658 7,658 INTRM1 DRILL CIRC T Mix and pump a 20 bbl hi vis sweep. Then circulate bottom's up. Pumping 300 gpm w/ 2470 psi. 16:15 16:30 0.25 7,658 7,658 INTRM1 DRILL OWFF T Monitor well- static. 16:30 17:00 0.50 7,658 7,658 INTRM1 DRILL CIRC T Pump a dry job. Blow down top drive. 17:00 19:45 2.75 7,658 656 INTRMI DRILL TRIP T Pull out of the hole f/ 7658' to 656'. 19:45 20:30 0.75 656 94 INTRM1 DRILL TRIP T Stand back BHA f/ 656' to 94'. 20:30 21:00 0.50 94 94 INTRMI DRILL PULD T Pick up, break bit, check scribe and orientation of motor and MWD. Note: Appears that the orientation of the MWD and motor again changed. MWD moved to the right 30 degrees (Less offset to the motor than when went in the hole). 21:00 22:00 1.00 94 94 INTRMI DRILL PULD T Pickup, then download MWD. Stand back motor and MWD. Rig up to run 2 -7/8" 6.5 ppf L -80 EUE tbg. 22:00 22:15 0.25 INTRM1 DRILL SFTY T Pre job safety meeting on making up cement stinger f/ setting kick off/ sidetrack plug. 22:15 00:00 1.75 0 1,297 INTRMI CEMEN" PULD T Pick up/ Make up cement stinger (orange peeled joint w/ (20) 3/4" holes on the side up to 5' from the bottom end), plus 40 joints. Total length 1294.77' + two crossovers 2.5= Total length 1297.27' Page 26 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subc ode T Comment 06/07/2010 24 hr Summary RIH w/ cement stinger on 4" drill pipe f/ 1297' to 4848', work through window to 5965', circulate to unplug stinger, con't RIH to 6532'- tag up w/ 5k, wash down- pumping 4 bpm w/ 640 psi f/ 6532' to 7690', circulate and condition mud- pumping 7 bpm w/ 1240 psi. PJSM, pump balanced plug (36 bls cement), POOH from 7675' to 7178', circulate 7 bpm w/ 1670 psi, pump balanced plu ( 36 b cement) (calc TOC 6682'. CIP 1335 hrs 6/7/2010) , POOH from 7178' to 6245', circulate 7 bpm w/ 1410 psi, POOH f/ 6245' to 1297', RU then lay down 2 -7/8" stinger. Clean floor, rig down 2 -7/8" tools, rig up then flush BOP stack. PJSM on picking up BHA. Lay down Sperry Sun 4.75" motor, PU Sperry Sun 5" motor and stabilizer, make up bit 4RR2, mark connections on the stand, install crossover and torque w/ top drive to 10k ft Ibs of torque. Slight movement on the stabilizer that was just made up. Orient motor and MWd, continue to MU BHA to 280'. Prepare to shallow test. 00:00 01:45 1.75 1,297 4,848 INTRM1 CEMEN "TRIP T RIH w cement stinger on 4" drill pipe f/ 1297' to 4848'. PU wt 93k, SO wt 80k. Cement stinger (orange peeled joint w/ (20) 3/4" holes on the side up to 5' from the bottom end), plus 40 joints. Total length 1294.77' + two crossovers 2.5= Total length 1297.27' 01:45 02:15 0.50 4,848 5,965 INTRMI CEMEN "TRIP T Continue to RIH through the window w/ no problems @ 4932', RIH to 5965'. 02:15 02:45 0.50 5,965 5,965 INTRMI CEMEN" CIRC T Pipe displacement not correct (Plugged stinger). Pressure up to 2500 psi to break free. Establish circulation, then pump 50 bbls, initial 3 bpm w/ 460 psi, final 4 bpm w/ 600 psi. 02:45 03:30 0.75 5,965 6,532 INTRM1 CEMEN "TRIP T Continue to RIH f/ 5965' to 6532' (tagged w/ 5k wt). 03:30 06:45 3.25 6,532 7,690 INTRM1 CEMEN" WASH T Wash in the hole w/ 2 -7/8" cement stinger from 6532' to 7690'. Watching f/ 1 to 2k WOB. Pumping 4 bpm w/ 640 psi. At 6532': PU wt 125k, SO wt 90k At 7690 ": PU wt 142k, SO wt 95k. 06:45 09:30 2.75 7,690 7,690 INTRMI CEMEN 'CIRC T Circulate and condition mud and hole. Pumping 7 bpm w/ 1240 psi. Reciprocate f/ 7690' to 7635' 09:30 10:00 0.50 7,690 7,690 INTRMI CEMEN" RURD T Break top drive. Blow down. Rig up to cement. 10:00 10:15 0.25 7,690 7,690 INTRM1 CEMEN" SFTY T Pre job safety meeting on pumping balanced cement kick off plug (17 PPg)• 10:15 10:45 0.50 7,690 7,690 INTRMI CEMEN" PUCM T Dowell pump 10 bbls water, test lines to 2500 psi, mix and pump 36 bbls 17 ppg class "G" cement (yield 1 cuft/sx, 3.86 gal /sx water, thickening time 3 hr), follow with 1 bbl water in the pipe. 10:45 11:00 0.25 7,690 7,690 INTRMI CEMEN" DISP T Rig displace cement w/ mud, pumping 63.5 bbls at 4 bpm w/ 100 psi initial and 320 psi final. Cement in place 1100 hrs 6/7/2010. 11:00 11:30 0.50 7,690 7,186 INTRM1 CEMEN" RURD T Rig down circulating equipment. Pull out of the hole from 7690' to 7186'. Page 27 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:45 1.25 7,186 7,186 INTRM1 CEMENT CIRC T Rig up circulating equipment. Stage pumps up from 3 bpm w/ 460 psi to 7 bpm w/ 1670 psi. Reciprocated from 7186' to 7138'. PU wt 130k, SO wt 90k. Dumped some mud with cement to the cuttings box. 12:45 13:00 0.25 7,186 7,186 INTRM1 CEMENT SFTY T Pre job safety meeting on pumping balanced cement kick off plug (17 PPM- 13:00 13:15 0.25 7,186 7,186 INTRM1 CEMENT PUCM T Dowell pump 10 bbls water, test lines to 2500 psi, mix and pump 36 bbls 17 ppg class "G" cement (yield lcuft/sx, 3.86 gal /sx water, thickening time 3 hr), follow with 1 bbl water in the pipe. 13:15 13:30 0.25 7,186 7,186 INTRMI CEMEN DISP T Rig displace cement w/ mud, pumping 58 bbls at 5 bpm w/ 100 psi initial and 900 psi final. Cement in place 1335 hrs 6/7/2010. 13:30 13:45 0.25 7,186 7,186 INTRM1 CEMENT RURD T Rig down circulating equipment. 13:45 14:30 0.75 7,186 6,245 INTRMI CEMENT TRIP T Pull out of the hole from 7186' to 6245'. 14:30 14:45 0.25 6,245 6,245 INTRMI CEMENT RURD T Rig up circulating equipment. 14:45 15:15 0.50 6,245 6,245 INTRMI CEMENT CIRC T Circulate, stage pumps up from initial 3 bpm w/ 420 psi to 7 bpm w/ 1410 psi. Circulate surface to surface conditioning mud. Dumped some mud with cement to the cuttings box. 15:15 15:30 0.25 6,245 6,245 INTRMI CEMENT OWFF T Monitor well- static. 15:30 15:45 0.25 6,245 6,245 INTRMI CEMENT CIRC T Pump dry job, drop 2 -3/16' rabbit. 15:45 18:00 2.25 6,245 1,297 INTRM1 CEMENT TRIP T Pull out of the hole with 2 -7/8" cementing stinger from 6245' to 1297', on the trip tank. 18:00 18:15 0.25 1,297 1,297 INTRMI CEMENT RURD T Rig up to lay down 40 jts plus orange peeled joint of 2 -7/8" 6.5 ppf L -80 EUE tubing stinger. 18:15 18:30 0.25 1,297 1,295 INTRMI CEMEN' PULD T Break off the two crossovers. 18:30 19:30 1.00 1,295 0 INTRMI CEMENT TRIP T Pull out of the hole w/ 2 -7/8" tbg. Found rabbit in the tubing, recovered same. 19:30 20:00 0.50 INTRMI DRILL OTHR T Clean and clear floor. 20:00 20:30 0.50 INTRM1 DRILL RURD T Rig down tubing handling tools. 20:30 21:00 0.50 INTRMI DRILL PULD T Rig up, then flush BOP stack w/ washing tool. Rig down. 21:00 21:15 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on picking up BHA. 21:15 22:30 1.25 0 84 INTRM1 DRILL PULD T Lay down Sperry drill 4.75" motor w/ 1.5 deg bend, Pick up Sperry 5" motor w/ 1.5 deg bend, make up stablizer, make up bit 4RR2, make up crossover on top of stand. Page 28 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 22:45 0.25 84 84 INTRMI DRILL PULD T Mark connections, torque to 10k w/ the top drive, check marks for movement. Slight movement on the stabilizer, all other connections did not move. 22:45 23:00 0.25 84 84 INTRMI DRILL PULD T Orient 5" motor (1.5 deg bend) and MWD. 23:00 23:45 0.75 84 84 INTRMI DRILL PULD T Upload MWD. 23:45 00:00 0.25 84 280 INTRMI DRILL TRIP T Continue to MU BHA to 280'. Prepare to shallow test. 06/08/2010 Shallow test Sperry Sun MWD at 280', RIH to 4850', orient to 45 right, slide through window, RIH to 5068' (tag w/ 12k), ream to ream to 5128'. Survey. Wash and ream f/ 5128' to 5221', survey, RIH to 5408', survey, wash 5408' to 5501', survey, RIH f/ 5501' to 5782', Survey at 5782', survey at 5875', RIH f/ 5875' to 6248', survey. Ream in the hole f/ 6248' to 7087'- looking for cement top. Obtain surveys on each stand. Circulate and condition mud ar 7087'. continue to w ash and /or ream in the hole from 7087' to 7305' -- loo for the ton of cement plug- no hard cement found. Send mud sample to Dowell to run compressive strength tests with 10 %, 30 %, & 50% mud contamination. Pump out of the hole from 7305' to 6806'. Pull out from 6806' to 4850' (above window). Wait on cement test results. Pull a stand from 4850' to 4756'. H2S drill with post recap. Continue to wait on cement tests -- no compresssive strength after 6 hrs. The original UCA with 100% mixed cement was 500 psi after 6 hrs. 00:00 00:15 0.25 280 280 INTRMI DRILL DHEQ T Shallow test Sperry Sun MWD at 280'. Pumping 275 gpm w/ 1160 psi. 00:15 00:30 0.25 280 280 INTRMI DRILL OTHR T Blow down the top drive. 00:30 02:45 2.25 280 4,850 INTRM1 DRILL TRIP T Trip in the hole f/ 280' to 4850' w/ BHA #11 02:45 03:00 0.25 4,850 5,035 INTRM1 DRILL CIRC T Orient motor to 45 right prior to exiting window. PU wt 112k, SO wt 87k. Pumping 64 spm w/ 1830 psi. Slide through window w/ 3k drag. 03:00 03:30 0.50 5,035 5,128 INTRM1 DRILL REAM T Continue trip in f/ 5035'. Tagged at 5068' w/ 12k. Obtain survey, then ream to 5128'. Survey. 03:30 05:30 2.00 5,128 6,248 INTRMI DRILL TRIP T Wash and ream f/ 5128' to 5221', survey, RIH to 5408', survey, wash 5408' to 5501', survey, RIH f/ 5501' to 5782', Survey at 5782', survey at 5875', RIH f/ 5875' to 6248', survey. PU wt 112, SO wt 87k, Rot wt 106k. 05:30 08:30 3.00 6,248 7,087 INTRMI DRILL REAM T Ream in the hole f/ 6248' to 7087'- - looking for the top of cement plug.. Obtain surveys on each stand. Pumping 278 gpm w/ 2050 psi. (motor turning 222 rpm). Rotate 50 to 60 rpm w/ 6 to 7k ft lbs of torque. PU wt 163k, SO wt 106k, Rot wt 120k. 08:30 10:00 1.50 7,087 7,087 INTRM1 DRILL CIRC T Circulate and condition mud @ 7087'. Pumping 296 rpm w/ 2460 psi (motor turning 237 rpm). Rotate 50 rpm w/ 7k ft lbs of torque. Page 29 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:30 1.50 7,087 7,305 INTRMI DRILL REAM T Continue to wash /Ream in the hole looking for cement. Ream f/ 7087' to 7305'. Pumping 127 gpm w/ 700 psi (motor turning 102 rpm). Send mud sample to Dowell to run compressive strength tests with 10 %, 30 %, & 50% mud contamination. 11:30 12:30 1.00 7,305 6,806 INTRM1 DRILL TRIP T Pump out of the hole from 7305' to 6806'. Pumping 252 gpm w/ 1840 psi. Rotate 60 rpm w/ 4 to 5k ft Ibs of torque. Ar 6806': PU wt 160k, SO wt 105k, Rot wt 125k 12:30 13:30 1.00 6,806 4,850 INTRM1 DRILL TRIP T Pull out of the hole to above window. Pull f/ 6806' to 4850' on elevators. 13:30 20:15 6.75 4,850 4,850 INTRMI DRILL WOC T Wait on cement test results. Perform service on mis equip on the rig, general housekeeping and painting. Working on planetary shaft installation. Change out supper tugger cable. 20:15 21:00 0.75 4,850 4,756 INTRMI DRILL SFTY T H2S drill while POOH drill w/ post recap. Pull one stand and set back f/ 4850' to 4756'. 21:00 00:00 3.00 4,756 4,756 INTRM1 DRILL WOC T Continue to wait on cement test results. Dowell running compressive strength tests with 10 %, 30 %, & 50% mud contamination. No compressive strength after 6 hrs. The original UCA with 100% mixed cement was 500 psi after 6 hrs. 06/09/2010 Continue to wait on cement (Bit @4756') (hole cleaned out to 7305'), monitor well- static, Pump 10 bbl dry job, mud clabbered up, RIH f/ 4756', orient @ 4850', pass through window , trip in to 5500', circulate and condition 1 -1/2 hole volumes, monitor well- static, POOH to 4850', pump dry job, POOH f/ 4850' to 646', monitor well- static, work BHA, download MWD, check orientation of motor and MWD- no change, break bit, change to a Sperrydrill 5" motor (1.5 deg bend) w/ ABI, MU same bit, check orientation, make up flex collars, shallow test tools at 260', continue to MU BHA to 625', trip in to 2234', POOH to 94', lay down Sperry Sun flex collar and float sub (overtorqued), PU new flex collar (ser # 11321319) and float sub (ser # 0834). MU BHA f/ 124' to 625', trip in the hole to 2493', fill pipe, trip in to 4362', fill pipe, trip in to 4850', orient motor 40 degrees right, pass through window w/ 7k drag. Continue trip in f/ 5015' to 5572', fill pipe, circ/survey @ 5572', trip in f/ 5572' to 6072', circ/survey @ 6072', trip in f/ 6072' to 6538', circ/survey @ 6538', trip in f/ 6538' to 7067'. Wash and ream in the hole from 7067' to 7285'. $low pumps down to 63 gpm (bit turning 50 rpm) w/ 330 psi. Slack off from 7285' to 7415', 10 to 15' /minute (600' /hr) with no indication of hard cement. Note: Cleaned hole to 7461' with no indication of hard cement, pumped dry job, POOH to inside casing to cut drilling line. Will F aafter rtrilling lines_' . ... '.. •• • .... s' 00:00 03:00 3.00 4,756 4,756 INTRMI DRILL WOC T Continue to wait on cement tests- - no compresssive strength after 6 hrs. The original UCA with 100% mixed cement was 500 psi after 6 hrs. 03:00 03:15 0.25 4,756 4,756 INTRMI DRILL OWFF T Monitor well- static. 03:15 03:30 0.25 4,756 4,756 INTRM1 DRILL CIRC T Pump 10 bbl dry job. Mud is clabbered up. 03:30 03:45 0.25 4,756 4,850 INTRM1 DRILL TRIP T Trip in the hole f/ 4756' to 4850'. 03:45 04:15 0.50 4,850 4,940 INTRMI DRILL TRIP T Trip in the hole from 4850' to 4940'. Saw 3 to 9k drag @ window. Page 30 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:00 0.75 4,940 5,500 INTRMI DRILL TRIP T Continue trip in the hole f/ 4940' to 5500'. 05:00 06:00 1.00 5,500 5,500 INTRMI DRILL CIRC T Circulate 1 -1/2 hole volumes to condition mud, reduce mud weight f/ 9.8ppg to 9.5 ppg. Initial circ rate 118 gpm w/ 750 psi, final circ rate 223 gpm w/ 1430 psi- ECD's 10.88 ppg. Rotate 40 rpm w/ 5k ft Ibs of torque. 06:00 06:15 0.25 5,500 5,500 INTRM1 DRILL OWFF T Monitor well- static. 06:15 06:45 0.50 5,500 4,850 INTRM1 DRILL TRIP T Pull out of the hole on elevators to inside casing. Pull 5500' to 4850'. 06:45 07:00 0.25 4,850 4,850 INTRMI DRILL OWFF T Monitor well- static. 07:00 07:30 0.50 4,850 4,850 INTRM1 DRILL CIRC T Pump dry job, blow down the top drive. 07:30 09:00 1.50 4,850 646 INTRMI DRILL TRIP T Pull out of the hole to change the motor to one with ABI from 4850' to 646' 09:00 09:15 0.25 646 646 INTRMI DRILL OWFF T Monitor well- static. 09:15 10:30 1.25 646 94 INTRMI DRILL TRIP T Stand back HWDP, drill collars, lay down circ sub f/ 646' to 94'. Calculated displacment 33.5 ppg, actual 33.5 bbls. 10:30 11:30 1.00 94 94 INTRMI DRILL OTHR T Download Sperry Sun MWD 11:30 11:45 0.25 94 94 INTRM1 DRILL OTHR T Check orientation of motor and MWD.No change f/ when it went in the hole. • 11:45 13:30 1.75 0 260 INTRMI DRILL OTHR T Break bit, change out motors. Make up same bit, check orientation of motor to MWD. Make up flex collars. 13:30 13:45 0.25 260 260 INTRM1 DRILL DHEQ T Fill pipe, shallow test MWD at 260'. Pumping 302 gpm w/ 1380 psi. 13:45 14:00 0.25 260 625 INTRM1 DRILL TRIP T Continue to make up BHA f/ 260' to 625'. 14:00 14:30 0.50 625 2,234 INTRM1 DRILL TRIP T Trip in the hole from 625' to 2234'. 14:30 15:30 1.00 2,234 656 INTRMI DRILL TRIP T Pull out of the hole f/ 2234' to lay down float sub. Float sub was overtorqued when made up. 15:30 16:30 1.00 656 94 INTRM1 DRILL TRIP T Stand back HWDP, drill collars, lay down circ sub f/ 646' to 94'. Lay down Sperry Sun flex collar ser # 11474147 and float sub ser # 0831. 16:30 17:00 0.50 94 124 INTRMI DRILL PULD T Pick up and make up Sperry Sun flex collar ser # 11321319 and float sub ser # 0834. 17:00 17:30 0.50 124 625 INTRMI DRILL TRIP T Make up BHA from 124' to 625'. 17:30 17:45 0.25 625 2,493 INTRMI DRILL TRIP T Trip in the hole from 625' to 2493'. 17:45 18:00 0.25 2,493 2,493 INTRMI DRILL CIRC T Fill pipe. Pumping 147 gpm w/ 640 psi. PU wt 80k, SO wt 75k. 18:00 18:45 0.75 2,493 4,362 INTRMI DRILL TRIP T Trip in the hole from 2493' to 4362'. 18:45 19:00 0.25 4,362 4,362 INTRMI DRILL CIRC T Fill pipe. Pumping 147 gpm w/ 710 psi. PU wt 100k, SO wt 83k. 19:00 19:15 0.25 4,362 4,850 INTRM1 DRILL TRIP T Trip in the hole from 4362' to 4850'. Page 31 of 58 • Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 19:15 19:30 0.25 4,850 4,850 INTRM1 DRILL CIRC T Orient motor 40 degree right. Pumping 270 gpm w/ 1830 psi. SO wt w/ pumps 82k. 19:30 19:45 0.25 4,850 5,015 INTRMI DRILL TRIP T Work through window f/ 4850' to 5015'. Observed 7k drag. 19:45 20:15 0.50 5,015 5,572 INTRM1 DRILL TRIP T Trip in the hole from 5015' to 5572'. 20:15 20:30 0.25 5,572 5,572 INTRMI DRILL CIRC T Survey @ 5572'. Pumping 260 gpm w/ 1810 psi. PU wt 120k, SO wt 86k. 20:30 20:45 0.25 5,572 6,072 INTRMI DRILL TRIP T Trip in the hole from 5572' to 6072'. 20:45 21:00 0.25 6,072 6,072 INTRMI DRILL CIRC T Survey @ 6072'. Pumping 260 gpm w/ 1830 psi. PU wt 132k, SO wt 90k. 21:00 21:15 0.25 6,072 6,538 INTRM1 DRILL TRIP T Trip in the hole from 6072' to 6538'. 21:15 21:45 0.50 6,538 6,538 INTRMI DRILL CIRC T Survey @ 6538'. Pumping 260 gpm w/ 1910 psi. PU wt 132k, SO wt 95k. 21:45 22:00 0.25 6,538 7,067 INTRMI DRILL TRIP T Trip in the hole from 6538' to 7067'. Rot wt 122k. 22:00 23:15 1.25 7,067 7,285 INTRMI DRILL REAM T Wash and ream from 7067' to 7285'. Rotate 40 rpm w/ 6 to 7k ft Ibs of torque. Pumping 290 gpm w/ 2200 psi. ECD's 11.03. PU wt 170k, SO wt 105k, Rot wt 125k. 23:15 00:00 0.75 7,285 7,415 INTRM1 DRILL REAM T Wash down from 7285' to 7415', pumping 15 -16 spm (63 gpm (motor turning 50 rpm), 330 psi initial, final 420 psi. Slack off at 10 to 15' /min _ (600' /hr). No indication of cement. 06/10/2010 Wash down from 7415' to 7461' Slack off speed 10 to 15' /minute (600' /hr) with no indication of hard cement. Set back a stand to 7441', pump a 17 bbl dry job, POOH f/ 7441' to 6507', blow down top drive, continue to POOH f/ 6507' to 4820', PJSM, slip and cut 85' of 1 -1/4" drilling line, trip in f/ 4820' to 5200', pick up a single, pick up as high as possible to trough, trough hole f/ 5135' to 5195' (oriented 120 left), displaced to 9.3 LSND mud while troughing, directional drill f/ 5195' to 5325', circulate and talk w/ Sperry Sun in town about surveys, continue to directional drill 6 -1/8" hole w/ Hycolog PDC and 5" SperryDrill 1.5 deg ABI motor from 5325' to 6150'. Note: Departure from 3N -16A at 51 • ' , • : la • 1 1 0 S7- Fr 3 00:00 00:15 0.25 7,415 7,461 INTRMI DRILL WASH T Wash down from 7415' to 7461', pumping 15 -16 spm (63 gpm (motor turning 50 rpm), 330 psi initial, final 420 psi. Slack off at 10 to 15' /min (600' /hr). No indication of cement. 00:15 00:30 0.25 7,461 7,441 INTRMI DRILL TRIP T Set back a stand from 7461' to 7441 00:30 00:45 0.25 7,441 7,441 INTRMI DRILL CIRC T Pump a 17 bbl dry job 00:45 01:15 0.50 7,441 6,507 INTRM1 DRILL TRIP T Pull out of the hole from 7441' to 6507' 01:15 02:30 1.25 6,507 4,820 INTRM1 DRILL TRIP T Continue to pull out of the hole from 6507' to 4820'. PU wt 116k, SO wt 87k. Saw 6 to 7k drag at window. 02:30 02:45 0.25 4,820 4,820 INTRM1 DRILL SFTY T PJSM on slip and cut drilling line. 02:45 03:45 1.00 4,820 4,820 INTRM1 RIGMNT SLPC T Slip and cut 85' of 1 -1/4" drilling line. Set crown -o- matic. Set TOTCO EDMS f/ block height. 03:45 04:45 1.00 4,820 5,200 INTRMI DRILL TRIP T Trip in the hole from 4820' to 5200'. Stand # 49 in the hole. Page 32 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:00 0.25 5,200 5,135 INTRMI DRILL TRIP T Pick up a single (30.76'), Pick up as high as possible to trough f/ 5135' to 5195'. 05:00 08:45 3.75 5,135 5,195 INTRM1 DRILL DDRL T Trough f/ 5135' to 5195'. Oriented 120 left. Pumping 70 spm 295 Gpm w/ 2220 psi. PU wt 120k, SO wt 87k. ECD's 11.49 to 11.28 ppg. Note: Departure from 3N -16A at 5195' at 0830 hrs 6/10/2010. Note: Displace to 9.3 ppg LSND mud while troughing @ 0820 hrs.. 08:45 10:30 1.75 5,195 5,325 INTRMI DRILL DDRL T Directional drill f/ 5195' to 5325' 3963 TVD). Actual rotating ' ) 9 time .56 hrs, actual sliding time .22 hrs, Total bit hrs .78 hrs. Jar hrs = 78.55 hrs. Pumping 291 gpm w/ 2050 psi on bottom, 1910 psi off bottom. Rotate 60 rpm w/ 5k ft Ibs of torque on bottom, 4k of torque off bottom. PU wt 122k, SO wt 92k, Rot wt 99k. 10:30 12:00 1.50 5,325 5,325 INTRM1 DRILL CIRC T Circulate, talking to Sperry Sun in town on surveys. Pumping 292 gpm w/ 1810 psi. Rotate 20 rpm w/ 4k ft Ibs of torque. Circulating , ECD 10.8 to 10.65 ppg. 12:00 00:00 12.00 5,325 6,150 INTRM1 DRILL DDRL T Directional drilling 6 -1/8" hole w/ Hycolog PDC and 5" SperryDrill 1.5 deg ABI motor from 5325' to 6150' (4652' TVD). Actual rotating time 4.5 hrs, actual sliding time 2.72. Total bit hrs = 8 hrs. Jar hrs 85.77 hrs. Drill w/ 2 to 6k WOB, pumping 292 to 299 gpm w/ 2070 to 2320 psi. ECD's 10.6 to 10.98 ppg. Rotating 60 rpm w/ 5 to 6k ft Ibs on bottom, 4 to 5k ft Ibs off bottom. PU wt 123 to 136k, SO wt 92 to 99k, Rot wt 99 to 108k. 06/11/2010 Directional drill 6 -1/8" hole w/ Hycolog PDC and 5" SperryDrill 1.5 deg ABI motor from 6150' to 7653' (6115' TVD). Note: Departure from 3N -16A at 5195' at 0830 hrs 6/10/2010. 5195' to 7833'= 3N- 16A -PB2 00:00 12:00 12.00 6,150 6,972 INTRMI DRILL DDRL T Directional drilling 6 -1/8" hole w/ Hycalog PDC and 5" SperryDrill 1.5 deg ABI motor from 6150' to 6972' (5454' TVD). ADT 9.51 hrs. Actual rotating time 8.7 hrs, actual sliding time .81. Total bit hrs = 17.51 hrs. Jar hrs 95.28 hrs. Drill w/ 5 to 7k WOB, pumping 296 gpm w/ 2330 psi. ECD's 10.98 ppg. Rotating 60 rpm w/ 7 k ft Ibs on bottom, 6 k ft Ibs off bottom. PU wt 155k, SO wt 109k, Rot wt 124k. Page 33 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 6,972 7,653 INTRMI DRILL DDRL T Directional drilling 6 -1/8" hole w/ Hycalog PDC and 5" SperryDrill 1.5 deg ABI motor from 6972' to 7653' (6115' TVD). ADT 8.98 hrs. Actual rotating time 5.94 hrs, actual sliding time 3.04. Total bit hrs = 26.49 hrs. Jar hrs 104.26 hrs. Drill w/ 4 to 7k WOB, pumping 299 gpm w/ 2350 psi. ECD's 10.98 to 10.74 ppg. Rotating 60 rpm w/ 7 to 8k ft Ibs on bottom, 6 to 7k ft Ibs off bottom. PU wt 167k, SO wt 116k, Rot wt 126k. 06/12/2010 Directional drill 6 -1/8" hole w/ Hycolog PDC and 5" SperryDrill 1.5 deg ABI motor from 7653' to 8000' (6373' TVD). Stand back a stand. Stand back a stand from 8000' to 7905'. Circulate and reciprocate from 7905' to 7810'. Pumping 320 gpm w/ 2700 psi. Rotate 60 rpm w/ 7k ft Ibs of torque. Continue to directional drill 6-1/8" hole w/ Hycalog PDC and 5" SperryDrill 1.5 deg ABI motor from 8000' to 8180' (6465' TVD). Drop a 1.76" ball to open the MI SWACO commander circ sub. Pump down at 4 bpm w/ 1090 psi. Once open, 4.5 bpm equals 650 psi. Pump a 20 bbl hi vis sweep. Pumping 428 gpm w/ 3170 psi initial. After sweep was out of the hole final rate of 452 gpm w/ 2450 psi. Monitor well- static. Pump a dry job. Blow down the top drive. Trip out of the hole from 8180' to 625'. Monitor well on the trip tank. Stand back jars and HWDP from 625' to 255'. Make a top drive connection. Pumping 35 spm w/ 20 psi- 13% TOTCO flow out. Increase rate to 50 spm w/ 22 psi - 22% TOTCO flow out. Drop a 1.76" OD ball, pressure to 1500 psi, then stage up in 200 psi increments to close MI SWACO commander circ tool. Closed at 2500 psi. Pressure to 50 spm w/ 720 psi and MWD detection observed. Blow down the top drive. Break commander tool at the ball catcher. Remove (4) 1.76" steel balls. Clean, dope and make up connection to 10500 ft Ibs of torque. Lay down circ sub. Lay down flex collars. Check orientation of MWD to motor. Downlaod Sperry Sun MWD. Finish laying down BHA. Clean and clear rig floor. PU Baker liner cementing head. Torque connections. Note: Departure from 3N -16A at 5195' at 0830 hrs 6/10/2010. 5195' to 7833'= 3N- 16A -PB2 00:00 10:30 10.50 7,653 8,000 INTRM1 DRILL DDRL T Directional drilling 6 -1/8" hole w/ Hycalog PDC and 5" SperryDrill 1.5 deg ABI motor from 7653' to 8000' (6373' TVD). ADT 7 hrs. Actual rotating time 2.05 hrs, actual sliding time 4.95. Total bit hrs = 33.49 hrs. Jar hrs 111.26 hrs. Drill w/ 4 to 10 k WOB, pumping 295 gpm w/ 2300 psi. ECD's 10.8 to 10.92 ppg. Rotating 60 rpm w/ 6 to 7k ft Ibs on bottom, 6 to 7k ft lbs off bottom. PU wt 169 to 180k, SO wt 116 to 115k, Rot wt 126 to 130k. 10:30 11:00 0.50 8,000 8,000 INTRMI DRILL CIRC T Stand back a stand from 8000' to 7905'. Circulate and reciprocate from 7905' to 7810'. Pumping 320 gpm w/ 2700 psi. Rotate 60 rpm w/ 7k ft Ibs of torque. Page 34 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 8,000 8,020 INTRM1 DRILL DDRL T Directional drilling 6 -1/8" hole w/ Hycalog PDC and 5" Sperry Drill 1.5 deg ABI motor from 8000' to 8020' (6386' TVD). ADT .46 hrs. Actual rotating time 0 hrs, actual sliding time .46. Total bit hrs = 33.95 hrs. Jar hrs 111.72 hrs. Drill w/ 4 to 10 k WOB, pumping 295 gpm w/ 2300 psi. ECD's 10.8 to 10.92 ppg. Rotating 60 rpm w/ 6 to 7k ft Ibs on bottom, 6 to 7k ft Ibs off bottom. PU wt 169 to 180k, SO wt 116 to 115k, Rot wt 126 to 130k. 12:00 14:30 2.50 8,020 8,180 INTRM1 DRILL DDRL T Directional drilling 6-1/8" hole w/ Hycalog PDC and 5" SperryDrill 1.5 deg ABI motor from 8020' to 8180' (6465' TVD). ADT 2.26 hrs. Actual rotating time 1.33 hrs, actual sliding time .93. Total bit hrs = 36.21 hrs. Jar hrs 113.98 hrs. Drill w/ 7 to 10 k WOB, pumping 297 to 292 gpm w/ 2410 psi. ECD's 10.92 to 10.99 ppg. Rotating 60 rpm w/ 7 to 10k ft Ibs on bottom, 7 to 8k ft Ibs off bottom. PU wt 180 to 181k, SO wt 116 to 117k, Rot wt 130 to 135k. 14:30 15:00 0.50 8,180 8,180 INTRM1 DRILL CIRC T Drop a 1.76" ball to open the MI SWACO commander circ sub. Pump down at 4 bpm w/ 1090 psi. Once open, 4.5 bpm equals 650 psi. 15:00 15:45 0.75 8,180 8,180 INTRM1 DRILL CIRC T Pump a 20 bbl hi vis sweep. Pumping 428 gpm w/ 3170 psi initial. After sweep was out of the hole final rate of 452 gpm w/ 2450 psi. 15:45 16:00 0.25 8,180 8,180 INTRM1 DRILL OWFF T Monitorwell- static. 16:00 20:00 4.00 8,180 625 INTRM1 DRILL TRIP T Trip out of the hole from 8180' to 625'. Monitor well on the trip tank. 20:00 20:15 0.25 625 255 INTRM1 DRILL TRIP T Stand back jars and HWDP from 625' to 255'. 20:15 21:30 1.25 255 255 INTRM1 DRILL CIRC T Make a top drive connection. Pumping 35 spm w/ 20 psi- 13% TOTCO flow out. Increase rate to 50 spm w/ 22 psi- 22% TOTCO flow out. Drop a 1.76" OD ball, pressure to 1500 psi, then stage up in 200 psi increments to close MI SWACO commander circ tool. Closed at 2500 psi. Pressure to 50 spm w/ 720 psi and MWD detection observed. Blow down the top drive. Break commander tool at the ball catcher. Remove (4) 1.76" steel balls. Clean, dope and make up connection to 10500 ft Ibs of torque. Lay down circ sub. 21:30 22:00 0.50 255 93 INTRM1 DRILL PULD T Lay down flex collars. Check orientation of MWD to motor. Page 35 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:45 0.75 93 93 INTRMI DRILL PULD T Downlaod Sperry Sun MWD. 22:45 23:45 1.00 93 0 INTRM1 DRILL PULD T Finish laying down BHA. 23:45 00:00 0.25 0 0 INTRMI DRILL PULD T PU Baker liner cementing head. Torque connections. 06/13/2010 Finish applying torque to the connections on Baker liner cementing head. Pull FMC wear bushing. Install FMC test plug (7" OD). Rig up testing equipment for BOPE testing. Fill stack with water. Testing BOPE. Witness of test waived by AOGCC inspector John Crisp. Test w/ 3 -1/2" test joint —lower pipe rams (3 -1/2" x 6 ") and upper pipe rams (2 -7/8" x 5 ") to 250 psi low and 3500 psi high. Test annular to 250 psi low and 2500 psi high. Chart tests, 5 min test each. Testing choke manifold, floor safety valves and top drive IBOP valves to 250 psi low and 3500 psi high. Test w/ 4" test joint - -lower pipe rams (3-1/2" x 6 ") and upper pipe rams (2 -7/8" x 5 ") to 250 psi low and 3500 psi high. Test annular to 250 psi low and 2500 psi high. Chart tests, 5 min test each. Test w/ 5 -1/2" test joint - -lower pipe rams to 250 psi low and 3500 psi high. Test annular to 250 psi low and 2500 psi high. Chart tests, 5 min test each. Test accumulator, initial pressure 2950, after closure 1750 psi, 200 psi build up in 21 seconds, full charge in 92 sec. Tested gas alarms. Valve #14 in choke manifold leaked, replaced seat and gate, retested, OK. Rig down testing equipment. Drain stack. Blow down the choke and kill lines. Install FMC wear bushing, 6 -3/8" ID. Rig down test equipment, install FMC 6 -3/8" wear bushing, PJSM, PU/MU BHA, test Smith Rhino Reamer, Test Sperry Sun MWD, Make up Sperry Sun motor, adjust bend to 1.15 deg, orient, baker lock bulinose on Smith Rhino Reamer. Trip in the hole to 4883', go through window (4932' to 4945')- no indication, continue to 5135' survey and orient 90 left , continue to 5316', Ream with surveys every stand to 5721', then survey every other stand to 6089' at midnight. Max traveling speed 300' /hr, Max pump rate 320 gpm. Motor turning 93 rpm w/ 70 rpm top drive = combined 163 rpm at the Smith Rhino Reamer. Note: Departure from 3N -16A at 5195' at 0830 hrs 6/10/2010. 5195' to 7833'= 3N- 16A -PB2 Note: 3N- 16APB1= 7740' to 8260', with departure at 7740'. 00:00 00:15 0.25 0 0 INTRMI DRILL PULD T Finish applying torque to the connections on Baker liner cementing head. 00:15 01:00 0.75 0 0 INTRM1 WHDBO NUND T Pull FMC wear bushing. Install FMC test plug (7" OD). 01:00 01:45 0.75 0 0 INTRMI WHDBO BOPE T Rig up testing equipment for BOPE testing.. Fill stack with water. Page 36 of 58 . • Time Logs Date From ` To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 11:30 9.75 0 0 INTRMI WHDBO BOPE T Testing BOPE. Witness of test waived by AOGCC inspector John Crisp. Test w/ 3-1/2" test joint - -lower pipe rams (3 -1/2" x 6 ") and upper pipe rams (2 -7/8" x 5 ") to 250 psi low and 3500 psi high. Test annular to 250 psi low and 2500 psi high. Chart tests, 5 min test each. Testing choke manifold, floor safety valves and top drive IBOP valves to 250 psi low and 3500 psi high. Test w/ 4" test joint - -lower pipe rams (3 -1/2" x 6 ") and upper pipe rams (2 -7/8" x 5 ") to 250 psi low and 3500 psi high. Test annular to 250 psi low and 2500 psi high. Chart tests, 5 min test each. Test w/ 5 -1/2" test joint - -lower pipe rams to 250 psi low and 3500 psi high. Test annular to 250 psi low and 2500 psi high. Chart tests, 5 min test each. Test accumulator, initial pressure 2950, after closure 1750 psi, 200 psi build up in 21 seconds, full charge in 92 sec. Tested gas alarms. Valve #14 in choke manifold leaked, replaced seat and gate, retested, OK. 11:30 12:15 0.75 0 0 INTRMI WHDBO RURD T Rig down testing equipment. Drain stack. Blow down the choke and kill lines. 12:15 12:30 0.25 0 0 INTRMI WHDBO NUND T Install FMC wear bushing, 6 -3/8" ID. 12:30 12:45 0.25 0 0 INTRMI DRILL SFTY T Pre job safety meeting on picking up BHA (Rhino Reamer). 12:45 13:45 1.00 0 0 INTRMI DRILL PULD T Make up BHA. 13:45 14:15 0.50 0 3 INTRMI DRILL DHEQ T Test Rhino Reamer- blades open when pumping 231 gpm w/ 550 psi. Test again, blades open when pumping 189 gpm w/ 450 psi. Shallow pulse test MWD. Break the bit and Rhino Reamer. 14:15 15:00 0.75 0 96 INTRM1 DRILL PULD T Make up the Sperry Drill 4 -3/4" motor, adjust bend to 1.15 deg bend. Orient motor to MWD. Make up Rhino Reamer and bakerlock the bullnose below the reamer. 15:00 15:15 0.25 96 585 INTRM1 DRILL TRIP T Continue to make up BHA #13 (Rhino Reamer w/ bullnose) f/ 96' to 585'. 15:15 17:00 1.75 585 4,883 INTRMI DRILL TRIP T Trip in the hole w/ BHA #13 (Rhino Reamer w/ bullnose) f/ 585' to 4883'. PU wt 105k, SO wt 87k. 17:00 17:15 0.25 4,883 5,135 INTRM1 DRILL TRIP T Trip in the hole w/ BHA #13 (Rhino Reamer w/ bullnose) f/ 4883' to 5135'. No indication going through window @ 4932' to 4945'. Page 37 of 58 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:00 0.75 5,135 5,135 INTRM1 DRILL CIRC T Orient motor to 90 left at 5135'. Pumping 292 gpm w/ 1800 psi. Note: Open hole sidtrack at 5195'. 18:00 18:15 0.25 5,135 5,316 INTRMI DRILL TRIP T Trip in w/ BHA #13 (Rhino Reamer w/ bullnose) f/ 5135' to 5316'. 18:15 18:30 0.25 5,316 5,316 INTRM1 DRILL SRVY T Pumping up survey. Pumping 292 gpm w/ 1800 psi. 18:30 18:45 0.25 5,316 5,345 INTRM1 DRILL REAM T Reaming hole f/ 6 -1/8" to 7" w/ Smith Rhino Reamer f/ 5316' to 5345'. 18:45 00:00 5.25 5,345 6,089 INTRM1 DRILL REAM T Continue to ream f/ 5345' to 6089'. Weight on bit (Reamer) 2 to 5k, Rotate 70 rpm w/ 4 to 5k ft-lbs on bottom, 4k ft-bs off bottom. Pumping 320 gpm w/ 2320 psi on bottom, 2250 psi off bottom. Motor turning reamer 93 rpm + 70 string rotation= 163 rpm. String speed up to 300' /hr while reaming. 06/14/2010 Continuing to ream with surveys every other stand from 6089' to 8180'. Max traveling speed 300' /hr, Max pump rate 325 gpm. Motor turning 93 rpm w/ 70 rpm top drive = combined 163 rpm at the Smith Rhino Reamer. Circulate and weight up f/ 9.3 ppg to 9.8 ppg. Drop a 1.76" ball to open the Commander circ tool, pump down at 2 bpm w/ 420 psi, ball on seat after 35.7 bbls pumped. Pressure to 1500 psi, then stage up in 200 psi increments to open valve. Tool opened at 3200 psi. Circulate a bottom's up stagging pumps up to final 560 gpm w/ 3350 psi. Pump a 20 bbl hi vis sweep, follow w/ mud, pumping 560 gpm w/ 3350 psi. While circulating sweep out of the hole, the hole started taking fluid. Slowed pump rate to 450 gpm w/ 2200 psi. Lost 45 bbis to the hole and noticed the sweep at surface 100 bbls late. Open hole size is 55 bbis larger than 7" hole. After sweep was out of the hole, continued to circulate at 325 gpm w/ 1330 psi (Total lost to hole 101 bbis at this time), reduced rate to 200 gpm w/ 690 psi (gained back 61 bbls of the 101 lost- 40 bbls lost to hole at this time), shut down and monitor well on the trip tank. Well breathing back fluid at 14.4 bpm initially, at midnight flow slowed down to 12.8 bpm. A total of 12.8 bbis had breathed back at midnight (A total of 27.2 bbis now lost to the hole). Flow back was decreasing. Note: Departure from 3N -16A at 5195' at 0830 hrs 6/10/2010. 5195' to 7833'= 3N- 16A -PB2 Note: 3N- 16APB1= 7740' to 8260', with departure at 7740'. 00:00 12:00 12.00 6,089 7,550 INTRM1 DRILL REAM T Continue to ream f/ 6089' to 7550' (6021' TVD). Weight on bit (Reamer) 2 to 10k, Rotate 70 rpm w/ 4 to 10k ft -Ibs on bottom, 4to 6k ft -bs off bottom. Pumping 320 to 325 gpm w/ 2320 to 2500 psi on bottom, 2250 2350 psi off bottom. Motor turning reamer 93 rpm + 70 string rotation= 163 rpm. String speed up to 300' /hr while reaming. Note: Total hrs on reamer 16.35 hrs, 12:00 17:00 5.00 7,550 8,180 INTRM1 DRILL REAM T Continue to ream f/ 7550' to 8180' (6471' TVD). Weight on bit (Reamer) 2 to 7k, Rotate 70 rpm w/ 6 to 10k ft-Ibs on bottom, 5.5 to 7k ft-bs off bottom. Pumping 325 gpm w/ 2500 to 2780 psi on bottom, 2350 2620 psi off bottom. Motor turning reamer 93 rpm + 70 string rotation= 163 rpm. String speed up to 300' /hr while reaming. Page 38 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:30 2.50 8,180 8,180 INTRMI DRILL CIRC T Circulate and weight up f/ 9.3 ppg to 9.8 ppg. Pumping 323gpm w/ 2620 psi. Initial circ pressure 2620 psi and ps. t p p final 2700 psi. 19:30 20:30 1.00 8,180 8,180 INTRM1 DRILL CIRC T Drop 1.76" ball to open commander circulating sub. Pump ball down at 2 bpm w/ 420 psi. Ball on seat after pumping 356 strokes. Pressure up to 1500 psi, then increase presure in 200 psi increments with wait in between to shear at 3200 psi. 20:30 21:30 1.00 8,180 8,180 INTRMI DRILL CIRC T Pump a bottoms up, stagging pumps up from 320 gpm w/ 1400 psi to 560 gpm w/ 3350 psi. 413 gpm w/ 2050 psi, 510 gpm w/ 2855 psi, 550 gpm w/ 3240 psi, 560 gpm w/ 3350 psi. Pump a 20 bbl hi vis sweep into the drill pipe, follow with mudpumping mud at 560 gpm w/ 3350 psi- 34% TOTCO flow out while picking up. Circulate sweep out of the hole at 450 gpm w/ 2200 psi- 33 to 35% flow out. Hole taking fluid. Lost 45 bbis to the hole. Sweep showed up 100 bbis late. 55 bbis extra open hole size. Continue to circulate, pumping 325 gpm w/ 1330 psi- 32 to 31% Totco flow out. 21:30 22:30 1.00 8,180 8,180 INTRMI DRILL CIRC T Reduce pump rate to 200 gpm w/ 690 psi -22 to 25% Totco flow out. While circulating at 200 gpm gained back 61 bbis of the 101 bbis total lost while circulating. At this point 40 bbis lost to the hole. 22:30 00:00 1.50 8,180 8,180 INTRM1 DRILL OWFF T Shut down, monitor well on the trip tank. Initial breathing back 14.4 bph. At midnight rate had slowed down to 12.8 bph. Note: Total losses to the well at midnight 40 bbis. 06/15/2010 Continue monitoring well observing flow from 12.8 BPH to 6 BPH and slowing. Circulate at 200 GPM's 630 PSI with no losses a total of 94 BBLS. Pump 68 BBLS of casing running pill. Monitor well - slight flow. POOH slow at 17 ft/min from 8180' - 7400'.Monitor well on trip tank, Continue POOH slow increasing speed to 5300'.Drop 1.76" Ball to land and closing valve with 3500 PSI. BROOH from 5300'- 5195'. Drop ball and open valve, circulating at 625 GPM's - 3040 PSI. Observed losses with 80 BBLS pumped away, 16 BBLS lost. Monitor well - well gave back 16 BBLS> Continue POOH from 5300' - 4883', above window. Drop ball and open valve. Circulate bottoms up staging pumps to 425 GPM's - 1230 PSI. Monitor well - static, pump dry job. Drop drift in DP for liner run. POOH, breakout & lay down BHA. Service Top Drive & Draw works. Pull Wear bushing. Rig up, and make up 5 1/2" liner shoe track with Float shoe, FC and LC. RIH to 3448'. Make up dual liner hanger assemblies, break circulation, verify clean at 3 BPM - 530 PSI. Continue RIH at 45 ft/min to 4849'. 0 Fluid Losses for the day. Page 39 of 58 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T _ Comment 00:00 01:15 1.25 8,180 8,180 INTRM1 DRILL OWFF T Monitor well on the trip tank. Breathing, slowed down f/ 12.8 bph to 6 bph. 01:15 01:45 0.50 8,180 8,180 INTRM1 DRILL CIRC T Circulate, pumping 200 gpm w/ 630 psi, no losses. Circulate 94 bbls. Mud weight 9.8 ppg. 01:45 02:00 0.25 8,180 8,180 INTRMI DRILL CIRC T Pump 27 bbls of casing running pil. Pill consists of 9.8 ppg mud w/ 10 ppb "G" seal, 2 ppb Alpine beads, 8% lube 776. 02:00 03:15 1.25 8,180 8,180 INTRMI DRILL OWFF T Monitor well- slight flow, while mixing up more casing running pill. 03:15 03:45 0.50 8,180 8,180 INTRMI DRILL CIRC T Pump 41 bbls more casing running pill, chase with 80 bbls of 9.8 ppg mud. Pumping 200 gpm w/ 650 psi. Same recipe used for pill. 03:45 04:00 0.25 8,180 8,180 INTRM1 DRILL OWFF T Monitor well- slight flow. 04:00 04:45 0.75 8,180 7,400 INTRMI DRILL TRIP T Pull out of the hole slow (17' /min) from 8180' to 7400'. Monitor well on the trip tank. 04:45 05:45 1.00 7,400 5,300 INTRM1 DRILL TRIP T Pull out of the hole faster from 7400' to 5300'. Monitor well on the trip tank. 05:45 07:00 1.25 5,300 5,195 INTRM1 DRILL CIRC T Drop a 1.76" ball to open commander circ tool. Pump down at 63 gpm w/ 240 psi. Observed closure at 2500 PSI. Back ream from 5300' - 5195' with 60 RPM's - 325 GPM's - 2600 PSI. UP WT - 165K, ROT WT - 95K. 07:00 08:00 1.00 5,195 5,300 INTRMI DRILL CIRC T Run back in hole to 5300' MD. Drop ball to open valve at 3500 PSI. Circulate @ 625 GPM's 3040 PSI while reciprocaste drill string. Observed 16 BBL loss in 80 BBLS pumped away. Monitor well - gave back 16 BBLS. 08:00 08:30 0.50 5,300 4,883 INTRM1 DRILL TRIP T POOH from 5300' to 4883', above window top. Observed proper hole fill. 08:30 09:30 1.00 4,883 4,883 INTRMI DRILL CIRC T Drop 1.698" ball to seat in commander valve and shut down flow to BHA. Allow ball to seat increasing pumps to 250 GPM's - 750 PSI, and then to 425 GPM's - 1230 PSI. 09:30 10:30 1.00 4,883 4,883 INTRM1 DRILL OWFF T Monitor well - static. Pump 15 BBLS dry job, and drop drill pipe rabbit for upcoming liner run. Drifted 46 stands. . 10:30 11:00 0.50 4,883 2,641 INTRMI DRILL TRIP T Trip out of hole form 4883' - 2641' MD.Observed proper hole fill. 11:00 12:00 1.00 2,641 2,641 INTRMI DRILL SVRG T Servie rig, Top Drive & darw works. Crew Change. 12:00 12:30 0.50 2,641 625 INTRMI DRILL TRIP T Continue POOH from 2641' - 625'. Observed proper hole fill. 12:30 14:30 2.00 625 0 INTRMI DRILL PULD T Breakout & lay down Rhino Reamer BHA. 14:30 15:00 0.50 0 0 INTRM1 DRILL PULD T Send tools out. Clean & clear rig floor area. Page 40 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 0 0 INTRMI CASING RURD T BOLDS. Pull Wear bushing. Rig up Doyon casing tongs & equipment to run 5 1/2" liner. 16:30 16:45 0.25 0 0 INTRMI CASING SFTY T Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to pick up, make up 5 1/2" STL liner assembly. 16:45 22:30 5.75 0 3,448 INTRMI CASING RUNL T Make up 4 1/2" Float shoe joint & FC. Crossover to 5 1/2" BTC installing 7 joints. Crossover to 5 1/2" STL, running 71 jnts. Make up Baker HMC liner hangers and packer assembly with running tool. Liner wt alone = UP WT - 75K, SO WT -70K. Break circulation verifying all free. Pump at 3 BPM - 530 PSI. 22:30 00:00 1.50 3,448 4,849 INTRMI CASING RUNL T Continue RIH with 5 1/2" liner on DP from 3448' - 4849' DPM, at running speed of 45 ft/minute. Observed proper hole fill. 06/16/2010 Continue RIH with 5 1/2" Liner assembly. Circulate every 10 stands in the hole. Run to 7528' MD. Liner became stuck, and packed off, Work to obtain circulation of up 4 1/2 BPM - 850 PSI, with no movement in pipe when attempting to pull free. Pulled up to 220K on weight indicator. Liner weight = 33K. Decision to release from liner. CBU and POOH with running tool ass mbly. TOL @ 4070'. Load fishing tools. Rig up Sperry Sun unit. Make up and run inclinometer and Gyro. Obtain surveys with indications of liner in old hole. Make up and RIH with Gyro Data gyro to obtain surveys for confirmation. Observed hole static. 00:00 00:30 0.50 4,849 4,849 INTRM1 CASING CIRC T Circulate bottoms up at the window. Pumps at 3 BPM - 580 PSI. UP WT = 92K, SO WT = 82K. 00:30 08:00 7.50 4,849 7,528 INTRMI CASING RUNL T Continue run 5 1/2" liner through window area with no issues. Run liner filling each stand and circulating every 10 stands. Work through Kick off point at 5242' MD setting down 30K, breaking circulation with 2 BPM and then free movement to continue in hole. Continue RIH with liner to take weight again at 7528'. UP WT - 120K, SO WT = 90K. Observed no movement in string. Attermpt to work pipe free, and observed packed off. Continue work string to gain fluid movement, and stage up to 4 1/2 BPM - 850 PSI. Work string continuously staging pull weights to 220K with no success in movement in pipe. Full circulation obtained. 08:00 08:30 0.50 7,528 7,528 INTRM1 CASING RUNL T Decision to release from liner. Rotate drill pipe 10 RH turns to release and pull to 4016'. UP WT - 90K, SO WT - 80K. Top of liner at 4070'. 08:30 09:00 0.50 4,016 4,016 INTRM1 CASING CIRC T Circulate bottoms up at 7 BPM - 650 PSI. Monitor well static. Blow down Top drive. 09:00 11:00 2.00 4,016 0 INTRMI CASING TRIP T POOH with running tool from 4016' to surface. Inspect and breakout running tool assembly. Page 41 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 0 0 INTRM1 CASING PULD T Clean & clear rig floor area. Send tools out. 11:30 15:30 4.00 0 0 INTRM1 DRILL PULD T Load fishing tools in pipe shed. Load and strap HWDP.Make up Jar and Bumper sub assembly.Perform light maintenance on equipment while standby for Sperry Sun unit. Install wear bushing and RIDS. 15:30 15:45 0.25 0 0 INTRMI DRILL ELOG T Held PJSM with crew & Halliburton reps. Discuss safety & hazard recognition issues. Discuss procedure rto RU and run Gyro run. 15:45 18:00 2.25 0 0 INTRMI DRILL ELOG T Spot and rig up Sperry Sun logging unit. RU and hang sheaves. Make up inclinometer and Gyro tool assembly. Test tool assembly. 18:00 21:30 3.50 0 0 INTRM1 DRILL ELOG T WLIH with inclinometer and Gyro assembly to obtain surveys from 4900' - 7462'. POOH from 7642' to surface. Initial indications indicate 5 1/2" liner assembly tracked into old hole. 21:30 22:30 1.00 0 0 INTRMI DRILL ELOG T lay down Sperry Sun inclinometer and Gyro assembly. Make up Gyro Data Gyro tools and test same. 22:30 00:00 1.50 0 0 INTRM1 DRILL ELOG T WLIH with Gyro Data tool string from surface to 4400'. 06/17/2010 / Continue WLIH with Gyro Data gyro assembly form 4400' - 6257'. Obtained surveys verf�ing 5 1/2" liner �( assembly_tracked into old hole where it is stuck., Make up Spear assembly. TIH to tag & engage top of liner 4011' DPM. Verify catch and stage up to pulling and firing jars at 100K over, with straight pull to 300K. Circulation rate of 4 BPM - 800 PSI. Observed 55 BBLs loss while jarring. No success in freeing liner string. Perform Post jarring inspections. release spear, POOH. RU HES E -line crew. make up and run Baker K -1 5 1/2" cement retainer to WLIH and set at 5360' WLM. Make up and run radial cutting torch on e-line. WLIH to tag CIBP on depth. While working wireline for correlation log, second attempt, wireline string became stuck at 5170' WLM. After repeated attempts to free string with no sucess, pull out of rope socket, and WLOH. Total losses for the day = 38 BBLS. 00:00 02:00 2.00 0 0 INTRMI DRILL ELOG T Continue WLIH with Gyrio Data gyro assembly from 4400' - 6257' WLM. Obtaine surveys verifying 5 1/2" liner tracked into old hole. 02:00 03:00 1.00 0 0 INTRM1 DRILL ELOG T Lay down gyro tool string. RD Halliburton unit and sheaves.. 03:00 03:30 0.50 INTRM1 DRILL OTHR T BOLDS. Pull Wear Bushing. 03:30 04:00 0.50 0 0 INTRM1 DRILL FISH T Make up BOT 5 1/2" Spear assembly with HWDP aned jars. Install PO sub. 04:00 05:00 1.00 0 4,029 INTRMI DRILL TRIP T Trip in hole with 5 1/2" spear assembly. 05:00 07:00 2.00 4,029 4,029 INTRM1 DRILL FISH T Tag up and engage Fish @ 4011' DPM. NO -GO @ 4029'. UP WT = 95K, SO WT = 80K. Break Circulation with 4 BPM - 800 PSI. Verify catch, and stage pulls to jar 100K over weight firing jars, and then straight pull to 300K. No success in freeing the liner string. Page 42 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:30 0.50 4,029 4,029 INTRM1 RIGMNT SVRG T Inspect Top Drive & Derrick for post jarring inspection. 07:30 09:30 2.00 4,029 4,029 INTRM1 DRILL FISH T Resume jarring with parameters as above. Observed fluid loss of 55 BBLS while jarring and pumping.No success in freeing stuck liner. Release grapple and verify drill string free. Stand back one stand, and perform post jarring inspection on Top Drive & derrick. 09:30 11:30 2.00 4,029 4,029 INTRMI DRILL OWFF T Monitor well - observed minor flow with gain of 12 BBLS with flow slowing. CBU at 3 BPM - 240 PSI. Monitor well gain back 2 BBLS. Well static. 11:30 12:30 1.00 4,029 0 INTRMI DRILL TRIP T POOH from 4011'- 477'. Observed proper hole fill. Monitor well - static. Rack back HWDP. 12:30 13:00 0.50 0 0 INTRM1 DRILL PULD T Breakout & lay down spear BHA. Clean & clear rig floor. 13:00 13:15 0.25 0 0 INTRM1 DRILL ELNE T Held PJSM with crew and Halliburton E -line reps. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run CIBP and cutter. 13:15 16:00 2.75 0 0 INTRMI DRILL ELNE T Rig up E -line sheaves and truck. Make up CIBP. Monitor well - static. 16:00 19:00 3.00 0 0 INTRMI DRILL ELNE T WLIH with Baker K -1 WL Set 5 1/2" Cement retainerLocate & set same at 5360' WLM. All indications good set. WLOH inspect firing head - all good. 19:00 21:00 2.00 0 0 INTRMI DRILL ELNE T Lay down CIBP assembly, and make up Radial Cutting Torch assembly. 21:00 00:00 3.00 0 0 INTRM1 DRILL ELNE T WLIH with RCT to pass through TOL with no issues. Continue WLIH @ 120 Ft/Min to lightly tag the CIBP and pull back for CCL correlation to 4700'. WLIH to tag again, and WLOH for CCL correlation. AT 2215 HRS, while pulling up, wireline tools became stuck at 5170' WLM. Repeat attempts to free tools string, no success.Stage pulling to 1700, 1800, 2000, and finally 2200 lbs, to pull free from rope socket. WLOH. Total losses for the day = 38 BBLS 06/18/2010 Continue WLOH with line pulled from rope socket. RD HES E -line crew. RU HES Slickline crew to fish tools. Fishing operation successful. POOH, inspect assembly - no trouble with tool string. Spot & rig up E -line unit. make up Jet cutter assembly. WLIH to locate & firew cutter @ 5338' WLM.. WLOH. RD. Make up TIH with spear assembly. Engage & pull to fire jars attempting to free liner. No success, indicating cut failed. POOH. Install WB. RILDS. Spot E - line unit. 00:00 00:30 0.50 0 0 INTRMI DRILL ELNE T Continue WLOH with frayed wire pulled from rope socket. RD Sheaves and unit. 00:30 01:00 0.50 0 0 INTRM1 DRILL SVRG T Service rig, Top Drive and draw works. Page 43 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:15 0.25 0 0 INTRM1 DRILL SFTY T Held PJSM with crew and HES Slickline crew. Discuss safety & hazard recognition issues. Discuss rig up and run slickline tools. 01:15 06:30 5.25 0 0 INTRMI DRILL SLKL T Spot Slickline unit and RU line and sheaves. Make up toolstring to fish E line tools.Make up Fishing toolstring. WLIH to engage & fire jars. Sheared pin. WLOH. Repeat of run number 1. Make up "S" tool assembly. WLIH engage fish. Jar fish free. WLOH lay down all tool strings including RCT tools. 06:30 11:30 5.00 0 0 INTRMI DRILL ELNE T RD Slickline unit, RU E -line unit. Rebuild rope socket. Wait on sheaves & jet cutter form Deadhorse. 11:30 17:30 6.00 0 0 INTRM1 DRILL ELNE T RU e-line tools. Make up Jet cutter assembly. WLIH to locate & set down on CIBP. Pull up to fire cutter at 5338' WLM. WLOH, lay down tools & RD E -line crew. 17:30 18:30 1.00 0 53 INTRM1 DRILL PULD T BOLDS. Pull Wear Bushing. make up Spear BHA #2. Total lenght = 53'. 18:30 19:30 1.00 53 3,871 INTRMI DRILL TRIP T Trip in hole from 53' - 3871'. Fill drill string every 2000" 19:30 20:30 1.00 3,871 4,011 INTRMI DRILL FISH T Obtain parameters. UP WT = 95K, SO WT = 80K. Slack off and engage liner. Liner top at 4011'. Pull to verify catch. Pull and fire jars staging up weights to 100K over to fire jars. Indications that the liner is not cut. No success in freeing liner. Staright pulls to 300K. Pump rates at 3 BPM - 650 PSI. Observed 9 BBL fluid losses while pumping. No return flow, indicating fluid being pumped away. Fluid came back when pumps off. Release spear. Pull up verify free. 20:30 22:00 1.50 4,011 4,011 INTRM1 DRILL OWFF T Monitor well - Static. Pump 18 BBL Dry job. Perform Post jarring inspection on Top Drive & derrick. 22:00 23:00 1.00 4,011 0 INTRMI DRILL TRIP T POOH to surface. Breakout & lay down Spear assembly. 23:00 00:00 1.00 0 0 INTRM1 DRILL ELNE T Drain Stack, Pull Wear bushing. RU E -line crew. Total fluid losses for the day =0. 06/19/2010 Continue make up Wireline RCT. WLIH with cutter to locate & fire at 5328'. Collar @ 5333" WLM. WLOH. RD E -Line. MU Spear, TIH tro engage at 4011' DPM. Jar liner free. CBU , monitor well. POOH, Lay down 5 1/2" Liner. Strap same. Make up 6 1/8" Clean out assembly. TIH filling drill string every 2000 ". Orient through window area, and no issues. Continue in hole to orient at 120 deg left to trough kick off point. Assembly in new hole first attempt. Backream through kick off point. Repeat 3 times. Work string through KO Point with no pump and no issues. Continue TIH on elevators to 7680' DPm. Took weight. MU TD and work tight spot. Losses for the day 45 BBLS. Page 44 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 0 0 INTRM1 DRILL ELNE T Continue Make up wireline RCT assembly. WLIH to locate & cut at 5328' WLM. Observed collar @ 5333 ". WLOH, inspect RCT tool, good indications of full burn giving a good cut. RD E -line crew. 02:30 03:00 0.50 0 0 INTRM1 DRILL PULD T Pull wear bushing. Clean & clear rig floor. 03:00 03:30 0.50 0 480 INTRMI DRILL PULD T Make up Spear assembly. 03:30 05:00 1.50 480 4,011 INTRMI DRILL TRIP T Trip in hole with Spear BHA #3. 05:00 06:00 1.00 4,011 4,011 INTRM1 DRILL FISH T Obtain parameters. UP WT = 95K, SO WT = 80K. Tag & engage liner top @ 4011' DPM. Pull to verify catch. Pull to fire jars staging up to 100K over, and straight pulls stagingh to 300K. Pumps to 3 BPM - injecting fluid with little returns. Observed fish came free with new up weight of 123K. Pull and rack back one stand. Monitor well. 06:00 07:00 1.00 5,300 5,300 INTRM1 DRILL CIRC T Drop ball to open Pump out sub. CBU @ 8 BPM - 800 PSI. Flow = 31 %. Monitor well until dead. 07:00 07:30 0.50 5,300 4,800 INTRM1 DRILL TRIP T POOH to 4800' with liner. Monitor well - static. Blow down TD. 07:30 09:00 1.50 4,800 1,317 INTRMI DRILL TRIP T Continue POOH from 4800' - 1317. Fishing tool assembly & Liner hangers. Observed proper hole fill. 09:00 10:30 1.50 1,317 1,250 INTRM1 DRILL PULD T Breakout & lay down fishing assembly, spear. RU liner running equipment, tongs. Breakout & lay down liner hangers and packer. Observed packer rubbers and rings damaged. Liner hangers missing 3 slip segments. 10:30 12:30 2.00 1,250 0 INTRM1 CASING PULD T Continue POOH breakout & lay down 5 1/2" STI liner. Strap all liner layed down. Observed proper hole fill. 12:30 13:00 0.50 0 0 INTRMI DRILL PULD T Drain BOP stack. RD casing running equipment. Install wear bushing. RILDS. 13:00 13:30 0.50 0 0 INTRM1 DRILL PULD T Pick up cement head, break down same. 13:30 15:30 2.00 0 0 INTRM1 DRILL PULD T Make up 6 1/8" clean out assembly with 1.15 deg mud motor.Observed firwt motor damaged. lay down same. Motor "bent" on top by box end..Make up back up motor with 1.15 deg bend. . 15:30 18:00 2.50 0 0 INTRM1 DRILL PULD T Contiune make up BHA. When making up commander valve on flex collar, connection was overtorqued. Valve and flex collar layed down. Assembly run without valve. 18:00 20:00 2.00 0 4,900 INTRM1 DRILL TRIP T Trip in hole to 4900', filling drill string every 2000'. Observed proper hole fill. Page 45 of 58 • i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:00 2.00 4,900 5,200 INTRMI DRILL REAM T Orient motor to 30 deg Right of high side to pass through window area wioth no issues. Continue in hole to kick off point, observing assembly in new hole first attempt with 9K set down weight. orient to 120 Deg left of high side. Owrk string through KO point with no isses. Back ream through 2 times, and work assembly with no pumps. Pumps at 280 GPM's -1660 PSI, 100 RPM's with 8K TQ. 22:00 00:00 2.00 5,200 7,680 INTRM1 DRILL TRIP T Continue trip in hole to tag up taking 20K set down weight at 7680' DPM. 40K overpull. Make up Top drive, observed packed off. Work drill string to gain circulation. Total losses for the day = 45 BBLS. 06/20/2010 3 d Continue work tight spot @ 7650' gaining circulation at 3 BPM. POOH, working string through tight spots 51 back to 7400'. Work string reaming down to 7850' DPM. At the connection Drillstring stuck, firing jars up to 250K, with no rotation & little or circulation. Gained full circulation to 330 GPM - 2500 PSI. No free movement in drill string. Fluid losses minimal. Continue work strinig to gain free movement pulling up hole working through tight spot at 7767'. Work free, Pull drill string BROOH to window. Continue POOH lay down BHA. Observed connections tight, and boxes swelled on MWD connections. Veld PJSM. RU and run 979' of 2 7/8 tbQ for cement stin•er. 00:00 09:00 9.00 7,680 7,850 INTRMI DRILL REAM T Continue work through tight spot at 7680' DPM. Observed assembly packed off and hanging up pulling to 250K to fire jars and free string. Work to gain circualtion up to 3 BPM, and pulling assembly back to 7400'. Continue circualting while reciprocate & rotating to bring pumps to 330 GPMs - 2500 PSI. Observed hole unloading Tots of sand returns. Circulate to clean hole. Make connections fighting back in hole each stand to 7850'. Circulate, reciprocate & rotate.. Observed packoff and hung up again at 7750' after mnaking connection. Work string firing jars, and pulling to 250K. Work string free and circulate and rotate to rack stand. 09:00 12:00 3.00 7,850 7,767 INTRMI DRILL CIRC T Pump 20 bbl hi vis sweep at 320 gpm and stand back one stand. CBU. Working pipe while circulating hit tight spot at 7767'. Work through tight spot. Attempt to rotate down through tight spot. Orient motor and try to slide through tight spot without success. Lost 0 bbl mud 12:00 12:30 0.50 7,767 7,660 INTRMI DRILL OWFF T Monitor well - static. 12:30 17:00 4.50 7,660 5,004 INTRMI DRILL REAM T BROOH from 7660' - 5004'. Pumps at 280 GPM's - 1760 PSI. 100 RPM's with 5K TQ. Page 46 of 58 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 5,004 4,932 INTRMI DRILL CIRC T Orient motor @ 30 Deg Right, and pull tghrough window area with no issues. Circulate bottoms up x 2. No Fluid losses. 18:00 18:30 0.50 4,932 4,932 INTRMI DRILL OWFF T Monitor well - static. Pump 18 BBL dry job. Blow down Top Drive. 18:30 20:00 1.50 4,932 500 INTRMI DRILL TRIP T POOH from 4932' - 520'. Observed proper hole fill. 20:00 21:30 1.50 500 0 INTRM1 DRILL PULD T Breakout & lay down BHA. Observed connection tight. Check MWD to motor scribe and found it 18.76 DEG, original scribe = 94.32 DEG.DM had a belled box connection. 21:30 22:00 0.50 0 0 INTRM1 DRILL PULD T Clean & clear rig floor area. Send tools out. 22:00 22:15 0.25 0 0 INTRM1 DRILL SFTY T Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run 2 7/8" TBG. 22:15 00:00 1.75 0 980 INTRM1 DRILL PULD T RU powwer tongs. Pick up 979.87' of 2 7/8" tbg & crossovers for cement stinger. 06/21/2010 Continue run 2 7/8" tbg for cement stinger. Run in hole to pass theough window - no issues. Continue to KO point having to wash & rotate through, and then RIH to tag up at 7880' DPM. String became sticky and temporarily stuck. Obtain full circulation. and pull back to 7600' for laying cement plugs. Circulate & condition mud. RU SWS trucks. Mix & pump 36 BBLS 15.8 cement plug spotting at 7600'.CIP @ 10:43 HRS Pull back to 7108' Circulate with no cement returns. Mix & spot 36 BBLS 15.8 PPG cement. CIP (a), 13:42 HRS Pull back to 6400'. Circulate - no cement returns. POOH lay down 2 7/8" tbg. Make up Baker KA_ echanical cement retainer, and TIH to locate & set same @ 4900' DPM. Established injection rates at 1 BPM - 450 PSI, 2 BPM - 540 PSI, 3 BPM - 650 PSI, 4 BPM - 780 PSI, and 5 BPM - 970 PSI. RU cement lines and valves to DP. Obtain lab reports on cement. 00:00 01:00 1.00 980 979 INTRM1 DRILL PULD T Continue pick up remaining 2 7/8" TBG and crossovers for cement stinger. Total BHA = 979.87'.Rig down all handling equipment and power tongs. 01:00 05:00 4.00 979 7,880 INTRMI DRILL TRIP T Trip in hole with 4" drill pipe to pass through window area at 4932' with noissues. Continue to kick off point and work string shoe through with 3 BPM - 450 PSI, and 5 RPM's 5K TQ. Continue TIH at 35 -40 ft/min, tagging up at 7880' DPM. String became temporarily stuck and packed off. We obtained full circulation and freed up the string pulling back to 7600' DPM for circulating and laying plugs. 05:00 08:00 3.00 7,880 7,600 INTRM1 DRILL CIRC T Circulate & reciprocate drill string with stinger at 150K UP WT. 100K SO WT. Stage pumps up to 8 BPM - 1400 PSI. Rig up schlumberger cementers, and spot trucks for job. 08:00 10:00 2.00 7,600 7,600 INTRM1 CEMEN CIRC T Continue circulating while holding safety meeting and batch mixing cement Page 47 of 58 1 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 7,600 7,600 INTRM1 CEMEN" CMNT T Pressure test lines to 3000 psi. Pump 10.5 bbl MudPush at 11.09 ppg followed by 35.9 bbl slurry @ 15.8 ppg followed by 2.8 bbl MudPush and displaced with 65 bbl mud with rig pump. CIP @ 10:43 hrs 06 -21 -2010 11:00 11:30 0.50 7,600 7,108 INTRMI CEMEN" TRIP T Pull out of the hole to 7108' 11:30 12:30 1.00 7,108 7,108 INTRM1 CEMEN "CIRC T Rig up cement equipment and CBU at 6 bpm @ 1073 psi. 0 bbl mud lost 12:30 13:30 1.00 7,108 7,108 INTRM1 CEMEN" CMNT T Pressure test lines to 3000 psi. Pump 10.5 bbl MudPush at 11.09 ppg followed by 35.9 bbl slurry @ 15.8 ppg followed by 2.8 bbl MudPush and displaced with 58 bbl mud with rig pump. CIP @ 13:42 hrs 06 -21 -2010 13:30 14:30 1.00 7,108 6,395 INTRM1 CEMEN" TRIP T RD Cement line & valves. Pull out of the hole to 6395' 14:30 15:30 1.00 6,395 6,395 INTRM1 CEMEN "CIRC T Circulate bottoms up @ 5.5 BPM - 740 PSI. No cement to surface. Monitor well - static. 15:30 16:30 1.00 6,395 4,902 INTRMI CEMEN" TRIP T POOH from 6395' - 4902'. Through window with no issues. 16:30 17:00 0.50 4,902 4,902 INTRM1 CEMEN" CIRC T Circulate bottoms up cleaning up window area. at 7 BPM - 910 PSI. Pump 18 BBL Dry Job. 17:00 18:00 1.00 4,902 979 INTRMI CEMEN "TRIP T POOH from 4902' - 979'. 18:00 18:30 0.50 979 979 INTRM1 CEMEN" RURD T Change out elevators and rig up power tongs. Monitor well. 18:30 20:00 1.50 979 0 INTRMI CEMEN" PULD T POOH, breakout & lay down 2 7/8" tbg and shoe joint. .RD Power tongs and equipment. 20:00 22:00 2.00 0 4,900 INTRM1 CEMEN 'TRIP T Make up BOT K -1 Mechanical cement reatainer with snap latch setting tool, and crossover. Total length = 6.08'.on DP. TIH to locate at 4900'. 22:00 23:00 1.00 4,900 4,900 INTRMI CEMEN" SQEZ T MU to top drive. UP WT = 102K, SO WT = 85K. Break circulation @ 4 BPM - 500 PSI. Locdate & rotate 12 RH turns to set retainer. Pull to 130K, Slack off to 60K. Repeat same. Establish injection rates as follows: 1 BPM - 450 PSI, 2 BPM - 540 PSI, 3 BPM - 650 PSI, 4 BPM - 780 PSI, and 5 BPM - 970 PSI. Total of 20 BBLS pumped away. Pull out of cement retainer, and pull up 10'. Close annular, establish Up / Down weights with annular closed. Open annular. 23:00 00:00 1.00 4,900 4,900 INTRM1 CEMEN" SQEZ T Breakout & blow down Top Drive. RU cement lines, and head to DP. Obtain lab reports for thickening times from SWS. Crew Change. Page 48 of 58 • • Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 06/22/2010 24 hr Summary Continue Rig up lines, and valves. Circulate @ 3 BPM - 350 PSI, while wait on lab reports for cement mix.PJSM Pump cement. Slip & cut DL & POH. Test BOPE 250 -3500 psi. Make up & run whipstock. Set same 65 deg. right @ 4899' MD. Mill window. TOW = 4882' BOW = 4895' 00:00 00:30 0.50 4,900 4,900 INTRM1 CEMEN" RURD T Continue rig up lines and valves. 00:30 03:30 3.00 4,900 4,900 INTRMI CEMEN" CIRC T Circulate above retainer at 3 BPM - 350 PSI. Obtain final lab reports for cement mix. Thickening time 4 HRS 15 Min. 03:30 03:45 0.25 4,900 4,900 INTRMI CEMEN" SFTY T Held PJSM with crew, BOT rep, and SWS reps. Discuss safety & hazard recognition issues. Discuss procedure to pump 51 BBL cement job, and mitigate cement return hazards. 03:45 07:00 3.25 4,900 4,900 INTRM1 CEMEN" CMNT T Turn over to SWS. Pump 2 BBLS H2O. Pressre test lines to 4000 PSI. Close annular. Mix & pump 51 BBLS of 15.8 cement down drill pipe. Hold 400 PSi back pressure on choke. Sting into cement retainer. Bleed annulaus off. No flow. Wash up. With rig, pump 9.8 ppg mud down DP at rates up to 4 BPM - max pressure at 1000 PSI. After 35 BBLS pumped , slow rate to 2.5 BPM - 600 PSI. With 51 BBLS pumped asway, observed pressure held at 340 PSI. CIP @ 04:40 HRS. Unsting from retainer. reverse circulate 2 DP volumes observing 1 - 1/12 BBLS cement returns. Continue pump sponge balls consecutively to wipe cement residue from ID of DP. Monitor well - static. 07:00 08:30 1.50 0 INTRM1 RIGMNT SLPC T Slip & cut drilling line. Inspect Top Drive. 08:30 10:00 1.50 4,900 0 INTRMI CEMEN "TRIP T POOH with cement stinger and lay down same. 10:00 16:00 6.00 0 0 INTRMI WHDBO BOPE T BOLDS. Pull Wear bushing. Flush BOP stack. RU to test BOP's. Test BOP's. test with 3 1/2" & 4" test joints. Test rams, choke & kill manuals, and HCR's. test choke nmanuifold and all valves. test all Floor valves. 6 Nitrogen bottles with and avg PSI of 2150. Perform Koomey test with the first 200 PSI increase in 21 secs, and full 3000 PSI in 1.42 minutes. Witness of test waived by AOGCC rep Chuck Scheve. Install wear bushing. 16:00 17:00 1.00 0 0 INTRM1 WHDBO BOPE T Blow down choke & kill line. Drain BOPE stack. 17:00 17:30 0.50 0 0 INTRM1 RIGMNT SVRG T Service & inspect top drive. Page 49 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:30 3.00 0 650 INTRMI STK PULD T Mobilize BHA. PJSM Make up BHA (Whipstock assembly) Orient whipstock to MWD. Continue make up BHA 20:30 21:00 0.50 650 650 INTRMI STK DHEQ T Shallow pulse test MWD © 325 gpm 21:00 23:00 2.00 650 4,837 INTRMI STK TRIP T RIH from 650' to 4837' MD. 23:00 00:00 1.00 4,837 4,837 INTRMI STK WPST T M/U top drive & obtain parameters. PU 105k SO 85k Orient tool face & circ. down to set whipstock. Tool face © 65 deg. right. Pick up to ensure anchor set. Slack off 35k to shear off whipstock. Whip storkset @ 4R99' Mn 06/23/2010 Trip Make up BHA RIH Displace mud in well DrIg. Ahead 00:00 07:00 7.00 4,882 4,911 INTRMI STK WPST T Mill window in 7" Casing. TOW = 4882', BOW = 4895'. Continnue mill \,✓ OH to 4911'. UP WT = 105K, SO WT //1' = 85K. ROT WT = 95K. Work window to verify clean with & without S r pumps. Recovered a taotal of 110# of iron cuttings. 07:00 08:00 1.00 4,911 4,911 INTRM1 STK CIRC T Circulate bottoms up. Monitor well - t tv static. r 08:00 11:00 3.00 4,911 0 INTRM1 STK TRIP T POOH to surface. Observed proper V hole fill. Breakout & lay down BHA. Inspect & gauge mills to full gauge @ 6.151 ". 11:00 11:30 0.50 0 0 INTRMI DRILL PULD T Make up stack washing tool ansd flush iron from BOP stack. 11:30 11:45 0.25 0 0 INTRMI DRILL SFTY T Held PJSM with crew & Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss procedure to make up and run 6 1/8" drilling assembly. 11:45 13:15 1.50 0 627 INTRMI DRILL PULD T Make up 6 1/8" drilling assembly with new Hycalog bit jetted with 5 x 12's for a .552 TFA. Drilling assembly includes MI commander valve. Total BHA length = 627.42 13:15 14:30 1.25 627 627 INTRM1 DRILL PULD T Down load MWD 14:30 15:30 1.00 627 627 INTRMI DRILL PULD T Continue make up BHA Find bad saver sub. 15:30 16:30 1.00 627 627 INTRM1 DRILL OTHR T PJSM- Change out saver sub. 16:30 17:00 0.50 627 627 INTRMI DRILL DHEQ T Shallow pulse test @ 265 gpm w/ 1210 psi. 17:00 20:00 3.00 627 4,831 INTRMI DRILL TRIP T RIH from 627' to 4831' MD Fill pipe every 2000'. 20:00 20:30 0.50 4,831 4,900 INTRM1 DRILL TRIP T M/u to topdrive -P /U wt. 105k S/O 76k Orient bit to 65 deg. right @ 255 gpm 1720 psi 4k bobble @ window RIH to 4900' MD. 20:30 21:00 0.50 4,900 4,900 INTRM1 DRILL CIRC T Displace well to new mud @ 6 bpm total of 190 bbls. 21:00 21:30 0.50 4,900 4,900 INTRMI DRILL LOT T Perform leak off test 12.0 EMW Page 50 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 4,900 4,955 INTRMI DRILL DDRL T Drlg. From 4911' to 4955' MD 3725' TVD. PP 2120 WOB 3k 345 gpm SPR #1 30 spm @ 460 psi 40 spm @ 650 psi. #2 30 @ 420 psi. 40 @ 620 psi. TQ 3K 06/24/2010 Continue directional drill 6 1/8" hole from 4955' - to 6455. 00:00 12:00 12.00 4,955 5,810 INTRMI DRILL DDRL T Continue directional drill 6 1/8" hole from 4955'- MD 3725 (TVD) WOB 2 -10K 350 GPM 2550 PSI UP WT. 120k DW 102k ROT WT 112k TQ off btm 4k on btm 4k. BHA out window @ 5386 MD 4010 TVD. Start back reaming every stand from 5479 MD 4085' TVD. Pumped 2 sweeps. Total bit hrs. 7.68 AST 3.68 Jar hrs. 7.68 ECD 11.69 SPR @ 5421 MD 4037 TVD #1 MP 30 SPM 560 PSI 40 SPM 890 PSI #2 MP 30 spm 580 psi 40 SPM 790 psi. No gas observed No Losses 12:00 00:00 12.00 5,810 6,455 INTRMI DRILL DDRL T Continue directional drlg & sliding from 5810 MD 4385 TVD to 6455 MD 5023 TVD. WOB 5-10k RPM 80 350 gpm PP on bottom 3040 psi off btm 2650 psi Rot wt 120k SOW 108k UP WT 135k TQ off btm 5k on btm 5.5k ECD 12.0 RPM 75 SPR @ 5948 MD 4472 TVD #1 MP 30 spm 600 psi 40 spm 810 psi #2 MP 30 spm 660 psi 40 spm 990 psiBit hrs. 10.90 AST .56 06/25/2010 Continue directional drlg. from 6455' MD 5023' (TVD) to 00:00 05:00 5.00 6,455 6,694 INTRM1 DRILL DDRL T Continue Directional drlg. from 6455' MD 5023 (TVD) to 6694' MD 5261' TVD. TQ 5.5k on btm 5k off btm 350 gpm 3110 psi on btm 2950 psi off btm wt on bit 5 -10k 80 rpm 138k up wt 112k do wt 125k rot wt pump 2 20 bbl hi -vis sweeps. 05:00 06:00 1.00 6,694 6,694 INTRMI DRILL CIRC T CBU @ 350 gpm 2690 psi monitor well pump 20 bbl dry job. 06:00 07:00 1.00 6,694 5,008 INTRMI DRILL WPRT T POOH on elevators f/ 6694' MD 5008 MD. Actual hole fill 10 bbls. verses calculated @ 10.8 bbls. 07:00 08:30 1.50 5,008 5,008 INTRM1 DRILL CIRC T Circ. 2x bottoms up @ 350 gpm w/ 2650 psi & 50 rpm,s. Monitor well. 08:30 09:00 0.50 5,008 6,602 INTRMI DRILL WPRT T RIH fromm 5203 to 6602' MD. 09:00 09:30 0.50 6,602 6,694 INTRM1 DRILL WASH T Wash down from 6602' to 6694' MD. No fill on bottom. Page 51 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 6,694 6,800 INTRM1 DRILL DDRL T Drig. 6 1/8" directional hole F/6694' MD 5261' (TVD) to 6800 MD 5365 (TVD) ECD,s 11.69 SPR @ 6455 MD (5023' TVD) MP #1 30 spm 980 40 spm 1050 psi. MP #230 spm 770 psi 40 spm 975 psi. Total bit hrs. 19.66 Jar hrs. 19.66 ART .9 AST .35 TST 5.39 hrs. TRT 14.27 ECD,s 11.44 ADT 1.25 12:00 18:00 6.00 6,800 7,022 INTRM1 DRILL DDRL T Continue drlg. from 6800' MD (5365' TVD) to 7022 MD (5579' TVD) pump 20 bbl nut plug sweep every 3rd stand drilled. Total bit hrs. 23.36 Jar hrs. 23.36 Total drilled hrs. 23.36 TST 7.36 TRT 16.0 18:00 00:00 6.00 7,022 7,087 INTRM1 DRILL DDRL T Continue drlg. f/ 7022' MD (5579 TVD) to 7087' MD (5638' TVD) Spot screen clean & Desco pill at bit during connection @ 7066' to soak bit to help with possible bit balling. PP on bottom 3100 psi off bottom 2960 psi 350 gpm TQ 5k rpm 80 WOB 5-15k PUW 142k SOW 112k ROT wt 125k ECD,s 11.65 SPR #1 pump @ 6693 30 spm 750 psi 40 spm 1010 psi #2 pump 30 spm 750 psi 40 spm 950 psi. SPR @ 7066' MD #1 30 spm 820 psi 40 spm 1130 psi #2 30 spm 790 psi 40 spm 1040 psi. 06/26/2010 DrIg. directional 6 1/8" hole to 8135' MD. 00:00 06:00 6.00 7,087 7,255 INTRM1 DRILL DDRL T Directional drlg. from 7087 MD (5638'TVD) to 7255' MD 5782' TVD 80 rpm 5 -5.5k tq on bottom 5k tq off bottom 350 gpm @ 2950 psi 5 -17k wt on bit. Pump screen clean sweep, 10 bbl nut plug sweeps every 1000 strokes pumped ecd,s 11.48. total bit hrs. 31.37 jar hrs. 31.37 total drilled hrs. 31.37 total slide hrs. 11.45 total rotating hrs. 19.92 . 6 hr tour hrs. 1.5 ast art 2.63 adt 4.13 06:00 12:00 6.00 7,255 7,534 INTRM1 DRILL DDRL T Directional drlg. from 7255' and 5782' tvdto 7534' and 5995' tvd 80 rpm 5.5k tq on bottom 5k tq off bottom 325 gpm @ 3040 psi on bottom 2850 psi off bottom5 -15k wt on bit ecd,s 11.52. 12:00 18:00 6.00 7,534 7,816 INTRM1 DRILL DDRL T directional drlg. from 7534' and 5995' tvd to 7816' and 6202 tvd total bit hrs. 38.16 jar hrs 38.16 total rot hrs 24.83 total slide hrs 13.33 1/2 tour slide hrs .57 rot 2.72 adt 3.29. Page 52 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,816 8,135 INTRMI DRILL DDRL T directional drlg. from 7816' and 6202' tvd to 8135' and 6436' tvd back ream all stands 2x @ the depth of 7723 to td. Total bit hrs. 41.46 jar hrs 41.46 total rot hrs 27.86 total slide hrs13.60 1/2 tour slide .27 rot 3.03 adt 3.30 on bottom psi 2860 -3130 off bottom psi2600 -3030 flow rate 325 -350 gpm tq on bottom 5 -6.5k tq off bottom 5.5 -6.5k rpm 80 flow rate © 31% no gas observed wob 5 -15k pu wt 165k sow 115k ecd,s 11.44- 11.86. SPR @ 7533 and 5994 tvd mp #1 30 spm 800 psi 40 960 psi mp #2 30 spm 800 psi 40 960 psi. spr @ 8004 and 6344 tvd mp #1 30 spm 690 psi 40 980 psi #2 30 spm 680 40 930 psi 06/27/2010 TD well. CBU & wiper trip clean hole. POOH lay down BHA & rig up to run liner. 00:00 00:30 0.50 8,135 8,190 INTRMI DRILL DDRL T Directional drlg. 6 1/8" hole from 8135' and 6436' tvd to TD @ 8190' and 6475' tvd. 80 rpm 7k tq on bottom 7k tq off bottom 356 gpm 3280 psi on bottom 3100 psi off bottom 5 -8k wob ecd,s 11.71 puw 170k sow 120k rot wt 125k. Total bit hrs. 42.11 Jars 42.11 Total drilled hrs. 42.11 Slide hrs. 13.6 Rot hrs. 28.51 Tour hrs. AST 0 ART .65 ADT .65 00:30 02:00 1.50 8,190 8,190 INTRM1 DRILL CIRC T Circ 3x bottoms up 356 gpm @ 3100 psi 80 rpm 7k tq. PJSM 02:00 03:30 1.50 8,190 8,190 INTRMI DRILL WPRT T Wiper trip from 8190' and to 7537' and calculated displacement -4.2 bbls. actual +1.5 bbl. RIH f/ 7537 to 8190'. Hole not taking fluid. 03:30 05:00 1.50 8,190 8,190 INTRM1 DRILL CIRC T Circ @ 350 gpm 3100 psi 7k tq 80 rpm & build mud wt from 9.8+ to 10.0 ppg. SPR @ 8190' and 6475 tvd mp #1 30 spm 720 psi 40 spm 1010 psi mp #2 30 spm 810 psi 40 spm 940 psi. Observe well for flow. 05:00 07:00 2.00 8,190 6,415 INTRM1 DRILL WPRT T Wiper trip from 8190' MD to 6415' MD. Monitor well. 07:00 08:30 1.50 6,415 8,190 INTRMI DRILL WPRT T RIH from 6415' MD to 8190' MD. Hole in good condition, no fill on bottom 08:30 10:00 1.50 8,190 8,190 INTRM1 DRILL CIRC T Circ. 20 bbl hi vis sweep @ 350 gpm 3040 psi 80 rpm 6k tq ecd,s 11.66 10:00 10:30 0.50 8,190 8,190 INTRMI DRILL CIRC T Pump 40 bbl liner running pill chase with 48 bbl mud. 10:30 12:00 1.50 8,190 7,349 INTRM1 DRILL TRIP T Pump out of hole from 8190' MD to 7349' MD 84 gpm @ 430 psi POH @ 50 fpm to spot liner running pill. & poh. SPR @ 8190' MD 6475 tvd mp #1 30 spm 720 psi 40 spm 1010 psi mp #2 30 spm 810 psi 40 spm 940 psi. Page 53 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 7,349 6,600 INTRMI DRILL TRIP T Continue pump out of hole to double check hole fill from 7349' to 6600' @ 84 gpm 430 psi calculated hole fill for last 5 stands 2.7 bbl. Actual 3.0 bbls. 13:00 14:00 1.00 6,600 5,085 INTRM1 DRILL TRIP T POH on elevators from 6600' to 5085' hole fill correct. 14:00 15:00 1.00 5,085 5,085 INTRMI DRILL CIRC T CBU X2 for a total of 329 bbls. @ 330 gpm 2250 psi 60 rpm orient © 65 deg befor pulling thru window & monitor well. 15:00 17:30 2.50 5,085 1,900 INTRMI DRILL TRIP T POH on elevators from 5085' to 1900'. 17:30 18:00 0.50 1,900 1,900 INTRM1 RIGMNTSVRG T Service top drive & drawworks. 18:00 18:30 0.50 1,900 627 INTRMI DRILL TRIP T POH from 1900' to 627'. 18:30 20:00 1.50 627 0 INTRMI DRILL PULD T Lay down drill collars & 1 jt. hwdp bha to mwd tool. 20:00 21:00 1.00 0 0 INTRM1 DRILL PULD T Down load MWD while cleaning rig floor. 21:00 22:00 1.00 0 0 INTRMI DRILL PULD T Finish lay down bha milk the motor break off bit. 22:00 22:30 0.50 0 0 INTRMI DRILL PULD T Clean & clear rig floor after wet trip. 22:30 23:00 0.50 0 0 INTRM1 CASING RURD T Rig up to run 3.5" liner. 23:00 00:00 1.00 0 0 INTRMI CASING SFTY T PJSM for running liner & pick up shoe jt. 06/28/2010 Running & cementing 3,5" liner, 00:00 04:30 4.50 0 3,200 INTRMI DRILL RUNL T RIH w/ 3.5" 9.3# IBT liner Check floats & fill every jt. top off every 5 jts. average make up tq 2400 ftlbs 04:30 07:00 2.50 3,200 3,532 INTRM1 DRILL PULD T Make up seal bore assembly. change elevators to 4" dp m/u liner hanger & running tool m/u 2 3/8" stinger make up wiper dart. P/U wt 64k sow 64k move hwdp out of way of dp. 07:00 08:00 1.00 3,532 4,840 INTRMI DRILL RUNL T RIH w/ 3.5" liner on dp from 3532' to 4840'. 08:00 09:00 1.00 4,840 4,840 INTRM1 DRILL CIRC T CBU @ 4.5 bpm @ 720 psi cond mud & monitor well. 09:00 10:00 1.00 4,840 4,913 INTRM1 DRILL RUNL T RIH from 4840' to 4913' p/u 80k sow 76k tag w/ 10k wt rotate pipe 1 turn to left s/o 20 -30k circ @ 1.3 bpm 220 psi. could not get all the way thru window. 10:00 11:00 1.00 4,913 3,532 INTRMI DRILL TRIP T Monitor well poh from 4913' to 3532'. 11:00 12:00 1.00 3,532 3,532 INTRMI DRILL RURD T Rig up power tongs & clean rig floor. 12:00 12:30 0.50 3,532 3,532 INTRM1 RIGMNTSVRG T Service rig & floor equipment. 12:30 13:30 1.00 3,532 3,532 INTRM1 DRILL PULD T Remove liner wiper plug c/o dies in power tongs I/d liner hanger lay down slick stick. 13:30 16:00 2.50 3,532 0 INTRM1 DRILL TRIP T POH w/ 3.5" liner from 3532' to surface calculated hole fill 11.2 bbls actual 11.4 bbls. Page 54 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/28/2010 24 hr Summary Running & cementing 3.5" liner 16:00 16:30 0.50 0 0 INTRMI DRILL PULD T Clean rig floor while changing out tong dies. 16:30 19:00 2.50 0 3,300 INTRMI DRILL RUNL T Install 3 bow spring centralizers 5' above shoe 1 each above & below float collar & landing collar. RIH w/ liner changing out seal rings in all connections.. 19:00 20:00 1.00 3,300 3,300 INTRMI DRILL PULD T Make up wiper plug & liner hanger assembly. 20:00 21:30 1.50 3,300 6,532 INTRMI DRILL RUNL T RIH from 3300' to6532'. Went thru window clean no bobbles 21:30 22:30 1.00 6,532 6,532 INTRMI DRILL CIRC T Circ well bore volume 221 bbls @ 6532' @ 5 bpm 1050 psi. 22:30 23:30 1.00 6,532 8,190 INTRM1 DRILL RUNL P RIH from 6532' to 8190' no fill or bridges. 23:30 00:00 0.50 8,190 8,190 INTRM1 DRILL CIRC P Circ. obtain parameters puw 123k sow 93k start circ @ 3 bpm 670 psi. 06/29/2010 Land & cement liner. lay down some dp. Trip for packer setting tool. Set packer test same. (Test Failed) 00:00 00:30 0.50 8,190 8,190 INTRM1 CASING CIRC P Circ stage up pump rate f/ 3 bpm to 5.5 bpm @ 1500 psi. 00:30 02:00 1.50 8,190 8,190 INTRM1 CEMEN" CIRC P Rig up cement head circ hole @ 5.5 bpm 1500 psi total 3900 strokes. PJSM on cementing liner. 02:00 03:00 1.00 8,190 8,190 INTRMI CEMEN' CMNT P Pump 3 bbl water pressure test lines to 4000 psi ok pump 40 bbl chemwash pump 40 bbl mudpush 2 l pump 119 bbl 15.8# cement kick out ' r plug & pump @ 5 bpm 1040 psi icp 1550 fcp bump plug & pressure to 3500 psi bleed off & check floats ok p/u to 110k s/o to 84k rotate 14 turns to release from hanger p/ up 8'. CIP @ 0300 hrs. 03:00 04:00 1.00 8,190 8,190 INTRMI CEMEN CIRC P Circ hole @ 10 bpm recovered 40 bbl chemwash & 20 -25 bbl mudpush then 10 ppg mud no cement. Full returns thru out cement job. No losses. 04:00 05:00 1.00 8,190 0 INTRM1 DRILL PULD P Monitor well. Lay down cement head. Break down cement lines. 05:00 05:30 0.50 0 0 INTRM1 DRILL CIRC P Pump 10 bbl dry job & blow down top drive. 05:30 07:00 1.50 0 0 INTRMI DRILL PULD P poh & stand in derrick from 4665' to 3363'. Lay down dp from 3363' to 3020'. 07:00 08:00 1.00 0 0 INTRM1 RIGMN1 SVRG P Service & inspect top drive & rig equipment. 08:00 11:00 3.00 0 0 INTRMI DRILL PULD P Lay down dp from 3020' to 1961'. Monitor well & POH from 1961' to 0.0 11:00 12:00 1.00 0 0 INTRMI DRILL PULD P Lay down 20' 2 3/8" slick stick & pick up pups w/ bull nose. 12:00 12:30 0.50 0 0 INTRMI DRILL PULD P Make up assembly for setting packer. 12:30 14:30 2.00 0 0 INTRM1 DRILL TRIP P RIH to 4639'. Actual hole fill 24 bbls. Calculated 24.3 bbls. Page 55 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment - 14:30 15:00 0.50 0 0 INTRMI DRILL PACK P Make up to top drive & obtain parameters PU 97k sow 85k rih to no go out @ 4716'. Set down 30k to set packer & 35k to set dawg sub verify setting w/ 40k down. 15:00 16:00 1.00 0 0 INTRMI DRILL PRTS P Rig up to test packer. Test lines to 2800 psi & test packer to 2500 psi. (Test Failed) 16:00 16:30 0.50 0 0 INTRMI DRILL PRTS T Pick up single & rotate 5 rpm while setting down 35k on on liner hanger. 16:30 18:00 1.50 0 0 INTRMI DRILL PRTS T Lay down single & rig up to retest packer Reverse circ to get air out of system. Test packer to 2500 psi Test Failed) 18:00 20:30 2.50 0 0 INTRM1 DRILL TRIP P POH from 4685' to surface. 20:30 21:00 0.50 0 0 INTRMI DRILL PULD P Break & lay down liner hanger running tool. 21:00 22:00 1.00 0 0 INTRM1 DRILL PULD T Make up Baker retriev -o -matic packer w/ rotating dog sub & sleeve packoff. 22:00 00:00 2.00 0 0 INTRM1 DRILL TRIP T RIH to 3016'. RIH slow due to mud flowing over dp. 06/30/2010 Find leak in liner. Test liner packer & annulus 2500 psi 30 mins. OK displace well to seawater. Lay down dp & run completion. 00:00 01:00 1.00 0 0 INTRMI DRILL TRIP T RIH from 3016' to 4601'. PUW 97k SOW 83k. 01:00 02:00 1.00 0 0 INTRMI DRILL CIRC T Circ. surface to surface volume 155 bbls. 4 bpm 410 psi 02:00 03:30 1.50 0 0 INTRMI DRILL PRTS T RIH from 4601' to 4665'. no-go @ l 4674' s/o 38k test 3.5" liner to 2500 psi bled to 1900 psi in 10 mins. Bleed pressure off to 0 Line up to "" 4 test annulus & liner top packer. Test ' V to 2500 psi for 30 mins. chart same. � (r 11 No bleed off test good. Bleed off pressure. Pull seals out of liner top. 03:30 04:00 0.50 0 0 INTRMI DRILL SFTY P PJSM on displacing well to inhibited seawater 04:00 05:00 1.00 0 0 INTRMI DRILL CIRC P Pump 20 bbl hi vis spacer & chase w/ 200 bbl seawater @ 5 bpm 560 psi monitor well blow down top drive PJSM on laying down dp. 05:00 10:00 5.00 0 0 INTRM1 DRILL PULD P Lay down drill pipe & test packer. 10:00 10:30 0.50 0 0 INTRM1 DRILL PULD P Clean & clear rig floor. 10:30 11:30 1.00 0 0 INTRMI DRILL PULD P Make up 3.5" mule shoe xo & 4 stands hwdp rih to 2519'. 11:30 13:30 2.00 0 0 INTRM1 DRILL PULD P Monitor well & lay down dp & hwdp. 13:30 14:00 0.50 0 0 INTRM1 DRILL RURD P Break down cement head service break & all connections on cement head. 14:00 14:30 0.50 0 0 INTRM1 DRILL RURD P Drain stack & pull wear ring Mobilize tbg. equipment. 14:30 15:00 0.50 0 0 INTRMI RPCOM RURD P Rig up 3.5" handling equipment Make up safety valve on x over. Page 56 of 58 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 0 0 INTRM1 RPCOM SFTY P PJSM make up tbg. jewelry. 16:00 18:30 2.50 0 0 INTRMI RPCOM RCST P RIH w/ 3.5" 9.3#1-80 eue 8 rd completion to 2600' make up torque 2600 fibs. 18:30 19:30 1.00 0 0 INTRM1 RPCOM SFTY P Tool box safety meeting Rig up camco spooler. 19:30 00:00 4.50 0 0 INTRMI RPCOM RCST P RIH w/ 3.5" completion string w/ control line to 4443'. 07/01/2010 Run & land 3.5" completion nipple down bope nipple up tree.freeze protect & release rig. 00:00 00:30 0.50 0 0 INTRM1 RPCOM RCST P RIH from 4443' to 4695' w/ 3.5" 9.3# L -80 eue 8 rd tbg.. 00:30 02:00 1.50 0 0 INTRM1 RPCOM RCST P PUW 73k SOW 67k RIH to 4703' tag no go @ 4719' Pull to 4631' Pick up space out pups 10.18' 10.13' & 8.02' Make up tbg. hanger 3.13' & terminate control line. 02:00 02:30 0.50 0 0 INTRM1 DRILL PULD P Remove short top drive bails. Install long bails. Make up landing jt. & circulating equipment. 02:30 03:00 0.50 0 0 INTRMI DRILL SFTY P PJSM on displacing well. Pressure test lines to 2500 psi. 03:00 04:30 1.50 0 0 INTRMI DRILL CIRC P Displace well w/ 162 bbl 8.4 corrosion inhibited brine 4 bpm @ 200 psi & monitor well. 04:30 05:30 1.00 0 0 INTRMI DRILL HOSO P Drain bop stack blow down choke & kill lines. Lamnd tbg. hanger Tag w/ 15k @ 4710. RILDS. 05:30 06:00 0.50 0 0 INTRMI DRILL CIRC P Line up & pump down annulus to 1800 psi shear dck valve. 06:00 06:30 0.50 0 0 INTRM1 WHDBO OTHR P Rig down circ. equipment drain bop stack set BPV 1 06:30 13:00 6.50 0 0 INTRMI WHDBO NUND P PJSM on nipple down bope. Clean out flow line & drip pan. Clean out drawworks drip pan. Rig down super sucker hose. 13:00 17:30 4.50 0 0 INTRM1 WHDBO NUND P Nipple down bope. Clean up well head. Bleed psi off control line. Nipple up adapter spool & tree. Test adapter spoll 5000 psi 10 mins. Check BPV for pressure. pull bpv set tree test plug. Test tree 5000 psi 15 mins. OK Pull tree test plug. 17:30 20:30 3.00 0 0 INTRM1 WHDBO PRTS P PJSM . Pressure test lines 3500 psiPump 85 bbl diesel down annulus @ lbpm final pressure @ 500 psi. Allow well to 'U' tube. Break down mud manifold. Send out x overs. 20:30 21:30 1.00 0 0 INTRM1 WHDBO OTHR P Close sssv & bleed off pressure. Drain tree. dry rod in bpv blow down circ. lines r/d cellar install all gauges on tree. o psi on all valves annulus & tbg. Page 57 of 58 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 0 INTRMI DRILL RURD P Bridle up rig down floor tuggers continue cleaning pits clean iron roughneck & spinner flip over cattle chute. WELL SECURED. RELEASE RIG @ MIDNIGHT 7 -01 -2010. Page 58 of 58 • • �N. ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N -16A 500292159301 Sperry Drilling Services Definitive Survey Report 06 July, 2010 HALLIBURTON 4 _ Sperry Drilling Services 0 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project Kuparuk River Unit TVD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Weilbore: 3N - 16A Survey Calculation Method: Minimum Curvature Design: 3N -16A Database: CPAI EDM Production 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 3N - 16 Well Position +N / -S 0.00 ft Northing: 6,013,799.25ft Latitude: 70° 26' 55.947 N +E / -W 0.00 ft Easting: 518,370.74 ft Longitude: 149° 51' 0.470 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.10ft Wellbore 3N -16A Magnetics Model Name Sample Date Declination D ip Angle Field Strength ( °) (°) (nT) BGGM2009 6/20/2010 21.65 80.91 57,670 Design 3N -16A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,792.28 Vertical Section: Depth From (TVD) +NI-S +E/ -W D irection (ft) (ft) (ft) (1 26.18 0.00 0.00 121.99 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 92.28 4,792.28 3N -16 (3N -16) GCT -MS Schlumberger GCT multishot 1/15/2001 1: 4,882.00 8,122.54 3N -16A (R1500) (3N -16A) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 6/24/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) ( °1100')- (ft) Survey Tool Name 26.18 0.00 0.00 26.18 -34.10 0.00 0.00 6,013,799.25 518,370.74 0.00 0.00 UNDEFINED 92.28 0.18 134.40 92.28 32.00 -0.07 0.07 6,013,799.18 518,370.81 0.27 0.10 GCT -MS (1) 192.28 0.35 111.97 192.28 132.00 -0.30 0.47 6,013,798.95 518,371.21 0.20 0.56 GCT -MS (1) 292.28 0.33 81.50 292.28 232.00 -0.37 1.04 6,013,798.88 518,371.78 0.18 1.08 GCT -MS (1) 392.28 0.52 72.62 392.27 331.99 -0.19 1.76 6,013,799.06 518,372.50 0.20 1.59 GCT -MS (1) 492.28 0.62 82.98 492.27 431.99 0.01 2.73 6,013,799.27 518,373.47 0.14 2.31 GCT -MS (1) 592.28 0.67 98.72 592.26 531.98 -0.01 3.84 6,013,799.25 518,374.58 0.18 3.26 GCT -MS (1) 692.28 1.28 107.73 692.25 631.97 -0.44 5.48 6,013,798.82 518,376.22 0.63 4.88 GCT -MS (1) 792.28 3.05 115.37 792.17 731.89 -1.92 8.95 6,013,797.35 518,379.69 1.79 8.61 GCT -MS (1) 892.28 6.55 118.63 891.81 831.53 -5.79 16.36 6,013,793.50 518,387.12 3.51 16.95 GCT -MS (1) 992.28 9.93 121.18 990.76 930.48 -12.99 28.75 6,013,786.33 518,399.52 3.40 31.27 GCT -MS (1) 1,092.28 12.95 125.87 1,088.76 1,028.48 -24.03 45.21 6,013,775.34 518,416.00 3.16 51.07 GCT -MS (1) 1,192.28 15.67 127.23 1,185.65 1,125.37 -38.76 65.05 6,013,760.65 518,435.88 2.74 75.70 GCT -MS (1) 7/6/2010 9:57:50AM Page 2 COMPASS 2003.16 Build 69 1 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project: Kuparuk River Unit TVD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N - 16A Survey Calculation Method: Minimum Curvature Design: 3N - 16A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD 1VDSS +Ni-S +E! W Northing Easting DLS Section (ft) (°) ( (ft) (ft) (ft) (ft) (ft) (ft) ( °110') (ft) Survey Tool Name 1,292.28 17.57 125.33 1,281.47 1,221.19 -55.67 88.12 6,013,743.81 518,458.98 1.98 104.22 GCT -MS (1) 1,392.28 20.57 124.32 1,375.97 1,315.69 -74.30 114.94 6,013,725.24 518,485.86 3.02 136.85 GCT -MS (1) 1,492.28 22.42 121.12 1,469.02 1,408.74 -94.07 145.78 6,013,705.55 518,516.74 2.19 173.48 GCT -MS (1) 1,592.28 25.32 119.37 1,560.46 1,500.18 - 114.41 180.75 6,013,685.29 518,551.75 2.98 213.92 GCT -MS (1) 1,692.28 28.47 120.32 1,649.63 1,589.35 - 136.94 219.97 6,013,662.87 518,591.03 3.18 259.11 GCT -MS (1) 1,792.28 30.47 121.47 1,736.69 1,676.41 - 162.21 262.18 6,013,637.70 518,633.29 2.08 308.30 GCT -MS (1) 1,892.28 32.43 122.00 1,821.99 1,761.71 - 189.66 306.54 6,013,610.37 518,677.72 1.98 360.47 GCT -MS (1) 1,992.28 35.52 121.80 1,904.91 1,844.63 - 219.18 353.98 6,013,580.96 518,725.23 3.09 416.34 GCT -MS (1) 2,092.28 38.42 121.73 1,984.80 1,924.52 - 250.84 405.11 6,013,549.44 518,776.43 2.90 476.48 GCT -MS (1) 2,192.28 41.63 121.33 2,061.36 2,001.08 - 284.46 459.92 6,013,515.95 518,831.32 3.22 540.78 GCT -MS (1) 2,292.28 44.55 121.13 2,134.38 2,074.10 - 319.87 518.34 6,013,480.69 518,889.81 2.92 609.08 GCT -MS (1) 2,392.28 46.95 121.78 2,204.16 2,143.88 - 357.25 579.43 6,013,443.46 518,950.99 2.44 680.70 GCT -MS (1) 2,492.28 49.45 122.17 2,270.81 2,210.53 - 396.73 642.66 6,013,404.14 519,014.31 2.52 755.24 GCT -MS (1) 2,592.28 50.80 122.15 2,334.92 2,274.64 - 437.58 707.63 6,013,363.46 519,079.37 1.35 831.98 GCT -MS (1) 2,692.28 51.32 122.60 2,397.77 2,337.49 - 479.23 773.32 6,013,321.97 519,145.16 0.63 909.76 GCT -MS (1) 2,792.28 52.00 122.93 2,459.80 2,399.52 - 521.68 839.27 6,013,279.69 519,211.21 0.73 988.19 GCT -MS (1) I 2 52.62 122.95 2,520.94 2,460.66 - 564.71 905.68 6,013,236.83 519,277.72 0.62 1,067.31 GCT -MS (1) 2,992.28 52.32 123.78 2,581.86 2,521.58 - 608.32 971.91 6,013,193.39 519,344.05 0.72 1,146.59 GCT -MS (1) 3,092.28 52.07 124.77 2,643.15 2,582.87 - 652.81 1,037.20 6,013,149.06 519,409.45 0.82 1,225.54 GCT -MS (1) ' 3,192.28 52.18 125.77 2,704.55 2,644.27 - 698.39 1,101.65 6,013,103.64 519,474.00 0.80 1,304.34 GCT -MS (1) 3,292.28 52.13 125.95 2,765.90 2,705.62 - 744.65 1,165.65 6,013,057.55 519,538.10 0.15 1,383.13 GCT -MS (1) 3,392.28 52.77 125.92 2,826.85 2,766.57 - 791.18 1,229.84 6,013,011.18 519,602.40 0.64 1,462.22 GCT -MS (1) 3,492.28 53.17 125.95 2,887.07 2,826.79 - 838.03 1,294.48 6,012,964.49 519,667.15 0.40 1,541.86 GCT -MS (1) 3,592.28 53.55 126.03 2,946.75 2,886.47 - 885.18 1,359.40 6,012,917.51 519,732.18 0.39 1,621.91 GCT -MS (1) 3,692.28 53.70 126.08 3,006.05 2,945.77 - 932.57 1,424.49 6,012,870.28 519,797.39 0.16 1,702.22 GCT -MS (1) I 3,792.28 54.08 126.33 3,064.99 3,004.71 - 980.29 1,489.68 6,012,822.73 519,862.69 0.43 1,782.79 GCT -MS (1) I 3,892.28 54.15 126.47 3,123.60 3,063.32 - 1,028.37 1,554.89 6,012,774.82 519,928.01 0.13 1,863.57 GCT -MS (1) 3,992.28 54.90 126.88 3,181.64 3,121.36 - 1,077.01 1,620.21 6,012,726.34 519,993.44 0.82 1,944.73 GCT -MS (1) 4,092.28 55.32 126.98 3,238.84 3,178.56 - 1,126.30 1,685.78 6,012,677.22 520,059.12 0.43 2,026.45 GCT -MS (1) 4,192.28 55.53 126.97 3,295.59 3,235.31 - 1,175.82 1,751.56 6,012,627.87 520,125.01 0.21 2,108.48 GCT -MS (1) 4,292.28 55.70 127.02 3,352.06 3,291.78 - 1,225.48 1,817.47 6,012,578.38 520,191.04 0.17 2,190.69 GCT -MS (1) 4,392.28 55.85 127.20 3,408.31 3,348.03 - 1,275.37 1,883.41 6,012,528.66 520,257.10 0.21 2,273.05 GCT -MS (1) 4,492.28 55.95 127.43 3,464.37 3,404.09 - 1,325.56 1,949.26 6,012,478.63 520,323.07 0.22 2,355.50 GCT -MS (1) 4,592.28 55.95 127.57 3,520.36 3,460.08 - 1,376.00 2,015.00 6,012,428.36 520,388.92 0.12 2,437.97 GCT -MS (1) 4,692.28 56.10 127.80 3,576.25 3,515.97 - 1,426.70 2,080.63 6,012,377.83 520,454.67 0.24 2,520.49 GCT -MS (1) 4,792.28 55.92 128.03 3,632.15 3,571.87 - 1,477.65 2,146.04 6,012,327.04 520,520.20 0.26 2,602.96 GCT -MS (1) 4,882.00 56.06 127.75 3,682.33 3,622.05 - 1,523.32 2,204.73 6,012,281.52 520,579.00 0.30 2,676.93 MWD +IFR- AK- CAZ -SC (2) 4,947.04 53.43 133.85 3,719.90 3,659.62 - 1,557.96 2,244.93 6,012,246.98 520,619.28 8.66 2,729.38 MWD +IFR- AK- CAZ -SC (2) 5,003.30 53.22 139.36 3,753.52 3,693.24 - 1,590.73 2,275.91 6,012,214.30 520,650.34 7.86 2,773.01 MWD +IFR- AK- CAZ -SC (2) 5,039.93 52.81 142.98 3,775.56 3,715.28 - 1,613.51 2,294.26 6,012,191.56 520,668.74 7.97 2,800.64 MWD +IFR- AK- CAZ -SC (2) 7/6/2010 9:57:50AM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference:. 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N - 16A Survey Calculation Method:. Minimum Curvature Design: 3N - 16A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Ail TVD 1VDSS +Ni-S +EI -W Northing Easting DLS Section (ft) ( °). _ - ( ° ) (ft) (ft) (ft) (ft) (ft) (ft) ( °110) (ft) Survey Toot Name 5,094.81 52.01 148.49 3,809.05 3,748.77 - 1,649.42 2,318.73 6,012,155.71 520,693.30 8.09 2,840.43 MWD +IFR -AK- CAZ -SC (2) 5,135.41 51.31 151.89 3,834.24 3,773.96 - 1,677.04 2,334.56 6,012,128.14 520,709.20 6.79 2,868.49 MWD +IFR -AK- CAZ -SC (2) 5,182.43 49.31 151.55 3,864.27 3,803.99 - 1,708.90 2,351.70 6,012,096.32 520,726.41 4.29 2,899.90 MWD +IFR -AK- CAZ -SC (2) 5,228.12 46.95 153.18 3,894.76 3,834.48 - 1,739.04 2,367.49 6,012,066.23 520,742.27 5.81 2,929.26 MWD +IFR -AK- CAZ -SC (2) 5,275.26 45.06 153.75 3,927.50 3,867.22 - 1,769.37 2,382.64 6,012,035.93 520,757.50 4.10 2,958.18 MWD +IFR -AK- CAZ -SC (2) 5,320.85 42.06 153.58 3,960.54 3,900.26 - 1,797.53 2,396.58 6,012,007.81 520,771.50 6.59 2,984.91 MWD +IFR -AK- CAZ -SC (2) 5,367.05 39.57 153.54 3,995.50 3,935.22 - 1,824.56 2,410.02 6,011,980.81 520,785.01 5.39 3,010.64 MWD +IFR -AK- CAZ -SC (2) 5,413.46 37.41 152.78 4,031.82 3,971.54 - 1,850.34 2,423.06 6,011,955.07 520,798.11 4.76 3,035.35 MWD +IFR -AK- CAZ -SC (2) 5,461.71 34.08 152.48 4,070.98 4,010.70 - 1,875.37 2,436.01 6,011,930.08 520,811.12 6.91 3,059.60 MWD +IFR -AK- CAZ -SC (2) 5,507.11 31.08 151.65 4,109.23 4,048.95 - 1,896.97 2,447.46 6,011,908.51 520,822.62 6.68 3,080.74 MWD +IFR -AK- CAZ -SC (2) 5,558.74 29.93 152.34 4,153.71 4,093.43 - 1,920.10 2,459.76 6,011,885.41 520,834.98 2.33 3,103.44 MWD +IFR -AK- CAZ -SC (2) 5,601.51 27.09 151.61 4,191.29 4,131.01 - 1,938.12 2,469.35 6,011,867.41 520,844.61 6.69 3,121.12 MWD +IFR -AK- CAZ -SC (2) 5,649.65 25.09 151.52 4,234.53 4,174.25 - 1,956.74 2,479.43 6,011,848.82 520,854.74 4.16 3,139.53 MWD +IFR -AK- CAZ -SC (2) 5,694.21 21.96 151.69 4,275.38 4,215.10 - 1,972.38 2,487.89 6,011,833.20 520,863.23 7.03 3,154.99 MWD +IFR -AK- CAZ -SC (2) 5,739.86 18.54 150.91 4,318.20 4,257.92 - 1,986.24 2,495.47 6,011,819.36 520,870.85 7.51 3,168.76 MWD +IFR -AK- CAZ -SC (2) 5,782.29 15.91 152.56 4,358.72 4,298.44 - 1,997.30 2,501.43 6,011,808.32 520,876.83 6.30 3,179.68 MWD +IFR -AK- CAZ -SC (2) 5,834.05 13.86 153.31 4,408.74 4,348.46 - 2,009.14 2,507.48 6,011,796.50 520,882.92 3.98 3,191.08 MWD +IFR -AK- CAZ -SC (2) 5,876.30 11.62 156.97 4,449.95 4,389.67 - 2,017.58 2,511.42 6,011,788.07 520,886.87 5.63 3,198.89 MWD +IFR -AK- CAZ -SC (2) 5,928.35 10.34 156.12 4,501.05 4,440.77 - 2,026.67 2,515.36 6,011,778.98 520,890.84 2.48 3,207.05 MWD +IFR -AK- CAZ -SC (2) 5,973.25 7.69 148.17 4,545.39 4,485.11 - 2,032.91 2,518.58 6,011,772.75 520,894.07 6.51 3,213.09 MWD +IFR -AK- CAZ -SC (2) 6,022.23 7.03 148.69 4,593.97 4,533.69 - 2,038.26 2,521.86 6,011,767.42 520,897.37 1.35 3,218.71 MWD +IFR -AK- CAZ -SC (2) 6,067.66 7.00 147.75 4,639.06 4,578.78 - 2,042.97 2,524.79 6,011,762.71 520,900.30 0.26 3,223.68 MWD +IFR -AK- CAZ -SC (2) 6,157.93 7.25 150.92 4,728.63 4,668.35 - 2,052.60 2,530.49 6,011,753.09 520,906.03 0.52 3,233.62 MWD +IFR -AK- CAZ -SC (2) 6,253.62 7.17 149.65 4,823.56 4,763.28 - 2,063.03 2,536.44 6,011,742.68 520,912.01 0.19 3,244.19 MWD +IFR -AK- CAZ -SC (2) 6,348.22 7.00 138.62 4,917.45 4,857.17 - 2,072.45 2,543.24 6,011,733.28 520,918.82 1.45 3,254.95 MWD +IFR -AK- CAZ -SC (2) 6,440.92 7.25 127.88 5,009.43 4,949.15 - 2,080.28 2,551.59 6,011,725.47 520,927.19 1.46 3,266.18 MWD +IFR -AK- CAZ -SC (2) 6,532.97 7.55 115.11 5,100.72 5,040.44 - 2,086.42 2,561.65 6,011,719.36 520,937.27 1.81 3,277.96 MWD +IFR -AK- CAZ -SC (2) 6,627.48 7.30 101.21 5,194.45 5,134.17 - 2,090.22 2,573.16 6,011,715.59 520,948.79 1.91 3,289.74 MWD +IFR -AK- CAZ -SC (2) 6,717.04 7.00 102.95 5,283.31 5,223.03 - 2,092.55 2,584.06 6,011,713.28 520,959.69 0.41 3,300.22 MWD +IFR -AK- CAZ -SC (2) 6,761.58 8.27 99.67 5,327.46 5,267.18 - 2,093.70 2,589.86 6,011,712.15 520,965.50 3.01 3,305.75 MWD +IFR -AK- CAZ -SC (2) 6,809.06 10.53 95.30 5,374.30 5,314.02 - 2,094.67 2,597.55 6,011,711.20 520,973.19 4.99 3,312.78 MWD +IFR -AK- CAZ -SC (2) 6,857.03 13.04 92.61 5,421.25 5,360.97 - 2,095.32 2,607.32 6,011,710.57 520,982.96 5.35 3,321.42 MWD +IFR -AK- CAZ -SC (2) 6,903.02 15.19 91.36 5,465.85 5,405.57 - 2,095.70 2,618.53 6,011,710.22 520,994.17 4.72 3,331.12 MWD +IFR -AK- CAZ -SC (2) 6,950.25 17.31 94.29 5,511.19 5,450.91 - 2,096.37 2,631.73 6,011,709.58 521,007.36 4.81 3,342.67 MWD +IFR -AK- CAZ -SC (2) 6,998.10 20.19 94.66 5,556.50 5,496.22 - 2,097.58 2,647.06 6,011,708.41 521,022.70 6.02 3,356.31 MWD +IFR -AK- CAZ -SC (2) 7,049.02 22.82 95.51 5,603.87 5,543.59 - 2,099.24 2,665.65 6,011,706.80 521,041.29 5.20 3,372.96 MWD +IFR -AK- CAZ -SC (2) 7,092.09 26.08 94.54 5,643.07 5,582.79 - 2,100.79 2,683.40 6,011,705.29 521,059.05 7.63 3,388.84 MWD +IFR -AK- CAZ -SC (2) 7,140.69 29.44 93.01 5,686.07 5,625.79 - 2,102.26 2,705.99 6,011,703.87 521,081.63 7.07 3,408.78 MWD +IFR -AK- CAZ -SC (2) 7,187.26 32.88 94.79 5,725.92 5,665.64 - 2,103.92 2,730.02 6,011,702.27 521,105.67 7.65 3,430.04 MWD +IFR -AK- CAZ -SC (2) 7,238.25 34.97 94.33 5,768.23 5,707.95 - 2,106.18 2,758.39 6,011,700.08 521,134.03 4.13 3,455.29 MWD +IFR -AK- CAZ -SC (2) 7/6/2010 9:57:50AM Page 4 COMPASS 2003.16 Build 69 1 ConocoPhillips (Alaska) Inc. Definitive Survey Report -- Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Protect: Kuparuk River Unit TVD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N - 16A Survey Calculation Method: Minimum Curvature Design: 3N - 16A Database: CPAI EDM Production Survey Map Map vertical MD Inc Azi TVD TVDSS +N/-S +E!-W Northing Easting DLS Section (ff► (°) (1 (R) (ft) (ft) (ft) (ft) (ft) ( °!100') (to Survey Tool Name 7,275.16 36.55 94.20 5,798.18 5,737.90 - 2,107.78 2,779.90 6,011,698.53 521,155.55 4.29 3,474.39 MWD +IFR -AK- CAZ -SC (2) 7,331.39 39.08 94.47 5,842.59 5,782.31 - 2,110.39 2,814.27 6,011,696.01 521,189.92 4.51 3,504.92 MWD +IFR -AK- CAZ -SC (2) 7,369.43 41.03 93.11 5,871.71 5,811.43 - 2,112.00 2,838.69 6,011,694.46 521,214.35 5.62 3,526.49 MWD +IFR -AK- CAZ -SC (2) 7,417.68 41.63 92.18 5,907.94 5,847.66 - 2,113.47 2,870.52 6,011,693.07 521,246.18 1.78 3,554.26 MWD +IFR -AK- CAZ -SC (2) 7,467.17 42.10 91.76 5,944.80 5,884.52 - 2,114.61 2,903.53 6,011,692.02 521,279.19 1.11 3,582.86 MWD +IFR -AK- CAZ -SC (2) 7,559.39 41.85 90.82 6,013.36 5,953.08 - 2,116.00 2,965.19 6,011,690.78 521,340.84 0.73 3,635.89 MWD +IFR -AK- CAZ -SC (2) 7,650.55 43.03 91.40 6,080.63 6,020.35 - 2,117.19 3,026.70 6,011,689.73 521,402.34 1.36 3,688.69 MWD +IFR -AK- CAZ -SC (2) 7,744.86 42.23 92.21 6,150.02 6,089.74 - 2,119.20 3,090.53 6,011,687.88 521,466.18 1.03 3,743.90 MWD +IFR -AK- CAZ -SC (2) 7,837.66 41.62 92.51 6,219.07 6,158.79 - 2,121.75 3,152.49 6,011,685.48 521,528.13 0.69 3,797.80 MWD +IFR -AK- CAZ -SC (2) 7,933.07 42.26 92.31 6,290.04 6,229.76 - 2,124.43 3,216.20 6,011,682.96 521,591.84 0.69 3,853.25 MWD +IFR -AK- CAZ -SC (2) 8,024.17 43.41 92.50 6,356.84 6,296.56 - 2,127.03 3,278.08 6,011,680.51 521,653.73 1.27 3,907.11 MWD +IFR -AK- CAZ -SC (2) 8,122.54 42.97 92.76 6,428.56 6,368.28 - 2,130.12 3,345.33 6,011,677.59 521,720.98 0.48 3,965.79 MWD +IFR -AK- CAZ -SC (2) 8,190.00 42.97 92.76 6,477.92 6,417.64 - 2,132.34 3,391.26 6,011,675.49 521,766.91 0.00 4,005.92 PROJECTED to TD 7/6/2010 9:57:50AM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N- 16APB1 500292159370 Sperry Drilling Services Definitive Survey Report 06 July, 2010 MALLIBURTON kss Sperry Drilling Services • ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project Kuparuk River Unit TVD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N 16APB1 Survey Calculation Method: Minimum Curvature Design: 3N- 16APB1 Database: CPAI EDM Production Protect 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 3N -16 Well Position +N/ 0.00 ft Northing: 6,013,799.25ft Latitude: 70° 26' 55.947 N +E/ - 0.00 ft Easting: 518,370.74 ft Longitude: 149° 51' 0.470 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.10ft Welibore 3N 16APB1 Magnetics Mod el Name Sample Date Declination Dip Angle Field Strength ( °) r) ( BGGM2009 5/20/2010 21.69 80.91 57,667 Design 3N 16APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,892.28 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction O (ft) On (') 26.18 0.00 0.00 121.99 Survey Program Date From To (ft) (ft). Survey (Weiibore) Tool Name Description Survey Date 92.28 4,892.28 3N -16 (3N -16) GCT -MS Schlumberger GCT multishot 1/15/2001 1: 4,932.00 5,552.23 3N- 16APB1 (Run 200) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/20/2010 1: 5,599.30 6,160.34 3N- 16APB1 (Run 300) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/22/2010 1: 6,211.30 7,325.02 3N- 16APB1 (Run 400) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/23/2010 1: 7,374.54 8,188.24 3N- 16APB1 (Run 500) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/25/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) ( (ff) (ft) (ft) ( ° / 100 ') (ft) Survey Tool Name 26.18 0.00 0.00 26.18 -34.10 0.00 0.00 6,013,799.25 518,370.74 0.00 0.00 UNDEFINED 92.28 0.18 134.40 92.28 32.00 -0.07 0.07 6,013,799.18 518,370.81 0.27 0.10 GCT -MS (1) 192.28 0.35 111.97 192.28 132.00 -0.30 0.47 6,013,798.95 518,371.21 0.20 0.56 GCT -MS (1) 292.28 0.33 81.50 292.28 232.00 -0.37 1.04 6,013,798.88 518,371.78 0.18 1.08 GCT -MS (1) 392.28 0.52 72.62 392.27 331.99 -0.19 1.76 6,013,799.06 518,372.50 0.20 1.59 GCT -MS (1) 492.28 0.62 82.98 492.27 431.99 0.01 2.73 6,013,799.27 518,373.47 0.14 2.31 GCT -MS (1) 592.28 0.67 98.72 592.26 531.98 -0.01 3.84 6,013,799.25 518,374.58 0.18 3.26 GCT -MS (1) 692.28 1.28 107.73 692.25 631.97 -0.44 5.48 6,013,798.82 518,376.22 0.63 4.88 GCT -MS (1) 792.28 3.05 115.37 792.17 731.89 -1.92 8.95 6,013,797.35 518,379.69 1.79 8.61 GCT -MS (1) 892.28 6.55 118.63 891.81 831.53 -5.79 16.36 6,013,793.50 518,387.12 3.51 16.95 GCT -MS (1) 7/6/2010 9 :59 :48AM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Protect Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N 16APB1 Survey Calculation Method: Minimum Curvature Design: 3N 16APB1 Database: CPAI EDM Production Survey Map Map V ertical MD Inc Azi TVD TVDSS +W-S +E/ -W Northing Easting DLS Section (ft) (°) -(1 (ft) (ft) (ft) (ft) (ft) . (ft) (%10d') (ft) .. Survey Tool Name 1 992.28 9.93 121.18 990.76 930.48 -12.99 28.75 6,013,786.33 518,399.52 3.40 31.27 GCT -MS (1) 1,092.28 12.95 125.87 1,088.76 1,028.48 -24.03 45.21 6,013,775.34 518,416.00 3.16 51.07 GCT -MS (1) 1,192.28 15.67 127.23 1,185.65 1,125.37 -38.76 65.05 6,013,760.65 518,435.88 2.74 75.70 GCT -MS (1) 1,292.28 17.57 125.33 1,281.47 1,221.19 -55.67 88.12 6,013,743.81 518,458.98 1.98 104.22 GCT -MS (1) 1,392.28 20.57 124.32 1,375.97 1,315.69 -74.30 114.94 6,013,725.24 518,485.86 3.02 136.85 GCT -MS (1) 1,492.28 22.42 121.12 1,469.02 1,408.74 -94.07 145.78 6,013,705.55 518,516.74 2.19 173.48 GCT -MS(1) 1,592.28 25.32 119.37 1,560.46 1,500.18 - 114.41 180.75 6,013,685.29 518,551.75 2.98 213.92 GCT -MS (1) 1,692.28 28.47 120.32 1,649.63 1,589.35 - 136.94 219.97 6,013,662.87 518,591.03 3.18 259.11 GCT -MS(1) 1,792.28 30.47 121.47 1,736.69 1,676.41 - 162.21 262.18 6,013,637.70 518,633.29 2.08 308.30 GCT -MS (1) 1,892.28 32.43 122.00 1,821.99 1,761.71 - 189.66 306.54 6,013,610.37 518,677.72 1.98 360.47 GCT -MS (1) 1,992.28 35.52 121.80 1,904.91 1,844.63 - 219.18 353.98 6,013,580.96 518,725.23 3.09 416.34 GCT -MS (1) 2,092.28 38.42 121.73 1,984.80 1,924.52 - 250.84 405.11 6,013,549.44 518,776.43 2.90 476.48 GCT -MS (1) 2,192.28 41.63 121.33 2,061.36 2,001.08 - 284.46 459.92 6,013,515.95 518,831.32 3.22 540.78 GCT -MS (1) 2,292.28 44.55 121.13 2,134.38 2,074.10 - 319.87 518.34 6,013,480.69 518,889.81 2.92 609.08 GCT -MS (1) 2,392.28 46.95 121.78 2,204.16 2,143.88 - 357.25 579.43 6,013,443.46 518,950.99 2.44 680.70 GCT -MS (1) 2,492.28 49.45 122.17 2,270.81 2,210.53 - 396.73 642.66 6,013,404.14 519,014.31 2.52 755.24 GCT -MS (1) 2,592.28 50.80 122.15 2,334.92 2,274.64 - 437.58 707.63 6,013,363.46 519,079.37 1.35 831.98 GCT -MS (1) 2,692.28 51.32 122.60 2,397.77 2,337.49 - 479.23 773.32 6,013,321.97 519,145.16 0.63 909.76 GCT -MS (1) 2,792.28 52.00 122.93 2,459.80 2,399.52 - 521.68 839.27 6,013,279.69 519,211.21 0.73 988.19 GCT -MS (1) 2,892.28 52.62 122.95 2,520.94 2,460.66 - 564.71 905.68 6,013,236.83 519,277.72 0.62 1,067.31 GCT -MS (1) 2,992.28 52.32 123.78 2,581.86 2,521.58 - 608.32 971.91 6,013,193.39 519,344.05 0.72 1,146.59 GCT -MS(1) 3,092.28 52.07 124.77 2,643.15 2,582.87 - 652.81 1,037.20 6,013,149.06 519,409.45 0.82 1,225.54 GCT -MS (1) 3,192.28 52.18 125.77 2,704.55 2,644.27 - 698.39 1,101.65 6,013,103.64 519,474.00 0.80 1,304.34 GCT -MS (1) 3,292.28 52.13 125.95 2,765.90 2,705.62 - 744.65 1,165.65 6,013,057.55 519,538.10 0.15 1,383.13 GCT -MS (1) 3,392.28 52.77 125.92 2,826.85 2,766.57 - 791.18 1,229.84 6,013,011.18 519,602.40 0.64 1,462.22 GCT -MS (1) 3,492.28 53.17 125.95 2,887.07 2,826.79 - 838.03 1,294.48 6,012,964.49 519,667.15 0.40 1,541.86 GCT -MS (1) 3,592.28 53.55 126.03 2,946.75 2,886.47 - 885.18 1,359.40 6,012,917.51 519,732.18 0.39 1,621.91 GCT -MS (1) 3,692.28 53.70 126.08 3,006.05 2,945.77 - 932.57 1,424.49 6,012,870.28 519,797.39 0.16 1,702.22 GCT -MS (1) 3,792.28 54.08 126.33 3,064.99 3,004.71 - 980.29 1,489.68 6,012,822.73 519,862.69 0.43 1,782.79 GCT -MS (1) 1 3,892.28 54.15 126.47 3,123.60 3,063.32 - 1,028.37 1,554.89 6,012,774.82 519,928.01 0.13 1,863.57 GCT -MS (1) 3,992.28 54.90 126.88 3,181.64 3,121.36 - 1,077.01 1,620.21 6,012,726.34 519,993.44 0.82 1,944.73 GCT -MS (1) 4,092.28 55.32 126.98 3,238.84 3,178.56 - 1,126.30 1,685.78 6,012,677.22 520,059.12 0.43 2,026.45 GCT -MS (1) 4,192.28 55.53 126.97 3,295.59 3,235.31 - 1,175.82 1,751.56 6,012,627.87 520,125.01 0.21 2,108.48 GCT -MS (1) 4,292.28 55.70 127.02 3,352.06 3,291.78 - 1,225.48 1,817.47 6,012,578.38 520,191.04 0.17 2,190.69 GCT -MS (1) 4,392.28 55.85 127.20 3,408.31 3,348.03 - 1,275.37 1,883.41 6,012,528.66 520,257.10 0.21 2,273.05 GCT -MS (1) 4,492.28 55.95 127.43 3,464.37 3,404.09 - 1,325.56 1,949.26 6,012,478.63 520,323.07 0.22 2,355.50 GCT -MS (1) 4,592.28 55.95 127.57 3,520.36 3,460.08 - 1,376.00 2,015.00 6,012,428.36 520,388.92 0.12 2,437.97 GCT -MS (1) 4,692.28 56.10 127.80 3,576.25 3,515.97 - 1,426.70 2,080.63 6,012,377.83 520,454.67 0.24 2,520.49 GCT -MS (1) 4,792.28 55.92 128.03 3,632.15 3,571.87 - 1,477.65 2,146.04 6,012,327.04 520,520.20 0.26 2,602.96 GCT -MS (1) 4,892.28 56.07 127.72 3,688.08 3,627.80 - 1,528.54 2,211.47 6,012,276.32 520,585.75 0.30 2,685.42 GCT -MS (1) 7/6/2010 9:59:48AM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Aiaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Protect: Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site Kuparuk 3N Pad MD Reference:. 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well:. 3N - 16 North Reference: True Wellbore: 3N 16APB1 Survey Calculation; Method: Minimum Curvature Design: 3N 16APB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +NI-S +E!-W Northing Easting DLS ° Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Nam 4,932.00 54.78 128.91 3,710.62 3,650.34 - 1,548.81 2,237.14 6,012,256.11 520,611.46 4.08 2,717.92 MWD +IFR -AK- CAZ -SC (2) 4,997.55 55.33 130.96 3,748.17 3,687.89 - 1,583.31 2,278.33 6,012,221.72 520,652.74 2.70 2,771.13 MWD +IFR -AK- CAZ -SC (2) 5,088.27 51.15 133.94 3,802.46 3,742.18 - 1,632.30 2,331.97 6,012,172.86 520,706.49 5.31 2,842.59 MWD +IFR -AK- CAZ -SC (2) 5,171.54 47.32 137.01 3,856.82 3,796.54 - 1,677.21 2,376.21 6,012,128.06 520,750.84 5.38 2,903.90 MWD +IFR -AK- CAZ -SC (2) 5,212.51 48.47 141.46 3,884.30 3,824.02 - 1,700.23 2,396.04 6,012,105.10 520,770.73 8.53 2,932.91 MWD +IFR -AK- CAZ -SC (2) 5,259.02 49.47 143.39 3,914.83 3,854.55 - 1,728.04 2,417.43 6,012,077.35 520,792.18 3.80 2,965.79 MWD +IFR -AK- CAZ -SC (2) 5,326.24 48.61 140.38 3,958.90 3,898.62 - 1,767.97 2,448.75 6,012,037.49 520,823.60 3.62 3,013.51 MWD +IFR -AK- CAZ -SC (2) 5,367.18 47.82 140.46 3,986.18 3,925.90 - 1,791.50 2,468.20 6,012,014.01 520,843.10 1.94 3,042.47 MWD +IFR -AK- CAZ -SC (2) 5,414.42 46.82 136.94 4,018.21 3,957.93 - 1,817.59 2,491.11 6,011,987.99 520,866.07 5.87 3,075.72 MWD +IFR -AK- CAZ -SC (2) 5,458.57 46.29 136.32 4,048.57 3,988.29 - 1,840.89 2,513.12 6,011,964.74 520,888.14 1.57 3,106.73 MWD +IFR -AK- CAZ -SC (2) 5,502.54 46.28 137.09 4,078.96 4,018.68 - 1,864.02 2,534.91 6,011,941.67 520,909.99 1.27 3,137.47 MWD +IFR -AK- CAZ -SC (2) 5,552.23 45.25 136.54 4,113.62 4,053.34 - 1,889.98 2,559.27 6,011,915.77 520,934.41 2.22 3,171.88 MWD +IFR -AK- CAZ -SC (2) 5,599.30 43.09 136.61 4,147.38 4,087.10 - 1,913.80 2,581.82 6,011,892.01 520,957.01 4.59 3,203.62 MWD +IFR -AK- CAZ -SC (3) 5,647.80 39.25 136.65 4,183.89 4,123.61 - 1,937.00 2,603.74 6,011,868.86 520,978.99 7.92 3,234.51 MWD +IFR -AK- CAZ -SC (3) 5,695.29 37.44 135.90 4,221.13 4,160.85 - 1,958.30 2,624.10 6,011,847.62 520,999.40 3.94 3,263.06 MWD +IFR -AK- CAZ -SC (3) 5,739.56 35.39 134.73 4,256.76 4,196.48 - 1,976.99 2,642.57 6,011,828.98 521,017.92 4.89 3,288.62 MWD +IFR -AK- CAZ -SC (3) 5,791.77 32.87 134.43 4,299.97 4,239.69 - 1,997.55 2,663.44 6,011,808.47 521,038.83 4.84 3,317.21 MWD +IFR -AK- CAZ -SC (3) 5,833.94 30.72 135.11 4,335.81 4,275.53 - 2,013.19 2,679.21 6,011,792.87 521,054.64 5.17 3,338.88 MWD +IFR -AK- CAZ -SC (3) 5,886.27 27.92 136.72 4,381.43 4,321.15 - 2,031.58 2,697.05 6,011,774.52 521,072.52 5.56 3,363.75 MWD +IFR -AK- CAZ -SC (3) 5,924.69 25.53 136.85 4,415.75 4,355.47 - 2,044.17 2,708.88 6,011,761.96 521,084.38 6.22 3,380.45 MWD +IFR -AK- CAZ -SC (3) 5,979.93 22.73 136.38 4,466.15 4,405.87 - 2,060.59 2,724.38 6,011,745.59 521,099.92 5.08 3,402.30 MWD +IFR -AK- CAZ -SC (3) 6,017.21 21.21 136.05 4,500.73 4,440.45 - 2,070.66 2,734.03 6,011,735.54 521,109.60 4.09 3,415.82 MWD +IFR -AK- CAZ -SC (3) 6,066.17 20.51 135.29 4,546.48 4,486.20 - 2,083.13 2,746.22 6,011,723.10 521,121.81 1.53 3,432.76 MWD +IFR -AK- CAZ -SC (3) 6,114.30 18.22 136.41 4,591.88 4,531.60 - 2,094.57 2,757.34 6,011,711.69 521,132.96 4.82 3,448.25 MWD +IFR -AK- CAZ -SC (3) 6,160.34 15.12 135.91 4,635.98 4,575.70 - 2,104.10 2,766.48 6,011,702.18 521,142.12 6.74 3,461.06 MWD +IFR -AK- CAZ -SC (3) 6,211.30 12.01 134.20 4,685.51 4,625.23 - 2,112.57 2,774.91 6,011,693.73 521,150.57 6.15 3,472.69 MWD +IFR -AK- CAZ -SC (4) 6,302.68 8.51 130.65 4,775.42 4,715.14 - 2,123.61 2,786.86 6,011,682.73 521,162.54 3.89 3,488.67 MWD +IFR -AK- CAZ -SC (4) 6,392.29 7.74 125.48 4,864.13 4,803.85 - 2,131.43 2,796.80 6,011,674.93 521,172.51 1.18 3,501.25 MWD +IFR -AK- CAZ -SC (4) 6,484.36 8.23 129.56 4,955.31 4,895.03 - 2,139.23 2,806.93 6,011,667.16 521,182.65 0.81 3,513.97 MWD +IFR -AK- CAZ -SC (4) 6,579.18 7.75 130.94 5,049.21 4,988.93 - 2,147.74 2,816.99 6,011,658.67 521,192.74 0.55 3,527.01 MWD +IFR -AK- CAZ -SC (4) 6,671.68 8.01 128.26 5,140.83 5,080.55 - 2,155.82 2,826.76 6,011,650.62 521,202.53 0.49 3,539.58 MWD +IFR -AK- CAZ -SC (4) 6,765.40 7.69 126.63 5,233.67 5,173.39 - 2,163.60 2,836.92 6,011,642.86 521,212.70 0.42 3,552.32 MWD +IFR -AK- CAZ -SC (4) 6,856.78 7.99 127.80 5,324.20 5,263.92 - 2,171.14 2,846.85 6,011,635.35 521,222.65 0.37 3,564.73 MWD +IFR -AK- CAZ -SC (4) 6,952.80 8.53 124.65 5,419.22 5,358.94 - 2,179.28 2,857.98 6,011,627.24 521,233.80 0.73 3,578.49 MWD +IFR -AK- CAZ -SC (4) 7,044.11 8.25 123.78 5,509.56 5,449.28 - 2,186.77 2,868.99 6,011,619.77 521,244.83 0.34 3,591.80 MWD +IFR -AK- CAZ -SC (4) 7,141.75 7.86 126.68 5,606.23 5,545.95 - 2,194.66 2,880.17 6,011,611.92 521,256.03 0.58 3,605.46 MWD +IFR -AK- CAZ -SC (4) 7,232.44 8.84 123.03 5,695.96 5,635.68 - 2,202.16 2,890.99 6,011,604.44 521,266.86 1.23 3,618.60 MWD +IFR -AK- CAZ -SC (4) 7,325.02 12.69 117.17 5,786.90 5,726.62 - 2,210.68 2,906.00 6,011,595.96 521,281.89 4.32 3,635.86 MWD +IFR -AK- CAZ -SC (4) 7,374.54 14.30 117.11 5,835.05 5,774.77 - 2,215.95 2,916.29 6,011,590.71 521,292.19 3.25 3,647.37 MWD +IFR -AK- CAZ -SC (5) 7,417.43 16.35 111.95 5,876.41 5,816.13 - 2,220.62 2,926.60 6,011,586.07 521,302.52 5.74 3,658.59 MWD +IFR -AK- CAZ -SC (5) 7/6/2010 9:59:48AM Page 4 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project Kuparuk River Unit 7VD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Well!bore: 3N 16APB1 Survey Calculation Method: Minimum Curvature Design: 3N 16APB1 Database: CPAI EDM Production Survey Map Map. Vertical MD Inc . Azi WD TVDSS +N/-S +EJ- -W Northing Easting ° DLS Section (ft) (°l ("1 (ft) (ft) (ft) (ft) (ft) (ft) 01001 (ft)'; Survey Tool Name 7,461.90 21.60 100.47 5,918.47 5,858.19 - 2,224.46 2,940.47 6,011,582.27 521,316.39 14.43 3,672.39 MWD +IFR -AK- CAZ -SC (5) 7,514.78 23.18 93.35 5,967.37 5,907.09 - 2,226.83 2,960.44 6,011,579.94 521,336.36 5.93 3,690.58 MWD +IFR -AK- CAZ -SC (5) 7,559.39 22.62 91.87 6,008.46 5,948.18 - 2,227.63 2,977.78 6,011,579.19 521,353.70 1.80 3,705.71 MWD +IFR -AK- CAZ -SC (5) 7,604.13 24.64 91.64 6,049.45 5,989.17 - 2,228.17 2,995.70 6,011,578.69 521,371.63 4.52 3,721.20 MWD +IFR -AK- CAZ -SC (5) 7,655.15 27.99 95.98 6,095.18 6,034.90 - 2,229.73 3,018.25 6,011,577.19 521,394.17 7.57 3,741.14 MWD +IFR -AK- CAZ -SC (5) 7,698.67 30.34 97.38 6,133.18 6,072.90 - 2,232.20 3,039.31 6,011,574.77 521,415.24 5.62 3,760.32 MWD +IFR -AK- CAZ -SC (5) 7,751.80 34.95 99.38 6,177.91 6,117.63 - 2,236.41 3,067.65 6,011,570.63 521,443.58 8.91 3,786.58 MWD +IFR -AK- CAZ -SC (5) 7,792.24 38.52 100.10 6,210.31 6,150.03 - 2,240.51 3,091.48 6,011,566.59 521,467.43 8.89 3,808.97 MWD +IFR -AK- CAZ -SC (5) 7,839.31 42.73 98.85 6,246.03 6,185.75 - 2,245.54 3,121.70 6,011,561.64 521,497.66 9.11 3,837.26 MWD +IFR -AK- CAZ -SC (5) 7,888.64 47.73 98.34 6,280.76 6,220.48 - 2,250.76 3,156.32 6,011,556.50 521,532.29 10.16 3,869.39 MWD +IFR -AK- CAZ -SC (5) 7,940.36 51.29 97.04 6,314.34 6,254.06 - 2,256.01 3,195.30 6,011,551.34 521,571.27 7.14 3,905.23 MWD +IFR -AK- CAZ -SC (5) 7,982.71 52.87 96.78 6,340.36 6,280.08 - 2,260.03 3,228.46 6,011,547.41 521,604.44 3.76 3,935.49 MWD +IFR -AK- CAZ -SC (5) 8,031.13 56.41 97.02 6,368.38 6,308.10 - 2,264.78 3,267.66 6,011,542.76 521,643.64 7.32 3,971.25 MWD +IFR -AK- CAZ -SC (5) 8,075.50 60.12 95.57 6,391.72 6,331.44 - 2,268.90 3,305.16 6,011,538.73 521,681.15 8.81 4,005.24 MWD +IFR -AK- CAZ -SC (5) 8,119.82 62.54 93.16 6,412.98 6,352.70 - 2,271.85 3,343.93 6,011,535.87 521,719.92 7.25 4,039.68 MWD +IFR -AK- CAZ -SC (5) 8,167.05 62.24 90.81 6,434.87 6,374.59 - 2,273.30 3,385.75 6,011,534.52 521,761.74 4.45 4,075.92 MWD +IFR -AK- CAZ -SC (5) 8,188.24 62.23 90.65 6,444.74 6,384.46 - 2,273.54 3,404.50 6,011,534.33 521,780.49 0.67 4,091.95 MWD +IFR -AK- CAZ -SC (5) 8,260.00 62.23 90.65 6,478.18 6,417.90 - 2,274.26 3,467.99 6,011,533.77 521,843.98 0.00 4,146.18 PROJECTED to TD 7/6/2010 9:59 :48AM Page 5 COMPASS 2003.16 Build 69 • • • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N- 16APB2 500292159371 Sperry Drilling Services Definitive Survey Report 06 July, 2010 I 5 , � ti� �i* HALLIBURTON 4 Sperry Drilling Services • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co -ordinate Reference: Well 3N - 16 Project Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N 16APB2 Survey Calculation Method: Minimum Curvature Design: 3N- 16APB2 Database: CPAI EDM Production Protect 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 3N -16 Well Position +N / - 0.00 ft Northing: 6,013,799.25ft Latitude: 70° 26' 55.947 N +E / - 0.00 ft Easting: 518,370.74 ft Longitude: 149° 51' 0.470 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.10ft Welibore 3N- 16APB2 Magnetics - Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 5/20/2010 21.69 80.91 57,667 Design 3N- 16APB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,698.67 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) (ft) (°) 26.18 0.00 0.00 123.68 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 92.28 4,892.28 3N -16 (3N -16) GCT -MS Schlumberger GCT multishot 1/15/2001 t 4,932.00 5,552.23 3N- 16APB1 (Run 200) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/20/2010 1: 5,599.30 6,160.34 3N- 16APB1 (Run 300) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/22/2010 1: 6,211.30 7,325.02 3N- 16APB1 (Run 400) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/23/2010 1: 7,374.54 7,698.67 3N- 16APB1 (Run 500) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/25/2010 1: 7,733.79 7,763.61 3N- 16APB2 (Run 800) (3N- 16APB2) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 6/3/2010 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ W Northing Easting DLS Section (ft) ( °) (1 (o) (ft) (ft) (ft) (ft) (ft) (°H00') (ft) Survey Tool Name 26.18 0.00 0.00 26.18 -34.10 0.00 0.00 6,013,799.25 518,370.74 0.00 0.00 UNDEFINED 92.28 0.18 134.40 92.28 32.00 -0.07 0.07 6,013,799.18 518,370.81 0.27 0.10 GCT -MS (1) 192.28 0.35 111.97 192.28 132.00 -0.30 0.47 6,013,798.95 518,371.21 0.20 0.56 GCT -MS (1) 292.28 0.33 81.50 292.28 232.00 -0.37 1.04 6,013,798.88 518,371.78 0.18 1.07 GCT -MS (1) 392.28 0.52 72.62 392.27 331.99 -0.19 1.76 6,013,799.06 518,372.50 0.20 1.57 GCT -MS (1) 492.28 0.62 82.98 492.27 431.99 0.01 2.73 6,013,799.27 518,373.47 0.14 2.26 GCT -MS (1) 592.28 0.67 98.72 592.26 531.98 -0.01 3.84 6,013,799.25 518,374.58 0.18 3.20 GCT -MS (1) 692.28 1.28 107.73 692.25 631.97 -0.44 5.48 6,013,798.82 518,376.22 0.63 4.81 GCT -MS (1) 792.28 3.05 115.37 792.17 731.89 -1.92 8.95 6,013,797.35 518,379.69 1.79 8.51 GCT -MS (1) 892.28 6.55 118.63 891.81 831.53 -5.79 16.36 6,013,793.50 518,387.12 3.51 16.83 GCT -MS (1) 7/6/2010 12 :15:06PM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Welibore: 3N 16APB2 Survey Calculation Method: Minimum Curvature Design: 3N 16APB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/- -W Northing Easting DLS Section (ft) ( ° ) ( °) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 992.28 9.93 121.18 990.76 930.48 -12.99 28.75 6,013,786.33 518,399.52 3.40 31.13 GCT -MS (1) 1,092.28 12.95 125.87 1,088.76 1,028.48 -24.03 45.21 6,013,775.34 518,416.00 3.16 50.94 GCT -MS (1) 1,192.28 15.67 127.23 1,185.65 1,125.37 -38.76 65.05 6,013,760.65 518,435.88 2.74 75.63 GCT -MS (1) 1,292.28 17.57 125.33 1,281.47 1,221.19 -55.67 88.12 6,013,743.81 518,458.98 1.98 104.19 GCT -MS (1) 1,392.28 20.57 124.32 1,375.97 1,315.69 -74.30 114.94 6,013,725.24 518,485.86 3.02 136.86 GCT -MS (1) 1,492.28 22.42 121.12 1,469.02 1,408.74 -94.07 145.78 6,013,705.55 518,516.74 2.19 173.48 GCT -MS (1) 1,592.28 25.32 119.37 1,560.46 1,500.18 - 114.41 180.75 6,013,685.29 518,551.75 2.98 213.86 GCT -MS (1) 1,692.28 28.47 120.32 1,649.63 1,589.35 - 136.94 219.97 6,013,662.87 518,591.03 3.18 258.99 GCT -MS(1) 1,792.28 30.47 121.47 1,736.69 1,676.41 - 162.21 262.18 6,013,637.70 518,633.29 2.08 308.12 GCT -MS (1) 1,892.28 32.43 122.00 1,821.99 1,761.71 - 189.66 306.54 6,013,610.37 518,677.72 1.98 360.27 GCT -MS (1) 1,992.28 35.52 121.80 1,904.91 1,844.63 - 219.18 353.98 6,013,580.96 518,725.23 3.09 416.12 GCT -MS (1) 2,092.28 38.42 121.73 1,984.80 1,924.52 - 250.84 405.11 6,013,549.44 518,776.43 2.90 476.21 GCT -MS (1) 2,192.28 41.63 121.33 2,061.36 2,001.08 - 284.46 459.92 6,013,515.95 518,831.32 3.22 540.47 GCT -MS (1) 2,292.28 44.55 121.13 2,134.38 2,074.10 - 319.87 518.34 6,013,480.69 518,889.81 2.92 608.72 GCT -MS (1) 2,392.28 46.95 121.78 2,204.16 2,143.88 - 357.25 579.43 6,013,443.46 518,950.99 2.44 680.29 GCT -MS (1) 2,492.28 49.45 122.17 2,270.81 2,210.53 - 396.73 642.66 6,013,404.14 519,014.31 2.52 754.80 GCT -MS (1) 2,592.28 50.80 122.15 2,334.92 2,274.64 - 437.58 707.63 6,013,363.46 519,079.37 1.35 831.51 GCT -MS (1) 2,692.28 51.32 122.60 2,397.77 2,337.49 - 479.23 773.32 6,013,321.97 519,145.16 0.63 909.27 GCT -MS (1) 2,792.28 52.00 122.93 2,459.80 2,399.52 - 521.68 839.27 6,013,279.69 519,211.21 0.73 987.70 GCT -MS (1) 2,892.28 52.62 122.95 2,520.94 2,460.66 - 564.71 905.68 6,013,236.83 519,277.72 0.62 1,066.82 GCT -MS (1) 2,992.28 52.32 123.78 2,581.86 2,521.58 - 608.32 971.91 6,013,193.39 519,344.05 0.72 1,146.12 GCT -MS (1) 3,092.28 52.07 124.77 2,643.15 2,582.87 - 652.81 1,037.20 6,013,149.06 519,409.45 0.82 1,225.13 GCT -MS (1) 3,192.28 52.18 125.77 2,704.55 2,644.27 - 698.39 1,101.65 6,013,103.64 519,474.00 0.80 1,304.03 GCT -MS (1) 3,292.28 52.13 125.95 2,765.90 2,705.62 - 744.65 1,165.65 6,013,057.55 519,538.10 0.15 1,382.94 GCT -MS (1) 3,392.28 52.77 125.92 2,826.85 2,766.57 - 791.18 1,229.84 6,013,011.18 519,602.40 0.64 1,462.16 GCT -MS (1) 3,492.28 53.17 125.95 2,887.07 2,826.79 - 838.03 1,294.48 6,012,964.49 519,667.15 0.40 1,541.93 GCT -MS (1) 3,592.28 53.55 126.03 2,946.75 2,886.47 - 885.18 1,359.40 6,012,917.51 519,732.18 0.39 1,622.11 GCT -MS (1) 3,692.28 53.70 126.08 3,006.05 2,945.77 - 932.57 1,424.49 6,012,870.28 519,797.39 0.16 1,702.55 GCT -MS (1) 3,792.28 54.08 126.33 3,064.99 3,004.71 - 980.29 1,489.68 6,012,822.73 519,862.69 0.43 1,783.26 GCT -MS (1) 3,892.28 54.15 126.47 3,123.60 3,063.32 - 1,028.37 1,554.89 6,012,774.82 519,928.01 0.13 1,864.19 GCT -MS (1) 3,992.28 54.90 126.88 3,181.64 3,121.36 - 1,077.01 1,620.21 6,012,726.34 519,993.44 0.82 1,945.51 GCT -MS (1) 4,092.28 55.32 126.98 3,238.84 3,178.56 - 1,126.30 1,685.78 6,012,677.22 520,059.12 0.43 2,027.41 GCT -MS (1) 4,192.28 55.53 126.97 3,295.59 3,235.31 - 1,175.82 1,751.56 6,012,627.87 520,125.01 0.21 2,109.61 GCT -MS (1) 4,292.28 55.70 127.02 3,352.06 3,291.78 - 1,225.48 1,817.47 6,012,578.38 520,191.04 0.17 2,192.00 GCT -MS (1) 4,392.28 55.85 127.20 3,408.31 3,348.03 - 1,275.37 1,883.41 6,012,528.66 520,257.10 0.21 2,274.53 GCT -MS (1) 4,492.28 55.95 127.43 3,464.37 3,404.09 - 1,325.56 1,949.26 6,012,478.63 520,323.07 0.22 2,357.17 GCT -MS (1) 4,592.28 55.95 127.57 3,520.36 3,460.08 - 1,376.00 2,015.00 6,012,428.36 520,388.92 0.12 2,439.84 GCT -MS (1) 4,692.28 56.10 127.80 3,576.25 3,515.97 - 1,426.70 2,080.63 6,012,377.83 520,454.67 0.24 2,522.57 GCT -MS (1) 4,792.28 55.92 128.03 3,632.15 3,571.87 - 1,477.65 2,146.04 6,012,327.04 520,520.20 0.26 2,605.26 GCT -MS (1) 4,892.28 56.07 127.72 3,688.08 3,627.80 - 1,528.54 2,211.47 6,012,276.32 520,585.75 0.30 2,687.93 GCT -MS (1) 7/6/2010 12:15 :O6PM Page 3 COMPASS 2003.16 Build 69 • . ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project: Kuparuk River Unit TVD Reference: 3N -16A @ 60.28ft (016 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A @ 60.28ft (016 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N 16APB2 Survey Calculation Method: Minimum Curvature Design: 3N 16APB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +e-W Northing Easting DLS Section (ft) r) l °) (ft) (ft) (ft) (ft) (ft) (ft) rpm.) .) (ft) Survey Tool Name 4,932.00 54.78 128.91 3,710.62 3,650.34 - 1,548.81 2,237.14 6,012,256.11 520,611.46 4.08 2,720.53 MWD +IFR -AK- CAZ -SC (2) 4,997.55 55.33 130.96 3,748.17 3,687.89 - 1,583.31 2,278.33 6,012,221.72 520,652.74 2.70 2,773.93 MWD +IFR -AK- CAZ -SC (2) 5,088.27 51.15 133.94 3,802.46 3,742.18 - 1,632.30 2,331.97 6,012,172.86 520,706.49 5.31 2,845.74 MWD +IFR -AK- CAZ -SC (2) 5,171.54 47.32 137.01 3,856.82 3,796.54 - 1,677.21 2,376.21 6,012,128.06 520,750.84 5.38 2,907.46 MWD +IFR -AK- CAZ -SC (2) 5,212.51 48.47 141.46 3,884.30 3,824.02 - 1,700.23 2,396.04 6,012,105.10 520,770.73 8.53 2,936.73 MWD +IFR -AK- CAZ -SC (2) 5,259.02 49.47 143.39 3,914.83 3,854.55 - 1,728.04 2,417.43 6,012,077.35 520,792.18 3.80 2,969.95 MWD +IFR -AK- CAZ -SC (2) 5,326.24 48.61 140.38 3,958.90 3,898.62 - 1,767.97 2,448.75 6,012,037.49 520,823.60 3.62 3,018.16 MWD +IFR -AK- CAZ -SC (2) 5,367.18 47.82 140.46 3,986.18 3,925.90 - 1,791.50 2,468.20 6,012,014.01 520,843.10 1.94 3,047.39 MWD +IFR -AK- CAZ -SC (2) 5,414.42 46.82 136.94 4,018.21 3,957.93 - 1,817.59 2,491.11 6,011,987.99 520,866.07 5.87 3,080.92 MWD +IFR -AK- CAZ -SC (2) 5,458.57 46.29 136.32 4,048.57 3,988.29 - 1,840.89 2,513.12 6,011,964.74 520,888.14 1.57 3,112.16 MWD +IFR -AK- CAZ -SC (2) 5,502.54 46.28 137.09 4,078.96 4,018.68 - 1,864.02 2,534.91 6,011,941.67 520,909.99 1.27 3,143.12 MWD +IFR -AK- CAZ -SC (2) 5,552.23 45.25 136.54 4,113.62 4,053.34 - 1,889.98 2,559.27 6,011,915.77 520,934.41 2.22 3,177.79 MWD +IFR -AK- CAZ -SC (2) 5,599.30 43.09 136.61 4,147.38 4,087.10 - 1,913.80 2,581.82 6,011,892.01 520,957.01 4.59 3,209.76 MWD +IFR -AK- CAZ -SC (3) 5,647.80 39.25 136.65 4,183.89 4,123.61 - 1,937.00 2,603.74 6,011,868.86 520,978.99 7.92 3,240.87 MWD +IFR -AK- CAZ -SC (3) 5,695.29 37.44 135.90 4,221.13 4,160.85 - 1,958.30 2,624.10 6,011,847.62 520,999.40 3.94 3,269.62 MWD +IFR -AK- CAZ -SC (3) 5,739.56 35.39 134.73 4,256.76 4,196.48 - 1,976.99 2,642.57 6,011,828.98 521,017.92 4.89 3,295.36 MWD +IFR -AK- CAZ -SC (3) 5,791.77 32.87 134.43 4,299.97 4,239.69 - 1,997.55 2,663.44 6,011,808.47 521,038.83 4.84 3,324.12 MWD +IFR -AK- CAZ -SC (3) 5,833.94 30.72 135.11 4,335.81 4,275.53 - 2,013.19 2,679.21 6,011,792.87 521,054.64 5.17 3,345.92 MWD +IFR -AK- CAZ -SC (3) 5,886.27 27.92 136.72 4,381.43 4,321.15 - 2,031.58 2,697.05 6,011,774.52 521,072.52 5.56 3,370.96 MWD +IFR -AK- CAZ -SC (3) 5,924.69 25.53 136.85 4,415.75 4,355.47 - 2,044.17 2,708.88 6,011,761.96 521,084.38 6.22 3,387.79 MWD +IFR -AK- CAZ -SC (3) 5,979.93 22.73 136.38 4,466.15 4,405.87 - 2,060.59 2,724.38 6,011,745.59 521,099.92 5.08 3,409.80 MWD +IFR -AK- CAZ -SC (3) 6,017.21 21.21 136.05 4,500.73 4,440.45 - 2,070.66 2,734.03 6,011,735.54 521,109.60 4.09 3,423.41 MWD +IFR -AK- CAZ -SC (3) 6,066.17 20.51 135.29 4,546.48 4,486.20 - 2,083.13 2,746.22 6,011,723.10 521,121.81 1.53 3,440.46 MWD +IFR -AK- CAZ -SC (3) 6,114.30 18.22 136.41 4,591.88 4,531.60 - 2,094.57 2,757.34 6,011,711.69 521,132.96 4.82 3,456.06 MWD +IFR -AK- CAZ -SC (3) 6,160.34 15.12 135.91 4,635.98 4,575.70 - 2,104.10 2,766.48 6,011,702.18 521,142.12 6.74 3,468.96 MWD +IFR -AK- CAZ -SC (3) 6,211.30 12.01 134.20 4,685.51 4,625.23 - 2,112.57 2,774.91 6,011,693.73 521,150.57 6.15 3,480.67 MWD +IFR -AK- CAZ -SC (4) 6,302.68 8.51 130.65 4,775.42 4,715.14 - 2,123.61 2,786.86 6,011,682.73 521,162.54 3.89 3,496.73 MWD +IFR -AK- CAZ -SC (4) 6,392.29 7.74 125.48 4,864.13 4,803.85 - 2,131.43 2,796.80 6,011,674.93 521,172.51 1.18 3,509.34 MWD +IFR -AK- CAZ -SC (4) 6,484.36 8.23 129.56 4,955.31 4,895.03 - 2,139.23 2,806.93 6,011,667.16 521,182.65 0.81 3,522.10 MWD +IFR -AK- CAZ -SC (4) 6,579.18 7.75 130.94 5,049.21 4,988.93 - 2,147.74 2,816.99 6,011,658.67 521,192.74 0.55 3,535.19 MWD +IFR -AK- CAZ -SC (4) 6,671.68 8.01 128.26 5,140.83 5,080.55 - 2,155.82 2,826.76 6,011,650.62 521,202.53 0.49 3,547.80 MWD +IFR -AK- CAZ -SC (4) 6,765.40 7.69 126.63 5,233.67 5,173.39 - 2,163.60 2,836.92 6,011,642.86 521,212.70 0.42 3,560.57 MWD +IFR -AK- CAZ -SC (4) 6,856.78 7.99 127.80 5,324.20 5,263.92 - 2,171.14 2,846.85 6,011,635.35 521,222.65 0.37 3,573.01 MWD +IFR -AK- CAZ -SC (4) 6,952.80 8.53 124.65 5,419.22 5,358.94 - 2,179.28 2,857.98 6,011,627.24 521,233.80 0.73 3,586.79 MWD +IFR -AK- CAZ -SC (4) 7,044.11 8.25 123.78 5,509.56 5,449.28 - 2,186.77 2,868.99 6,011,619.77 521,244.83 0.34 3,600.11 MWD +IFR -AK- CAZ -SC (4) 7,141.75 7.86 126.68 5,606.23 5,545.95 - 2,194.66 2,880.17 6,011,611.92 521,256.03 0.58 3,613.78 MWD +IFR -AK- CAZ -SC (4) 7,232.44 8.84 123.03 5,695.96 5,635.68 - 2,202.16 2,890.99 6,011,604.44 521,266.86 1.23 3,626.94 MWD +IFR -AK- CAZ -SC (4) 7,325.02 12.69 117.17 5,786.90 5,726.62 - 2,210.68 2,906.00 6,011,595.96 521,281.89 4.32 3,644.17 MWD +IFR -AK- CAZ -SC (4) 7,374.54 14.30 117.11 5,835.05 5,774.77 - 2,215.95 2,916.29 6,011,590.71 521,292.19 3.25 3,655.65 MWD +IFR -AK- CAZ -SC (5) 7,417.43 16.35 111.95 5,876.41 5,816.13 - 2,220.62 2,926.60 6,011,586.07 521,302.52 5.74 3,666.82 MWD +IFR -AK- CAZ -SC (5) 7/6/2010 12:15:O6PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N -16 Protect Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Well: 3N -16 North Reference: True Wellbore: ° 3N- 16APB2 Survey Calculation Method: Minimum Curvature Design: 3N- 16APB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD 1VDSS +N/S +E/ -W Northing Easting DLS Section - (ft) r) _` (°) :; (ft) . (ft) (ft) (ft) (ft) (ft) (%1o0') (ft) Survey Tool Name 7,461.90 21.60 100.47 5,918.47 5,858.19 - 2,224.46 2,940.47 6,011,582.27 521,316.39 14.43 3,680.49 MWD +IFR -AK- CAZ -SC (5) 7,514.78 23.18 93.35 5,967.37 5,907.09 - 2,226.83 2,960.44 6,011,579.94 521,336.36 5.93 3,698.42 MWD +IFR -AK- CAZ -SC (5) 7,559.39 22.62 91.87 6,008.46 5,948.18 - 2,227.63 2,977.78 6,011,579.19 521,353.70 1.80 3,713.29 MWD +IFR -AK- CAZ -SC (5) 7,604.13 24.64 91.64 6,049.45 5,989.17 - 2,228.17 2,995.70 6,011,578.69 521,371.63 4.52 3,728.51 MWD +IFR -AK- CAZ -SC (5) 7,655.15 27.99 95.98 6,095.18 6,034.90 - 2,229.73 3,018.25 6,011,577.19 521,394.17 7.57 3,748.13 MWD +IFR -AK- CAZ -SC (5) 7,698.67 30.34 97.38 6,133.18 6,072.90 - 2,232.20 3,039.31 6,011,574.77 521,415.24 5.62 3,767.03 MWD +IFR -AK- CAZ -SC (5) 1 7,733.79 30.89 105.82 6,163.42 6,103.14 - 2,235.80 3,056.79 6,011,571.21 521,432.72 12.33 3,783.57 MWD +IFR -AK- CAZ -SC (6) 7,763.61 30.05 112.38 6,189.13 6,128.85 - 2,240.73 3,071.06 6,011,566.32 521,447.01 11.50 3,798.18 MWD +IFR -AK- CAZ -SC (6) 7,833.00 30.05 112.38 6,249.19 6,188.91 - 2,253.96 3,103.19 6,011,553.17 521,479.17 0.00 3,832.26 PROJECTED to TD 7/6/2010 12:15:06PM Page 5 COMPASS 2003.16 Build 69 • • I�• ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N- 16APB3 500292159372 Sperry Drilling Services Definitive Survey Report 06 July, 2010 • • { i s : F 4 E HALUBURTON Sperry Drilling Services II • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project: Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N 16APB3 Survey Calculation Method: Minimum Curvature Design: 3N- 16APB3 Database: CPAI EDM Production 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 3N - 16 Well Position +NI-S 0.00 ft Northing: 6,013,799.25ft Latitude: 70° 26' 55.947 N +E/ -W 0.00 ft Easting: 518,370.74 ft Longitude: 149° 51' 0.470 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.10ft Wellbore 3N 16APB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2009 6/4/2010 21.67 80.91 57,669 Design 3N 16APB3 Audit Notes: 1 Version: 1.0 Phase: ACTUAL Tie On Depth: 5,171.54 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) - - _ (ft) - ( - - - - 26.18 0.00 0.00 121.99 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 92.28 4,892.28 3N -16 (3N -16) GCT -MS Schlumberger GCT multishot 1/15/2001 t 4,932.00 5,171.54 3N- 16APB1 (Run 200) (3N- 16APB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/20/2010 1: 5,195.00 8,180.00 3N -16A (3N- 16APB3) MWD +IFR- AK- CAZ -SC MWD+IFR AK CAZ SCC 6/8/2010 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +V -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (°/700') (ft) Survey Tool Name 26.18 0.00 0.00 26.18 -34.10 0.00 0.00 6,013,799.25 518,370.74 0.00 0.00 UNDEFINED 92.28 0.18 134.40 92.28 32.00 -0.07 0.07 6,013,799.18 518,370.81 0.27 0.10 GCT -MS (1) 192.28 0.35 111.97 192.28 132.00 -0.30 0.47 6,013,798.95 518,371.21 0.20 0.56 GCT -MS (1) 292.28 0.33 81.50 292.28 232.00 -0.37 1.04 6,013,798.88 518,371.78 0.18 1.08 GCT -MS (1) 392.28 0.52 72.62 392.27 331.99 -0.19 1.76 6,013,799.06 518,372.50 020 1.59 GCT -MS (1) 492.28 0.62 82.98 492.27 431.99 0.01 2.73 6,013,799.27 518,373.47 0.14 2.31 GCT -MS (1) 1 592.28 0.67 98.72 592.26 531.98 -0.01 3.84 6,013,799.25 518,374.58 0.18 3.26 GCT -MS (1) 692.28 1.28 107.73 692.25 631.97 -0.44 5.48 6,013,798.82 518,376.22 0.63 4.88 GCT -MS (1) 792.28 3.05 115.37 792.17 731.89 -1.92 8.95 6,013,797.35 518,379.69 1.79 8.61 GCT -MS (1) 892.28 6.55 118.63 891.81 831.53 -5.79 16.36 6,013,793.50 518,387.12 3.51 16.95 GCT -MS (1) 992.28 9.93 121.18 990.76 930.48 -12.99 28.75 6,013,786.33 518,399.52 3.40 31.27 GCT -MS (1) 1,092.28 12.95 125.87 1,088.76 1,028.48 -24.03 45.21 6,013,775.34 518,416.00 3.16 51.07 GCT -MS (1) 7/6/2010 10:03:38AM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N - 16 Project Kuparuk River Unit TVD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A @ 60.28ft (D16 (34.1+ 26.18)) Well: 3N - 16 North Reference: True Wellbore: 3N 16APB3 Survey Calculation Method: Minimum Curvature Design: 3N 16APB3 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (1 (f) (ft) (ft)`. (ft) (ft) (ft) ( *MOO') (ft) Surrey Tool Name 1,192.28 15.67 127.23 1,185.65 1,125.37 -38.76 65.05 6,013,760.65 518,435.88 2.74 75.70 GCT -MS (1) 1,292.28 17.57 125.33 1,281.47 1,221.19 -55.67 88.12 6,013,743.81 518,458.98 1.98 104.22 GCT -MS (1) 1,392.28 20.57 124.32 1,375.97 1,315.69 -74.30 114.94 6,013,725.24 518,485.86 3.02 136.85 GCT -MS (1) 1,492.28 22.42 121.12 1,469.02 1,408.74 -94.07 145.78 6,013,705.55 518,516.74 2.19 173.48 GCT -MS (1) 1,592.28 25.32 119.37 1,560.46 1,500.18 - 114.41 180.75 6,013,685.29 518,551.75 2.98 213.92 GCT -MS(1) 1,692.28 28.47 120.32 1,649.63 1,589.35 - 136.94 219.97 6,013,662.87 518,591.03 3.18 259.11 GCT -MS(1) 1,792.28 30.47 121.47 1,736.69 1,676.41 - 162.21 262.18 6,013,637.70 518,633.29 2.08 308.30 GCT -MS (1) 1,892.28 32.43 122.00 1,821.99 1,761.71 - 189.66 306.54 6,013,610.37 518,677.72 1.98 360.47 GCT -MS (1) 1,992.28 35.52 121.80 1,904.91 1,844.63 - 219.18 353.98 6,013,580.96 518,725.23 3.09 416.34 GCT -MS (1) 2,092.28 38.42 121.73 1,984.80 1,924.52 - 250.84 405.11 6,013,549.44 518,776.43 2.90 476.48 GCT -MS (1) 2,192.28 41.63 121.33 2,061.36 2,001.08 - 284.46 459.92 6,013,515.95 518,831.32 3.22 540.78 GCT -MS (1) 2,292.28 44.55 121.13 2,134.38 2,074.10 - 319.87 518.34 6,013,480.69 518,889.81 2.92 609.08 GCT -MS (1) 2,392.28 46.95 121.78 2,204.16 2,143.88 - 357.25 579.43 6,013,443.46 518,950.99 2.44 680.70 GCT -MS (1) 2,492.28 49.45 122.17 2,270.81 2,210.53 - 396.73 642.66 6,013,404.14 519,014.31 2.52 755.24 GCT -MS (1) 2,592.28 50.80 122.15 2,334.92 2,274.64 - 437.58 707.63 6,013,363.46 519,079.37 1.35 831.98 GCT -MS (1) 2,692.28 51.32 122.60 2,397.77 2,337.49 - 479.23 773.32 6,013,321.97 519,145.16 0.63 909.76 GCT -MS (1) 2,792.28 52.00 122.93 2,459.80 2,399.52 - 521.68 839.27 6,013,279.69 519,211.21 0.73 988.19 GCT -MS (1) 2,892.28 52.62 122.95 2,520.94 2,460.66 - 564.71 905.68 6,013,236.83 519,277.72 0.62 1,067.31 GCT -MS (1) 2,992.28 52.32 123.78 2,581.86 2,521.58 - 608.32 971.91 6,013,193.39 519,344.05 0.72 1,146.59 GCT -MS (1) 3,092.28 52.07 124.77 2,643.15 2,582.87 - 652.81 1,037.20 6,013,149.06 519,409.45 0.82 1,225.54 GCT -MS (1) 3,192.28 52.18 125.77 2,704.55 2,644.27 - 698.39 1,101.65 6,013,103.64 519,474.00 0.80 1,304.34 GCT -MS (1) 3,292.28 52.13 125.95 2,765.90 2,705.62 - 744.65 1,165.65 6,013,057.55 519,538.10 0.15 1,383.13 GCT -MS (1) 3,392.28 52.77 125.92 2,826.85 2,766.57 - 791.18 1,229.84 6,013,011.18 519,602.40 0.64 1,462.22 GCT -MS (1) 3,492.28 53.17 125.95 2,887.07 2,826.79 - 838.03 1,294.48 6,012,964.49 519,667.15 0.40 1,541.86 GCT -MS (1) 3,592.28 53.55 126.03 2,946.75 2,886.47 - 885.18 1,359.40 6,012,917.51 519,732.18 0.39 1,621.91 GCT -MS (1) 3,692.28 53.70 126.08 3,006.05 2,945.77 - 932.57 1,424.49 6,012,870.28 519,797.39 0.16 1,702.22 GCT -MS (1) 3,792.28 54.08 126.33 3,064.99 3,004.71 - 980.29 1,489.68 6,012,822.73 519,862.69 0.43 1,782.79 GCT -MS(1) 3,892.28 54.15 126.47 3,123.60 3,063.32 - 1,028.37 1,554.89 6,012,774.82 519,928.01 0.13 1,863.57 GCT -MS (1) 3,992.28 54.90 126.88 3,181.64 3,121.36 - 1,077.01 1,620.21 6,012,726.34 519,993.44 0.82 1,944.73 GCT -MS (1) 4,092.28 55.32 126.98 3,238.84 3,178.56 - 1,126.30 1,685.78 6,012,677.22 520,059.12 0.43 2,026.45 GCT -MS (1) 4,192.28 55.53 126.97 3,295.59 3,235.31 - 1,175.82 1,751.56 6,012,627.87 520,125.01 0.21 2,108.48 GCT -MS (1) 4,292.28 55.70 127.02 3,352.06 3,291.78 - 1,225.48 1,817.47 6,012,578.38 520,191.04 0.17 2,190.69 GCT -MS (1) 4,392.28 55.85 127.20 3,408.31 3,348.03 - 1,275.37 1,883.41 6,012,528.66 520,257.10 0.21 2,273.05 GCT -MS (1) 4,492.28 55.95 127.43 3,464.37 3,404.09 - 1,325.56 1,949.26 6,012,478.63 520,323.07 0.22 2,355.50 GCT -MS (1) 4,592.28 55.95 127.57 3,520.36 3,460.08 - 1,376.00 2,015.00 6,012,428.36 520,388.92 0.12 2,437.97 GCT -MS (1) 4,692.28 56.10 127.80 3,576.25 3,515.97 - 1,426.70 2,080.63 6,012,377.83 520,454.67 0.24 2,520.49 GCT -MS (1) 4,792.28 55.92 128.03 3,632.15 3,571.87 - 1,477.65 2,146.04 6,012,327.04 520,520.20 0.26 2,602.96 GCT -MS (1) 4,892.28 56.07 127.72 3,688.08 3,627.80 - 1,528.54 2,211.47 6,012,276.32 520,585.75 0.30 2,685.42 GCT -MS (1) 4,932.00 54.78 128.91 3,710.62 3,650.34 - 1,548.81 2,237.14 6,012,256.11 520,611.46 4.08 2,717.92 MWD +IFR- AK- CAZ -SC (2) 4,997.55 55.33 130.96 3,748.17 3,687.89 - 1,583.31 2,278.33 6,012,221.72 520,652.74 2.70 2,771.13 MWD +IFR- AK- CAZ -SC (2) 7/6/2010 10 :03:38AM Page 3 COMPASS 2003.16 Build 69 • ConocoPhilli p s (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N -16 Project Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N -16 North Reference: True Weiibore: 3N- 16APB3 Survey Calculation Method: Minimum Curvature Design: 3N- 16APB3 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! WD TVDSS +NJ-S +FJ-W Northing Easting DLS Section (ti) (°) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ("1100 (ft) Survey Tool Nance 5,088.27 51.15 133.94 3,802.46 3,742.18 - 1,632.30 2,331.97 6,012,172.86 520,706.49 5.31 2,842.59 MWD +IFR -AK- CAZ -SC (2) 5,171.54 47.32 137.01 3,856.82 3,796.54 - 1,677.21 2,376.21 6,012,128.06 520,750.84 5.38 2,903.90 MWD +IFR -AK- CAZ -SC (2) 5,195.00 46.93 134.70 3,872.79 3,812.51 - 1,689.55 2,388.18 6,012,115.76 520,762.84 7.40 2,920.59 MWD +IFR -AK- CAZ -SC (3) 5,253.70 45.60 128.80 3,913.39 3,853.11 - 1,717.79 2,419.78 6,012,087.60 520,794.51 7.61 2,962.35 MWD +IFR -AK- CAZ -SC (3) 5,315.27 45.68 122.48 3,956.46 3,896.18 - 1,743.41 2,455.52 6,012,062.07 520,830.31 7.34 3,006.24 MWD +IFR -AK- CAZ -SC (3) 5,361.49 45.36 126.04 3,988.85 3,928.57 - 1,761.97 2,482.77 6,012,043.58 520,857.60 5.54 3,039.18 MWD +IFR -AK- CAZ -SC (3) 5,410.83 44.92 125.41 4,023.65 3,963.37 - 1,782.39 2,511.16 6,012,023.24 520,886.04 1.27 3,074.08 MWD +IFR -AK- CAZ -SC (3) 5,451.10 44.49 124.25 4,052.27 3,991.99 - 1,798.57 2,534.41 6,012,007.11 520,909.33 2.29 3,102.37 MWD +IFR -AK- CAZ -SC (3) 5,502.52 40.59 128.34 4,090.16 4,029.88 - 1,819.10 2,562.44 6,011,986.66 520,937.40 9.29 3,137.02 MWD +IFR -AK- CAZ -SC (3) 5,550.72 39.12 134.56 4,127.17 4,066.89 - 1,839.50 2,585.59 6,011,966.31 520,960.60 8.81 3,167.46 MWD +IFR -AK- CAZ -SC (3) 5,598.23 39.33 139.62 4,163.99 4,103.71 - 1,861.49 2,606.03 6,011,944.37 520,981.09 6.75 3,196.44 MWD +IFR -AK- CAZ -SC (3) 5,643.79 37.07 136.85 4,199.79 4,139.51 - 1,882.51 2,624.77 6,011,923.40 520,999.88 6.22 3,223.48 MWD +IFR -AK- CAZ -SC (3) 5,687.36 34.59 132.68 4,235.12 4,174.84 - 1,900.48 2,642.85 6,011,905.48 521,018.01 7.98 3,248.33 MWD +IFR -AK- CAZ -SC (3) 5,732.62 34.60 128.75 4,272.38 4,212.10 - 1,917.24 2,662.32 6,011,888.77 521,037.51 4.93 3,273.72 MWD +IFR -AK- CAZ -SC (3) 5,784.54 31.68 126.53 4,315.85 4,255.57 - 1,934.58 2,684.78 6,011,871.48 521,060.01 6.09 3,301.96 MWD +IFR -AK- CAZ -SC (3) 5,822.75 30.62 123.90 4,348.55 4,288.27 - 1,945.98 2,700.92 6,011,860.12 521,076.18 4.51 3,321.69 MWD +IFR -AK- CAZ -SC (3) 5,877.67 29.35 122.34 4,396.12 4,335.84 - 1,960.99 2,723.90 6,011,845.18 521,099.19 2.71 3,349.12 MWD +IFR -AK- CAZ -SC (3) 5,916.63 26.78 121.61 4,430.50 4,370.22 - 1,970.70 2,739.45 6,011,835.51 521,114.76 6.66 3,367.45 MWD +IFR -AK- CAZ -SC (3) 5,967.33 24.24 123.94 4,476.25 4,415.97 - 1,982.49 2,757.81 6,011,823.76 521,133.15 5.39 3,389.28 MWD +IFR -AK- CAZ -SC (3) 6,020.39 22.67 124.96 4,524.93 4,464.65 - 1,994.44 2,775.23 6,011,811.86 521,150.60 3.06 3,410.38 MWD +IFR -AK- CAZ -SC (3) 6,062.03 20.51 127.22 4,563.65 4,503.37 - 2,003.45 2,787.62 6,011,802.88 521,163.01 5.56 3,425.66 MWD +IFR -AK- CAZ -SC (3) 6,110.48 18.34 125.72 4,609.34 4,549.06 - 2,013.03 2,800.56 6,011,793.33 521,175.98 4.60 3,441.72 MWD +IFR -AK- CAZ -SC (3) 6,157.10 16.45 123.48 4,653.82 4,593.54 - 2,020.96 2,812.03 6,011,785.43 521,187.46 4.30 3,455.64 MWD +IFR -AK- CAZ -SC (3) 6,200.27 14.45 120.43 4,695.43 4,635.15 - 2,027.06 2,821.77 6,011,779.35 521,197.22 5.00 3,467.13 MWD +IFR -AK- CAZ -SC (3) 6,250.77 13.20 120.37 4,744.47 4,684.19 - 2,033.16 2,832.18 6,011,773.27 521,207.64 2.48 3,479.20 MWD +IFR -AK- CAZ -SC (3) 6,295.61 11.18 123.80 4,788.29 4,728.01 - 2,038.17 2,840.21 6,011,768.29 521,215.68 4.78 3,488.66 MWD +IFR -AK- CAZ -SC (3) 6,340.74 9.90 131.56 4,832.66 4,772.38 - 2,043.18 2,846.75 6,011,763.30 521,222.23 4.23 3,496.86 MWD +IFR -AK- CAZ -SC (3) 6,432.45 9.69 130.52 4,923.04 4,862.76 - 2,053.42 2,858.51 6,011,753.08 521,234.02 0.30 3,512.27 MWD +IFR -AK- CAZ -SC (3) 6,527.86 9.74 130.45 5,017.08 4,956.80 - 2,063.88 2,870.76 6,011,742.66 521,246.29 0.05 3,528.19 MWD +IFR -AK- CAZ -SC (3) 6,624.06 9.57 131.37 5,111.92 5,051.64 - 2,074.44 2,882.95 6,011,732.13 521,258.51 0.24 3,544.13 MWD +IFR -AK- CAZ -SC (3) 6,713.58 8.44 125.72 5,200.33 5,140.05 - 2,083.20 2,893.87 6,011,723.40 521,269.45 1.60 3,558.03 MWD +IFR -AK- CAZ -SC (3) 6,808.06 8.27 127.51 5,293.81 5,233.53 - 2,091.38 2,904.89 6,011,715.24 521,280.49 0.33 3,571.71 MWD +IFR -AK- CAZ -SC (3) 6,901.54 8.14 128.27 5,386.33 5,326.05 - 2,099.57 2,915.42 6,011,707.08 521,291.04 0.18 3,584.98 MWD +IFR -AK- CAZ -SC (3) 6,995.13 8.21 128.58 5,478.97 5,418.69 - 2,107.85 2,925.85 6,011,698.83 521,301.48 0.09 3,598.20 MWD +IFR -AK- CAZ -SC (3) 7,086.66 6.89 121.92 5,569.71 5,509.43 - 2,114.82 2,935.62 6,011,691.88 521,311.27 1.73 3,610.19 MWD +IFR -AK- CAZ -SC (3) 7,184.16 6.83 122.41 5,666.51 5,606.23 - 2,121.02 2,945.47 6,011,685.70 521,321.14 0.09 3,621.83 MWD +IFR -AK- CAZ -SC (3) 7,277.13 11.27 118.74 5,758.30 5,698.02 - 2,128.36 2,958.11 6,011,678.40 521,333.79 4.81 3,636.44 MWD +IFR -AK- CAZ -SC (3) 7,370.41 11.91 115.97 5,849.68 5,789.40 - 2,136.96 2,974.76 6,011,669.84 521,350.46 0.91 3,655.11 MWD +IFR -AK- CAZ -SC (3) 7,417.96 14.91 113.29 5,895.93 5,835.65 - 2,141.53 2,984.79 6,011,665.30 521,360.50 6.44 3,666.04 MWD +IFR -AK- CAZ -SC (3) 7,464.30 18.45 109.11 5,940.31 5,880.03 - 2,146.28 2,997.20 6,011,660.57 521,372.92 8.06 3,679.09 MWD +IFR -AK- CAZ -SC (3) 7/6/2010 10 :03 :38AM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 3N-16 Project ' Kuparuk River Unit TVD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Site: Kuparuk 3N Pad MD Reference: 3N -16A © 60.28ft (D16 (34.1+ 26.18)) Well: 3N -16 North Reference: True Wellbore: 3N- 16APB3 Survey Calculation Method: Minimum Curvature Design: 3N- 16APB3 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az' TVD TVDSS +W-S +E/ -W Northing Eastlng DLS Section (ft) C) (°) (ft) on (ft) (ft) (ft) (ft) moo') (ft) Survey. Tool Nam 7,510.82 19.77 108.27 5,984.27 5,923.99 - 2,151.16 3,011.63 6,011,655.73 521,387.36 2.90 3,693.91 MWD +IFR -AK- CAZ -SC (3) 7,555.80 21.53 108.64 6,026.36 5,966.08 - 2,156.18 3,026.67 6,011,650.75 521,402.42 3.92 3,709.33 MWD +IFR -AK- CAZ -SC (3) 7,603.57 24.58 112.90 6,070.31 6,010.03 - 2,162.85 3,044.14 6,011,644.12 521,419.89 7.27 3,727.67 MWD +IFR -AK- CAZ -SC (3) 7,647.61 28.69 114.23 6,109.67 6,049.39 - 2,170.76 3,062.22 6,011,636.26 521,438.00 9.43 3,747.20 MWD +IFR -AK- CAZ -SC (3) 7,700.85 31.43 115.55 6,155.74 6,095.46 - 2,181.99 3,086.40 6,011,625.09 521,462.20 5.29 3,773.66 MWD +IFR -AK- CAZ -SC (3) . 7,742.56 35.44 113.53 6,190.54 6,130.26 - 2,191.52 3,107.31 6,011,615.62 521,483.13 9.98 3,796.44 MWD +IFR -AK- CAZ -SC (3) 7,790.34 39.37 111.51 6,228.49 6,168.21 - 2,202.61 3,134.12 6,011,604.59 521,509.97 8.62 3,825.05 MWD +IFR -AK- CAZ -SC (3) 7,835.33 42.32 107.52 6,262.53 6,202.25 - 2,212.40 3,161.85 6,011,594.87 521,537.72 8.75 3,853.76 MWD +IFR -AK- CAZ -SC (3) 7,888.62 45.40 103.79 6,300.95 6,240.67 - 2,222.33 3,197.40 6,011,585.03 521,573.29 7.54 3,889.17 MWD +IFR -AK- CAZ -SC (3) 7,927.55 47.97 102.66 6,327.66 6,267.38 - 2,228.80 3,224.97 6,011,578.62 521,600.87 6.93 3,915.98 MWD +IFR -AK- CAZ -SC (3) 7,976.74 51.16 100.73 6,359.56 6,299.28 - 2,236.38 3,261.63 6,011,571.14 521,637.55 7.14 3,951.09 MWD +IFR -AK- CAZ -SC (3) 8,025.18 54.60 97.88 6,388.79 6,328.51 - 2,242.60 3,299.74 6,011,565.01 521,675.66 8.51 3,986.70 MWD +IFR -AK- CAZ -SC (3) 8,068.76 56.94 95.03 6,413.31 6,353.03 - 2,246.64 3,335.53 6,011,561.07 521,711.47 7.62 4,019.20 MWD +IFR -AK- CAZ -SC (3) 8,104.55 58.55 91.48 6,432.41 6,372.13 - 2,248.35 3,365.74 6,011,559.43 521,741.68 9.52 4,045.73 MWD +IFR -AK- CAZ -SC (3) 8,180.00 58.55 91.48 6,471.78 6,411.50 - 2,250.01 3,430.09 6,011,557.93 521,806.02 0.00 4,101.19 MWD +IFR -AK- CAZ -SC (3) 7/6/2010 10 :03 :38AM Page 5 COMPASS 2003.16 Build 69 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 29, 2010 8:22 AM To: 'Greener, Mike R.' Cc: Lowry, Scott L; Maunder, Thomas E (DOA) Subject: RE: 3N -16A liner cementing pro 210 Mike, Per 20 AAC 25.030 (6) & (7) the intermediate liner doesn't need to be completely cemented but the liner lap interval must be pressure competent . Provided the liner top packer tests you are good to go. This liner lap will not be subjected to the injection pressure as the seal bore will be above it and see only IA annulus pressure. A CBL is needed to verify the cement quality and determine TOC. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Greener, Mike R. [mailto: Mike .R.Greener @conocophillips.com] Sent: Tuesday, June 29, 2010 8:05 AM To: Greener, Mike R.; Schwartz, Guy L (DOA) Cc: Lowry, Scott L Subject: RE: 3N -16A liner cementing Correction to information below. Expected TOC is 650' below the TOL NOT the window. Mike Greener From: Greener, Mike R. Sent: Tuesday, June 29, 2010 6:44 AM To: Schwartz, Guy L (DOA) Cc: Lowry, Scott L Subject: 3N -16A liner cementing Ran 3-1/2" liner to TD at 8,190' MD / 6,478' TVD. Cemented liner with 119 bbls of 15.8 ppg cement. Proceeded cement with 40 bbl chemwash and then 40 bbl mudpush. Cement excess at 35 %. 6/29/2010 Page 2 of 2 Bump plug with no issues. Bled off and floats held. Release from hanger. Circulate hole clean and recover 40 bbls of chemwash and 20 -25 bbls of mudpush then 10 ppg mud but no cement. Liner lap is 209' inside 7" casing which is 5 bbls. Expect TOC should be about 650' below 7" window. FIT on window was 12 ppg. We have not set the liner top packer. Currently we are laying down some of our 4" DP. Do we need to squeeze the liner top considering how close the estimated TOC is to the liner top? I will call to follow up. Mike Greener 6/29/2010 • Page 1 of 2 Schwartz, Guy L (DOA) From: Greener, Mike R. [ Mike .R.Greener ©conocophillips.com] Z /o -oYq Sent: Tuesday, June 22, 2010 9:01 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: 3N -16A status at 15:00 hrs 6/21/2010 Attachments: Greener Mike.vcf; 3N -16A Rig Surveys (NAD 83).xls; welibore with ST.jpg Wellplan is now #13. Attached is the new wellplan. The plug backs are in the file also. Cartoon attached showing the different sidetracks. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, June 22, 2010 7:35 AM To: Maunder, Thomas E (DOA); Greener, Mike R.; Schwartz, Guy L (DOA) Subject: RE: 3N -16A status at 15:00 hrs 6/21/2010 Mike, Following up on your plan to mill a new window (I pasted in your earlier message). Is the BHL target still the same? We probably need to talk about all the correct naming of all the plug backs. I should be in all morning. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, June 21, 2010 7:42 PM To: Greener, Mike R.; Schwartz, Guy L (DOA) Subject: RE: 3N -16A status at 15:00 hrs 6/21/2010 Mike, Sorry, I was out of the office today. The answer to your original question, did you need to tag the first plug is NO provided it goes into place without issues. It would appear since you have proceeded on that you were successfully able to place both plugs. As I remember our discussion last week, the Kuparuk had not been penetrated which mitigates the need to tag. Good luck with this tar baby. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto: Mike .R.Greener @conocophillips.com] Sent: Mon 6/21/2010 3 :22 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Subject: 3N -16A status at 15:00 hrs 6/21/2010 We have placed the two 500' plugs into the well with the bottom of the first plug at 7,600'. We are now POOH to PU a cement retainer which will be set at 4,900' in the 7" casing. We will squeeze with 50 bbls of 16.8 ppg cement. 6/28/2010 • • Page 2 of 2 My cell # is 350 -3238 Mike Greener From: Greener, Mike R. [mailto:Mike.R.Greener @conocophillips.com] Sent: Monday, June 21, 2010 9:06 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: Status of 3N -16A as of 6/21/10 We attempted to get to bottom on ST #3 and we stuck our drillstring at +/- 7,700' . The HRZ appears to be running shale on us. We got the drillstring free and after consulting with the north slope AOGCC rep we proceeded to PU a 2 -7/8" stinger to place two cement plugs in ST #3. During the run in of the 980' stinger on our 4" DP we stuck it at +/- 7,800'. We stopped running in the hole as soon as we tagged up and the stinger stuck and packed off. After working it for a period we were able to establish circulation and we got the stinger free. We are currently placing the first cement plug at +/- 7,600'. It is sized to be a 500' plug with 50% excess. Do we have to tag this first plug before placing the second one on top of it? We are also going to place a retainer above the window in the 7" casing and squeeze the window. Plan forward is to mill a new window above the retainer and drill ST #4. Mike Greener 6/28/2010 • i 3N -16A Plan as of 6/16/2010 ( ' D 216 og(R Events to date Drilled original sidetrack ( #1) from the 7" casing to 8,260' MD / 6,417' TVD. During the running of the 5 -1/2" liner we were unable to get pass 7,740' MD. We pulled out of the hole and picked up our BHA and during the clean up of the wellbore we inadvertently sidetracked at 7,682' MD ( #2). We attempted to continue this new sidetrack ( #2) but our BHA directional tools malfunctioned and the wellbore was drilled in the wrong direction to a depth 7,756' MD. After review it was determined to be able to keep drilling in the new ST ( #2) we would have to obtain doglegs greater than 10 degrees to reach our objective. We then placed a cement plug in the well which failed to set up and which required a second plug to be placed. We were unable to get a solid KOP on the second plug and the decision was made to do an openhole ST ( #3) at 5,195' in the original ST ( #1). The new ST ( #3) was drilled to a depth of 8,180' MD / 6,465' TVD. The 5 -1/2" liner was run with a 4 -1/2" shoe (to assist entering the new ST ( #3)). The liner was run to 7,528' MD where it became stuck. We have backed off from the liner hanger and are currently at the surface preparing to run a inclinometer to verify which ST we have the liner in. We will then RIH and jar on the liner in an attempt to free it. Late night 6/16/2010 we will POOH and run a gyro to do a backup verification on the liner placement. . • • PLAN FORWARD as of 6/16/2010 If the liner is in ST #1 (the old hole) 1. We will place a CIBP in the liner at +/- 5,350' MD. Wireline is acceptable. 2. Run in hole with a jet cutter on wireline and cut the liner at +/- 5,325'. 3. RIH and retrieve liner. 4. PU reamer with bullnose and motor and RIH to clean out to TD in ST #3. TD depth is 8,180' MD. 5. POOH and run 3 -1/2" liner and cement same. Liner shoe needs to be less than 35' in length to stay in the "B" shale. 6. Cement needs to come to the liner top. If we do not circulate any cement off of the liner top then the liner top needs to be squeezed. If the liner is in ST #3 (the new hole) 1. We will place a CIBP in the liner at +/- 5,350' MD. Wireline is acceptable. 2. Run in hole with a jet cutter on wireline and cut the liner at +/- 5,325'. 3. RIH and retrieve liner. 4. PU cement retainer and RIH to 4,900' and set same in 7" casing. Squeeze ST and window with yet to be determined amount of cement. 5. POOH and PU whipstock and RIH. 6. Cut new window using yet to be determined new directional plan. Plan is dependent upon whipstock set depth. 7. Drill new ST #4 to planned TD. 8. Run and cement 3 -1/2" liner. Liner shoe needs to be less than 35' in length to stay in the `B" shale. 9. Cement needs to come to the liner top. If we do not circulate any cement off of the liner top then the liner top needs to be squeezed. 1 • • • PT() Ziv -c1(9 7" casing Whipstock ©4,950' 7,682' ST #3 8,180' ST #1 ST #2 . 7,756' 8,260' 2 /6- 7" casing • 0 Surface sho @ 4,797' tVhipst ck O n tap of=etairier • Retainer set @ 4,900' ST #4 Whipstock ' :`':.. @ 950' ::::: ::::^�:: ..::::.. ::::: :_:.:.:.:.:C;iiB,it:pt CIBP r�i :.:.. 5,360' i -lf „ liner : :::::::::::: ::::': ::;: ::: ::::: :. , : : : : : ::' :::::::�:. : : : :: 8,197 MD 6,4 ?S' TVD 7,682' 8,180' 7,756' 8,260' ST #1 Page 1 of 3 • • Schwartz, Guy L (DOA) F L From: Greener, Mike R. [ Mike .R.Greener@conocophillips.com] Sent: Tuesday, June 08, 2010 3:15 PM To: Schwartz, Guy L (DOA) Cc: Lowry, Scott L; Chambers, Mark A; Alvord, Chip Subject: Up date on 3N -16A, attached is directional Attachments: Greener Mike.vcf An update on what has been happening on the 3N -16A. 1. The sidetrack was drilled to a depth of 8,260'. 2. The liner was run and it failed to go pass the depth of 7,740'. It would go no further. 3. POOH and PU bit and RIH. 4. The BHA ended up sidetracking the well at a depth of 7,756'. All attempts to get back into the old hole failed. 5. Attempted to ST old well at depth of 7,756'. - 6. Due to BHA / MWD failure we drilled in the wrong direction and corrections to the directional path would result in dogleg severities that would prohibit getting the liner to bottom (doglegs >10 degrees). 7. Decision was made to POOH and PU 2 -7/8" cementing stinger. 8. Tried to get into old hole with 2 -7/8" stinger (bent) with no success. 9. Spotted 15# gel pill at 7,833' and then PU 100' above gel pill. 10. Placed a 26 bbl 16.5 ppg Class "G" cement pill and then pulled up to 7,300'. I I 11. Pumped second 26 bbl cement plug of 16.5 ppg Class "G" cement 6/8/2010 Page 2 of 3 • 1 and then pulled up to 6,367'. 12. Circulate hole clean and POOH. 13. After 15 hours TIH to find cement top. 14. Encountered cement stringers to a firm cement top at 7,690'. TOC too deep to be effective. 15. Placed two more cement plugs in well using 17 ppg neat cement with the 2 -7/8" stinger (900'). 16. Plug #1 was 36 bbls and placed from 7,690' to 7,186'. Circulate at 7,186' and recover some cement in returns. 17. Place 2 plug (36 bbls) from 7,186' to 6,245'. Circulate at 6,245' and recover some cement in returns. 18. RIH after 18 hours looking for cement top. 19. Wash down to 7,300' without finding cement top. POOH to window in 7" casing and WOC in case cement contamination has extended set time of cement. • Current operations at 15:00 hours on 6/8/2010. Circulating waiting on cement to set up. Expect to attempt to find TOC at 21:00 on 6/8/2010. If we do not find TOC, we will POOH to +/- 5,200' and attempt to sidetrack from that point. If we do find TOC, we will ST at that point as long as it is above 7,461' where a severe dogleg is located (>14 degrees) Mike Greener 6/8/2010 • STIMIE DIF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -16A ConocoPhillips Alaska, Inc. Permit No: 210 -049 Surface Location: 1561' FSL, 30' FEL, Sec. 29, T13N, R9E, UM Bottomhole Location: 4585' FSL, 3343' FWL, Sec. 33, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2! day of April, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) ConocIIIips APR 1 5 2010 Post Office Box 100360 Al2S8GC1SC Anchorage, Alaska 99510 -0360 AnChOratl Randy Thomas Phone (907) 265 -6830 Fax: (907) 265 -1535 Email: randy.l.thomas @conocophillips.com April 9, 2010 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Injector 3N -16A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Injection well, KRU 3N -16A. It is planned to abandon the original wellbore and then set a CIPB at +/- 4,930' MD and place a permanent whipstock on top of the CIBP with the whipstock at +/- 4,920' MD. We will then cut and mill a window in the existing 7" production casing with a planned TD of +/- 8,140' MD / 6,494' TVD. . The existing 7" casing cement job from the original wellbore did not bring the top of cement up as high as the window. The current plan is to mill the window and perform a FIT test/ LOT, which ever comes first, with a required minimum of 11.5 ppg EMW. ** If the FIT/LOT is too low, a squeeze cement job will be performed on the window and a second FIT/LOT will be performed after drill out. After a successful FIT/LOT test the intermediate section will be drilled with a 6" bit x 7 -1/2" reamer down through the Kuparuk C sand and stop at the TD depth of 8,140' MD / 6,494' TVD (above the A sand). After running the tubing completion, the drilling rig will move off, the coiled tubing rig will move on and this wellbore will • then be used as a setup for coiled tubing sidetracking of the "A" sand. The spud date is expected to be May 15 2010. • If you have any questions or require any further information, please contact Mike Greener at 263 -4820. Sincerely, Chip Alvord GKA Drilling Team Leader RECEIVED • STATE OF ALASKA • APR 010 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 PERMIT TO DRILL Alaska Oil & Gas Cons. Comm ission 20 AAC 25.005 Anchorage la. Type of Work: lb. Proposed Well Class: Development - Oil ❑ Service - Winj El , 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 U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 3N - 16A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 8140' " TVD: 6494' • Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Surface: 1561' FSL, 30' FEL, Sec. 29, T13N, R9E, UM ' ADL 25521 ' Kuparuk River Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4585' FSL, 3254' FWL, Sec. 33, T13N, R9E, UM 2557, 2556 5/15/2010 Total Depth: 9. Acres in Property: 14. Distance to 4585' FSL, 3343' FWL, Sec. 33, T13N, R9E, UM 2560 Nearest Property: > 1 mile 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 50 feet 15. Distance to Nearest Well Open Surface: x - 518371 • y - 6013799 • Zone 4 GL Elevation above MSL: . 34 feet to Same Pool: 3N -16 , 1347' . 16. Deviated wells: Kickoff depth: 4900 + ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25 035) Maximum Hole Angle: 57 d Downhole: 1111 psig • Surface: 446 psig • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 7.5" 5.5" 15.5# L - 80 ST - L 4720' 4720' 3600' 8140' 6494' 250 sx Class G 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) 9235 6851 9102' 6745' Casing Length Size Cement Volume MD TVD Conductor /Structural 115' 16" 249 sx CS II 115' 115' Surface 4797' 9.625" 1350 sx AS III, 350 sx Class G 4797' 3638' Intermediate Production 9189' 7" 300 sx Class G, 175 sx AS I 9189' 6815' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 8776- 8799', 8896- 8914', 8920' -8956' 6488'- 6505', 6582'- 6596', 6601' -6617' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program i_..- s 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date: / / p 22. I hereby certify that the foregoing is true and correct. Contact Mike Gre�,jpjf 263 - 4820 Printed Name G. Alvord // Title Alaska Drilling Manager � % V' / Signature �e .,„, CL` r p 14 Lvo Phon 265 -63o6 Date c f it( (1 d J Commission Use Only Permit to Drill API Number: Permit Appr val See cover letter (C� ) Number: f 3 '"6� : � 9 b I for other requirements (�..� 50- n.25-- � 1 � �,_'C��- L- Date. 'b q � ements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalb d m ane, gas hydrates, or gas contained in shales: .3500 (S &P 5 I f S amples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [r Other: 2.5406 eSL A nr+ri.e . ---F3 �hw.� 1 2S measures: Yes [+r No ❑ Directional svy req'd: Yes 0 No ❑ el 4/ ,,l 7/0 APPROVED BY THE COMMISSION 0 DAT 1 COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 Mpiithl f tieldple. royal (20 AAC 25.005(g)) Submit in Duplicate 1 120VO ...A il-- � r 6 [r /`r ie. • • Application for Permit to DrillRevision , Well 3N -16A No.O Saved: 14- Apr -10 Permit It — Kuparuk Well 3N -16A Application for Permit to Drill Document " T e Mpximiz8 Well VQI i Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005 (c)(5) 3 6. Casing and Cementing Program 3 Requirements of 20 AAC 25.005(c)(6) 3 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 9. Abnormally Pressured Formation Information 4 Requirements of 20 AAC 25.005 (c)(9) 4 10. Seismic Analysis 4 Requirements of 20 AAC 25.005 (c)(10) 4 11. Seabed Condition Analysis 4 Requirements of 20 AAC 25.005 (c)(11) 4 12. Evidence of Bonding 5 Requirements of 20 AAC 25.005 (c)(12) 5 13. Proposed Drilling Program 5 Requirements of 20 AAC 25.005 (c)(13) 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 t 1 A L (not done) 3N -16A PERMIT IT. DOC Page 1 of 6 • • Application for Permit to Drill, Well 3N -16A Revision No.O Saved: 14- Apr -10 Requirements of 20 AAC 25.005 (c)(14) 7 15. Attachments 7 Attachment 1 Directional Plan .............................................................. ............................... 6 Attachment Well Schemaics ............................................................... ..............................6 1. Well Name Requirements of 20 AAC 25.005 0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 A.1C 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3N -16A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (2) a plat identi6 the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at the top ()leach objective formation and at total depth: Location at Surface 1,560.75' FSL, 5,250.16' FWL, Sec 29, T13N, RO9E, UM • NGS Coordinates RKB Elevation 50' AMSL Northings: 6,013,799 Eastings: 518,371 Pad Elevation 34.1' AMSL Location at Top of 4,585.4' FSL, 3,253.82' FWL, Sec 33, T13N, RO9E, UM Productive Interval (Kuparuk C Sand) NGS Coordinates Measured Depth, RKB: 8,013' Northings: 6,011,553 Eastings: 521,666 Total Vertical Depth, RKB: 6,405' Total Vertical Depth, SS: 6,345' Location at Total Depth 4,585' FSL, 3,343' FWL, Sec 33, T13N, RO9E, UM NGS Coordinates Measured Depth, RKB: 8,140' Northings: 6,011,553 Eastings: 521,755 Total Vertical Depth, RKB: 6,494' . Total Vertical Depth, SS: 6,435' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Forum 10 -401) must (1) include a plat, drawn to a suitable scale. showing the path of the proposed wellbore, inch,dang all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to time extent that those names are known or discoverable in public records. and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. R 1GINAL (not done) 3N -16A PERMIT IT.DOC Page 2 of 6 • Application for Permit to Drill, R Well evision 3N -16A No.O Saved: 14- Apr -10 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 16. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may he encountered criteria used to determine it, and maxinmm potential surface pressure based on a methane gradient: BHP data on offset injectors indicates that the current reservoir pressure for 3N -16A is < 1,111 psi at 6,301' TVDSS (6,375' TVD), 0.18 psi/ft or 3.4 ppg EMW. • The maximum potential surface pressure (MPSP) while drilling 3N -16A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 6,375' TVD: MPSP = (6,375 ft) *(0.18 - 0.11 psi/ft) = 446 psi (B) data on potential gas zones: The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata. lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of'the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030; A procedure is on file with the commission for performing LOT's. For 3N -16A the procedure will be followed after milling the window, with one exception. The formation at the window depth will be pressured until leak -off occurs or to 16.0 ppg EMW is reached, which ever comes first. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already onn file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD /TVD MD /TVD OD (in) (in) (lb /ft) Grade Conn. (ft) (ft) (ft) Cement Program Original Wellbore 3N -16 9 -5/8" 12 -1/4 36 J -55 BTC 4,797' surface 4,797' / 3,638' 7" 8 -1/2 26 J -55 BTC 9,189' surface 9,189' / 6,815' 2 -7/8" 6.5 J -55 EUE 8,854' surface 8,854' / 6,548' Tubing 3N -16A Sidetrack Plan 7" window 8 -1/2" 26 J -55 BTC 4,920' surface 4,920' / 3,702' 5.5" flush jt 7 -1/2" 15.5 L -80 ST -L 4,720' 4,720' / 3,600' 8,140'/ 6,494' ' 250 sx 15.8 Class G, 1.16 ft /sk I `,! i L (not done) 3N -16A PERMIT IT.DOC Page 3 of 6 • Application for Permit to Drill, Well 3N -16A Revision No.O Saved: 14- Apr -10 7. Diverter System Information Requirements of 20 AAC 25.005(c) (7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the conm,ission and identified in the application: (7) a diagram and description of the diverter system as required by 20.44C 25.035, unless this requirement is waived by the commission under 20 A.4C 25.035(h)(2); This rotary sidetrack will exit pre - existing casing at + 4,900' MD. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c) (8) An application for a Permit to Drill must he accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drillingfluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done using a LSND mud systems having the following properties: Sidetrack Hole mud properties Initial Drillout KOP TD Depth MD/ TVD 4,920' MD 8,140' MD / 6,494' TVD Density (ppg) 9.0 9.0 Funnel Viscosity (seconds) 45 — 55 45 — 55 Yield Point (cP) 15 - 20 15 — 20 Plastic Viscostiy (lb /100 st) 12 - 18 12 — 18 pH 9.5 -10.5 9.5 -10.5 API Filtrate(cc) <6 <6 Diagram of Doyon 16 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033f: N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or refection analysis as required by 20 AAC 25.061(a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items. except for an items already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure. jack -up rig. or floating drilling vessel, an analysis of seabed conditions as required by 20 A.4C 25.061(b): N/A - Application is not for an offshore well. 1,) ke I U 1 N PA L (not done) 3N -16A PERMIT IT.DOC Page 4 of 6 • Application for Permit to Drill, Well 3N -16A Revision No.O Saved: 14- Apr -10 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding/ have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. . 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Pre -Rig Well Work: NOTE: test IA +1- 2 weeks prior to rig moving — Wells Group will supervise and permit the work below. Slickline Pre - Cement Squeeze work: 1. Tagged PBTD at 8953' SLM (1' RH). 2. Set CA -2 Plug & gauges in D Nipple at 8841' RKB for A Sand SBHP. 3. Set Catcher Sub on top of CA -2 Plug at 8841' RKB. 4. Obtain C sand SBHP dunk at 8800' RKB. 5. Pull CV's at St#11 at 8811', St #10 at 8739', and St #9 at 8671' RKB. Set DV's in all 3 of these stations for CMIT. 6. Perform an MIT on the tubing to 2500 psi. 7. Pull OV from St# 8 at 8579' RKB. Leave pocket open for CMIT. 8. Perform CMIT to 2500 psi. 9. Pull Catcher Sub from top of CA -2 Plug at 8841' RKB. 10. Pull CA -2 Plug & gauges from D Nipple at 8841' RKB. Download data. 11. Pull DV's from St #11 at 8811', St #10 at 8739', and St#9 at 8671' RKB. Leave all 3 pockets open for cement squeeze of the selective. St # 8 at 8579' RKB should remain open pocket (see step `f above) to enable cement circulation to IA when spotting cement on top of the packer inside the IA (step 3 below). Coiled Tubing 1. RU CTU & PT equipment. Notify AOGCC Inspector of date and time of operation. 2. RIH with Weatherford cement retainer stinger assembly with centralizers to ensure coil has a straight shot at the retainer. Stab onto retainer at +/- 8656' RKB, and shift slide valve open. Pump slick SW at 1 - 2 bpm to establish injection rate and pressure. 3. Pump cement into formation until target squeeze pressure of 1000 psi is reached. Total 7" production casing and 2- 7/8" tubing volume below cement retainer is —5 bbls. Attempt to squeeze at least 6 bbls of cement into the formation, if possible. 4. Pull out of retainer, open CT x tubing annulus and pump 7.2 bbls of cement into the tubing while taking 1:1 returns. Park coil at 8400' RKB and assist cement U- tubing by pumping cement from tubing to the IA through open pocket at 8579' RKB (GLM #8). Take 5.8 bbls of returns from the IA then shut -in the IA. Note, max estimated TOC in the 2- 7/8" tubing should no cement enter the IA is 7412' RKB. Rig -ST KOP is —4900' RKB. 5. A 7.2 bbl cement volume will leave —220' of cement plug on top of the cement retainer in the tubing and —200' of cement on top of the packer inside the IA. Estimated TOC in the IA and the tubing after U -tube of cement will be —8436' RKB. 6. After 5.8 bbls of returns have been taken from the IA, and the IA has been shut -in with the CT at 8400' RKB, swap to pumping Biozan and POOH with CT circulating out contaminated cement. FP the upper 2500' of tubing with 15 bbls Diesel. RD CTU. R1G1NAL (not done) 3N -16A PERMIT /T.DOC Page 5 of 6 d Application for Permit to Drill, Well 3N -16A Revision No.O Saved: 14- Apr -10 Slickline Post - Cement Squeeze 1. WOC 24 hours. RIH & drift tubing to PBTD (TOC) with 2.28" gauge. PT cement plug to 1500 psi on the tubing and hold for 30 minutes. Record test results. Notify AOGCC of the timing of the post- cement plug tag and PT. 2. Perform drawdown test by bleeding any tubing, IA and OA pressure to open -top tank. Tubing and IA should bleed to 0 psi.. E -line Tubing Cut 1. RIH with a tubing perforator and shoot a 2' interval (4 spf; 8 holes) in the tubing at 8258 - 8260' RKB in preparation for tubing cut. This will locate the tubing perfs just below the middle of the first full joint below GLM #7 at 8236' RKB. 2. RIH with an RCT with anchor arms for 2 -7/8" tubing and cut the tubing at +/- 8252' RKB. This puts the cut at the middle of the first full joint below GLM #7 at 8236' RKB, and —6' above the tubing perforations. This cut location is well below the planned sidetrack KOP of +/- 4920' RKB. POOH with E -line. Pump slick seawater down the tubing while noting rates and pressures to verify likelihood of a successful cut. RD. 3. Set BPV & VR plug. Pull the well house and prep site for rig. NOTE: Drilling Group will supervise and permit the work below. Current Wellhead: FMC Gen III, 11 "x 3K, 7- 1/16" x 3K Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Doyon 16. Install blanking plug on top of the back pressure valve. 2. NU and test the 11 "x 5K BOPE to 250# / 3500 #. 3. Engage the 3 -1/2" tubing with a spear. L/D the tubing hanger and POOH with the 3 -1/2" tubing. 4. Set storm packer. 5. N/D BOP's. Remove FMC Gen III tubing head and replace it with a 11 "x 3M x 11 "x 5M spool. - 6. NU Bop's to the 11 ", 5000 psi flange on the FMC Gen III system & test 250 psi & 3500 psi. - 7. PU mill, casing scraper, and 4" DP and RIH to top of tubing stub. Circulate clean and POOH. • 8. RU wireline set a CIBP inside the 7" casing at +/- 4,930' MD based on casing collar depth. (Note: CIBP must be >_ 2.0' above a casing collar and >_ 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 2500 psi and hold for 15 min. Test okay. (If not contact Engineer- discuss will have to get packer and RIH and attempt to find hole in casing.) 9. PU and RIH with Baker's "WindowMaster" whipstock system & window mill, bottom trip anchor, MWD, and �� UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP. 1 10. Orient whipstock 45 degrees left of low side, shear off, and POOH. 11. Displace 8.8 ppg Brine from hole with 9.0 ppg LSND mud to mill window. Mill window and drill 20' new formation. Dress window. Pump super sweep pill. \/ 12. Perform FIT/LOT. (Note: if the FIT/LOT does not reach the minimum 11.5 ppg required the window will be 4 " 5 y . \ squeezed, drilled out, and a new FIT/LOT will be performed) 13. POOH and LD window mill etc. 1:2 a t 4 (not done) 3N - 16A PERMIT IT.DOC Page 6 of 6 • Application for Permit to Drill, Well 3N -16A Revision No.O Saved: 14- Apr -10 14. PU motor, near bit Rhino Reamer, 6 -1/8" bit & BHA, 4.0" DP, and RIH. 15. Drill to TD (8,140' MD / 6,494' TVD). MW expected to be 9.0 ppg. 16. PU 5.5" flush joint liner and RIH. Liner over lap into 7" casing needs to be +/- 200'. 17. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. Cement the liner bringing cement to +/- 6,625' MD100' above the liner top. '7 18. Release from liner. Set packer. 19. Displace the well above the TOL with seawater until the returns are clean. Check for flow. POOH. LD /DP. 20. Set storm packer and change out the 11 "x3 by 7- 1/16" x 5M spool and then re -run the tbg head. 21. R/U and RIH with the 3 -1/2" tubing tag the TOL. Space out and land. RILDs. Test tubing, PBR and liner to 2500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 2500 psi. Bleed off all pressures. 22. Install a TWC. ND BOPE. NU and test the 3 -1/8" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to + 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid. Install a BPV. R/D and M /O. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori.ation under 20 AAC 25.080 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments : Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary ?R !GINAL (not done) 3N -16A PERMIT IT.DOC Page 7 of 6 ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3N Pad CSI Plan: 3N -16A (wp07) 1/4 Mile Pool Scan Sperry Drilling Services March 31, 2010 • HALLIBURTON Sperry Drilling Closest in POOL Closest Approach: Reference Well: 3N -16A (wp07) Plan Offset Well: 3N -16 3 -D ctr-ctr Hoi 3e.7112I 0nbsoa Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. DHtanre DifferPnoe Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (121.99 °) Comments Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (121.99 °) Comments POOL Min Distance POOL Min Distance (1347.26 ft) in POOL (1347.26 ft) in POOL (6400 - 6435.24 (6400 - 6435.24 • TVDss) to 3N -16 TVDss) to 3N -16A (6500 - 6791.22 (wp07) Plan (6500 - I 1347.26 t 1H 0.84 61.816440 8140.02 45.00 90.00 6435.24 6011304.88 1661787.38 4060.56 TVDss) 8875.00 37.35 115.79 6497.06 6010679.17 1662978.92 5402.87 6791.22 TVDss) Closest Approach: Reference Well: 3N -16A (wp07) Plan Offset Well: 3N -19 3 -D ctr -ctr '- lori.r:nm4 Sub .% Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. . Difterr:nce Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (121.99 °) Comments Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (121.99 °) Comments POOL Min Distance POOL Min Distance (1373.75 ft) in POOL (1373.75 ft) in POOL (6400 - 6435.24 (6400 - 6435.24 TVDss) to 3N -19 (- TVDss) to 3N -16A • • 6375 - 6411.04 (wp07) Plan ( -6375 - 1373.75 1373.71 -1' 05 8097.85 45.00 89.99 6405.42 6011304.81 1661757.56 4035.27 TVDss) 8699.41 85.71 124.29 6394.34 6010170.76 1660982.31 3889.86 6411.04 TVDss) Closest Approach: Reference Well: 3N -16A (wp07) Plan Offset Well: 3N -14A 3 -D ctr-ctr Hon750:,24 Sub553 Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. :7■:st :c Difrcron,:e Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)NV( -) (121.99 °) Comments Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (121.99 °) Comments ., �«d POOL Min Distance POOL Min Distance (1435.17 ft) in POOL (1435.17 ft) in POOL -qi,) (6400 - 6435.24 (6400 - 6435.24 TVDss) to 3N -14A TVDss) to 3N -16A (6303 - 6584.79 (wp07) Plan (6303 - 1435.17 - 1423.92 179.30501 8097.85 45.00 89.99 6405.42 6011304.81 1661757.56 4035.27 TVDss) 8220.00 32.83 102.67 6584.79 6012690.08 1661428.08 3024.40 6584.79 TVDss) 1 ill POOL Summary.xls 3/31/2010 3:06 PM NEM HALLIBURTON Project: Kuparuk River Unit wE1LnETAn s: 3N-16 Ir,s Site: Kuparuk 3N Pad Ground Level: 34.10 Well: 3N -16 +N / -S -tE/-W Northing Easting Latittude Longitude Slot 9 5/8" x 12 1/4" Welbore: Plan: 3N -16A 0.00 0.00 6013550.99 1658402.43 70° 26'54.896N 149 51' 11.761 W - Plan: 3N- 16A(wp07) 0— REFERENCE INFORMATION Co-ordinate (N /E) Reference: Well 3N -16, True North - Vertical (TVD) Reference: PIan:3N -16A Q 59.60ft (D16 (34.1 +25.5)) - Measured Depth Reference: PIan:3N -16A Q 59.60ft (016 (34.1 +25.5)) _ Y� Calculation Method: Minimum Curvature 9 5/8" -467— CASINGDEI'AILS = TVD TVDSS MD Size Name -700— 3629.79 3570.19 4788.60 9-5/8 95, " ¢. 3695.52 3635.92 4906.12 7 7" TOW _ ° 6494.60 6435.00 8140.02 3-1/2 512x312" z -933 - -1167— 1400 — • _ s.. 9 5/8" -1633- 7 " TOW -1867 — w 14: :::: : * °o � -2100 - 3N- 16A(wp07) .....•••••0 - 2333 — - 2567 — ,>\'' 5 1/2 x 3 1/2" =(O = a. -2800 tl�7 — 7" • = ...:-.;or e -3033— M -3267— �" -3500- 5 1/2' 3N 16AKupA51 /4Mile -3733— 3967— T M Azimuths to True North `,,, - Magnetic North: 21.72 - 4200 — Magnetic Field - Strength: 57665.2snT - Dip Angle: 80.91° 4433 — Date: 4/25/2010 - Model: BGGM2009 i "> 1 -4667-: 11 1 1111 111 11 1 1111 1 1111 1111 1 1111' 11111 1 1111 1 1111 1111 1 111I1I 1111 111 11 11111 1 1111 1 111 IIII I II 1111 II 111 1 1111 II 111 1 1111 III 11 III 11 11111 11111 11111 1 11111111 -933 -700 -467 -233 0 233 467 700 933 1167 1400 1633 1867 2100 2333 2567 2800 3033 3267 3500 3733 3967 4200 4433 4667 4900 5113 5367 5600 West(-)/East( +) (700 ft/in) lo- COt10C0P'tllllPS Alaska \P Project: Kuparuk River Unit �� " ConocoPhillips Site: Kuparuk 3N Pad 3N -16 a " � .:" (01 3''''20 Wellbore: PIan:3N -16A a HALLIBURTON Plan: 3N -16A (wp07) (3N-16/Plan: 3N-16A) tadius u 0 Plot Sperry Drilling c nnnd Level 34.10 RK6: Plan :3N-16A @ 59.601[ (D16 (30.1 +25.5)) Northing /ASP Y: 6013550.99 Fasting /ASP X: 1656402,43 1000 2000 95/8"x121/4"'.: 3000 • 95/8" 000 9 5/8" 7 "TOW 5000 6000 - -4. • ; .;' ; • 7" "° 1000 51/2" 51/2x31/2" 8000 i •` i i',..: ' ° 3N -14A ` -. 1 000 . -19 I 7" ': 2000 3000 3N -16: 3N -16A (wpO7) • ' 4-000 • • 5000 • • • • ° `" 6000 1 0 0 0 C=D o o °° Q 0 0 C=I 0 0 0 \ 7 Z • 1 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N -16 Plan: 3N -16A Plan: 3N -16A (wp07) Standard Proposal Report 30 March, 2010 HALLIBURTON Sperry Drifting Services I 1\1 I \ L . . HAL Project: Kuparuk River Unit WELL DETAILS: 3N -16 Site: Kuparuk 3N Pad Ground Level: 34.10 , Well: 3N -16 +N / -S +E/ -W Northing Easting Latittude Longitude Slot Sperry Drilling Wellbore: Plan: 3N -16A 0.00 0.00 6013799.25 518370 .7470° 26' 55.947 N 149° 51' 0.470 W Plan: 3N -16A (wpO7) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well 3N -16, True North Vertical (TVD) Reference: PIan:3N -16A @ 59.805 (016 (34.1 +25.5)) ' Measured Depth Reference: PIan:3N -16A @ 59.8Oft (016 (34.1 +25.5)) Calculation Method: Minimum Curvature 2750- - CASING DETAILS + Tie - on @ MD, 3696' TVD: 25 FSL, 21ST FWL Sec28,TI3N, 09E 3000 _ klir TVD TVDSS MD Size Name .■ ■ 3629.79 3570.19 4788.60 9 -5/8 9 5/8" 3250 - -- I 3695.52 3635.92 840.12 2 7" TOW 6494.58 6434.98 81140.02 3 -1/2 5 1/2 x 3 1/2" 3500 - --- I - I 1 ! ■1 • U•• 1 9 s 3750 _ . - /8 ". - a. °'° -- -- - -- -- 4000 - -- - -- - - - -- 7" TONS � ° i DDI = 5.894 4250 - 4500 _ — I II JI I 1 II F - - - - - 1 - — 0 4750 --- ' • I _ - -- - - -- - -- _-I X000 - ■ ■• 5250 — 1 I j5500 , et ■ \ — —L 2. 5750 _ l t .r — - - 6000 — ' / f.oLeGeA 0° TD Intermediate @ 8140' MD, 6495' TVD: 695' FNL, 193 ' 1 6250 — _ - -- - -- -- - -- -- 'K E 3N-16 N- 16 Ah}: 3. A -- � �: = � G �4 ,- ^ � e Q e _ o - _ _ _ . .. � - - - - — - : - 6500 _ . a _ _ k - = s - ._ •. 1 6750 p 51/2x31/2' 6 1 Kup A3 .;_ . 7000 4 — 1 _^,-- - — Kelp A ■ 7250 - - - kxpAl ■ — I I iiiirillill 11 1111 1111 'Hi 1111 1111 1111 1111 1111 1111 1111 1111 1111 MI mil IIII IIII 1111 1111 1111 1111 IIIIIIill 1111 1111 1111 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750 Vertical Section at 121.99° (1000 ft/in) -1000 0 1Lli Tie -on @ 4906' MD, 3696' TVD 25' FSL, 2187' FWL - Sec28T13N'r" -- i -1250 i It -- 11 - t �� .. EN 1-4 .. : is ■' `' - -1500 - - - - 9 - s /s• ^ } . 1 , iI(i( 1 7 " TOW ° -1750 0 - j • O � : I I ' , TD Intermediate @ 8140 MD, 6495' TVD: 695' FNL, 1937 FEL + -2000 - _ _ C ' I t o 1 _ -2250 1 __ -- _ / / , ,_16A 1wp1199 `, stnx3v2' ' a 1 -2500 -- - l - - -._ .-_ - 1 3N -16A KupA5 (wp0' "g -- , _ 1 I M Azl uths to rue North __ - " M. No h: 17.18° ' DD Poly 95/ co 1 t f 1 2750 �_ . _ 1 - r = S rength 5 3 ■ ® t Dip An. e: 79.87° Date: •/25/2010 25/2010 -3000 •., =i 1 u - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 West( - )/East( +) (650 ft/in) ConotoPhillips Attska ORIGINAL • • Halliburton HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 3N -16 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) • Project: Kuparuk River Unit MD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Site: Kuparuk 3N Pad North Reference: True Well: 3N -16 Survey Calculation Method: Minimum Curvature Welibore: PIan: 3N-16A Design: 3N -16A (wp07) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3N Pad Site Position: Northing: 6,013,799.17ft Latitude: 70° 26' 55.957 N From: Map Easting: 517,946.19ft Longitude: 149° 51' 12.938 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.14 ° Weil 3N -16 Well Position +NI -S 0.00 ft Northing: 6,013,799.25 ft Latitude: 70° 26' 55.947 N +E / -W 0.00 ft Easting: 518,370.74 ft Longitude: 149° 51' 0.470 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.10ft Welibore PIan: 3N-16A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) ( °) (nT) I BGGM2009 4/25/2010 17.18 79.87 57,383 Design 3N -16A (wp07) Audit Notes: Version: Phase: PLAN Tie On Depth: 4,906.10 Vertical Section: Depth From (TVD) +WS +E/-W Direction (ft) (ft) (ft) (°) 25.50 0.00 0.00 121.99 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/ -W Rate Rate Rate Tool Face (ft) ( °) (°) (ft) ft (ft) (ft) ( ° /100ft) ( ° /100ft) ( °/100ft) (°) 4,906.10 55.93 127.65 3,695.51 3,635.91 - 1,535.89 2,220.99 0.00 0.00 0.00 0.00 4,918.10 57.29 129.25 3,702.11 3,642.51 - 1,542.12 2,228.83 15.90 11.33 13.36 45.00 4,938.10 57.29 129.25 3,712.92 3,653.32 - 1,552.77 2,241.86 0.00 0.00 0.00 0.00 5,038.10 57.29 132.25 3,766.96 3,707.36 - 1,607.68 2,305.60 2.52 0.00 3.00 90.00 5,986.85 14.59 131.89 4,517.46 4,457.86 - 1,972.89 2,708.85 4.50 -4.50 -0.04 - 179.87 7,257.34 14.59 131.89 5,746.97 5,687.37 - 2,186.61 2,947.14 0.00 0.00 0.00 0.00 8,040.06 45.00 90.00 6,423.89 6,364.29 - 2,254.60 3,308.74 4.50 3.88 -5.35 -54.94 8,140.06 45.00 90.00 6,494.60 6,435.00 - 2,254.60 3,379.45 0.00 0.00 0.00 0.00 3/30/2010 1:31:31PM Page 2 COMPASS 2003.16 Build 69 ; '''' : ) / le"\ I tt 1 t' i 0 • Halliburton HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 3N -16 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Project: Kuparuk River Unit MD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Site: Kuparuk 3N Pad North Reference: True Well: 3N -16 Survey Calculation Method: Minimum Curvature Welibore: PIan: 3N-16A Design: 3N -16A (wp07) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) ( °) (ft) ft (ft) (ft) (ft) (ft) (1100ft) 25.50 0.00 0.00 25.50 -34.10 0.00 0.00 6,013,799.25 518,370.74 0.00 0.00 91.60 0.18 134.40 91.60 32.00 -0.07 0.07 6,013,799.18 518,370.81 0.27 0.10 191.60 0.35 111.97 191.60 132.00 -0.30 0.47 6,013,798.95 518,371.21 0.20 0.56 291.60 0.33 81.50 291.60 232.00 -0.37 1.04 6,013,798.88 518,371.78 0.18 1.08 391.60 0.52 72.62 391.59 331.99 -0.19 1.76 6,013,799.06 518,372.50 0.20 1.59 491.60 0.62 82.98 491.59 431.99 0.01 2.73 6,013,799.27 518,373.47 0.14 2.31 591.60 0.67 98.72 591.58 531.98 -0.01 3.84 6,013,799.25 518,374.58 0.18 3.26 691.60 1.28 107.73 691.57 631.97 -0.44 5.48 6,013,798.82 518,376.22 0.63 4.88 791.60 3.05 115.37 791.49 731.89 -1.92 8.95 6,013,797.35 518,379.69 1.79 8.61 891.60 6.55 118.63 891.13 831.53 -5.79 16.36 6,013,793.50 518,387.12 3.51 16.95 991.60 9.93 121.18 990.08 930.48 -12.99 28.75 6,013,786.33 518,399.52 3.40 31.27 1,091.60 12.95 125.87 1,088.08 1,028.48 -24.03 45.21 6,013,775.34 518,416.00 3.16 51.07 I 1,191.60 15.67 127.23 1,184.97 1,125.37 -38.76 65.05 6,013,760.65 518,435.88 2.74 75.70 1,291.60 17.57 125.33 1,280.79 1,221.19 -55.67 88.12 6,013,743.81 518,458.98 1.98 104.22 1,391.60 20.57 124.32 1,375.29 1,315.69 -74.30 114.94 6,013,725.24 518,485.86 3.02 136.85 1,491.60 22.42 121.12 1,468.34 1,408.74 -94.07 145.78 6,013,705.55 518,516.74 2.19 173.48 1,591.60 25.32 119.37 1,559.78 1,500.18 - 114.41 180.75 6,013,685.29 518,551.75 2.98 213.92 1,691.60 28.47 120.32 1,648.95 1,589.35 - 136.94 219.97 6,013,662.87 518,591.03 3.18 259.11 1,791.60 30.47 121.47 1,736.01 1,676.41 - 162.21 262.18 6,013,637.70 518,633.29 2.08 308.30 1,891.60 32.43 122.00 1,821.31 1,761.71 - 189.66 306.54 6,013,610.37 518,677.72 1.98 360.47 1,991.60 35.52 121.80 1,904.23 1,844.63 - 219.18 353.98 6,013,580.96 518,725.23 3.09 416.34 2,091.60 38.42 121.73 1,984.12 1,924.52 - 250.84 405.11 6,013,549.44 518,776.43 2.90 476.48 2,191.60 41.63 121.33 2,060.68 2,001.08 - 284.46 459.92 6,013,515.95 518,831.32 3.22 540.78 2,291.60 44.55 121.13 2,133.70 2,074.10 - 319.87 518.34 6,013,480.69 518,889.81 2.92 609.08 2,391.60 46.95 121.78 2,203.48 2,143.88 - 357.25 579.43 6,013,443.46 518,950.99 2.44 680.70 2,491.60 49.45 122.17 2,270.13 2,210.53 - 396.73 642.66 6,013,404.14 519,014.31 2.52 755.24 2,591.60 50.80 122.15 2,334.24 2,274.64 - 437.58 707.63 6,013,363.46 519,079.37 1.35 831.98 2,691.60 51.32 122.60 2,397.09 2,337.49 - 479.23 773.32 6,013,321.97 519,145.16 0.63 909.76 2,791.60 52.00 122.93 2,459.12 2,399.52 - 521.68 839.27 6,013,279.69 519,211.21 0.73 988.19 2,891.60 52.62 122.95 2,520.26 2,460.66 - 564.71 905.68 6,013,236.83 519,277.72 0.62 1,067.31 2,991.60 52.32 123.78 2,581.18 2,521.58 - 608.32 971.91 6,013,193.39 519,344.05 0.72 1,146.59 3,091.60 52.07 124.77 2,642.47 2,582.87 - 652.81 1,037.20 6,013,149.06 519,409.45 0.82 1,225.54 3,191.60 52.18 125.77 2,703.87 2,644.27 - 698.39 1,101.65 6,013,103.64 519,474.00 0.80 1,304.34 3,291.60 52.13 125.95 2,765.22 2,705.62 - 744.65 1,165.65 6,013,057.55 519,538.10 0.15 1,383.13 3,391.60 52.77 125.92 2,826.17 2,766.57 - 791.18 1,229.84 6,013,011.18 519,602.40 0.64 1,462.22 3,491.60 53.17 125.95 2,886.39 2,826.79 - 838.03 1,294.48 6,012,964.49 519,667.15 0.40 1,541.86 3,591.60 53.55 126.03 2,946.07 2,886.47 - 885.18 1,359.40 6,012,917.51 519,732.18 0.39 1,621.91 3,691.60 53.70 126.08 3,005.37 2,945.77 - 932.57 1,424.49 6,012,870.28 519,797.39 0.16 1,702.22 3,791.60 54.08 126.33 3,064.31 3,004.71 - 980.29 1,489.68 6,012,822.73 519,862.69 0.43 1,782.79 3,891.60 54.15 126.47 3,122.92 3,063.32 - 1,028.37 1,554.89 6,012,774.82 519,928.01 0.13 1,863.57 3,991.60 54.90 126.88 3,180.96 3,121.36 - 1,077.01 1,620.21 6,012,726.34 519,993.44 0.82 1,944.73 4,091.60 55.32 126.98 3,238.16 3,178.56 - 1,126.30 1,685.78 6,012,677.22 520,059.12 0.43 2,026.45 4,191.60 55.53 126.97 3,294.91 3,235.31 - 1,175.82 1,751.56 6,012,627.87 520,125.01 0.21 2,108.48 4,291.60 55.70 127.02 3,351.38 3,291.78 - 1,225.48 1,817.47 6,012,578.38 520,191.04 0.17 2,190.69 4,391.60 55.85 127.20 3,407.63 3,348.03 - 1,275.37 1,883.41 6,012,528.66 520,257.10 0.21 2,273.05 3/30/2010 1:31:31PM Page 3 COMPASS 2003.16 Build 69 ti_..3 f. . L. ' i °: 's • 0 Halliburton Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordlnate Reference: Well 3N -16 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Project: Kuparuk River Unit MD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Site: Kuparuk 3N Pad North Reference: True Well: 3N -16 Survey Calculation Method: Minimum Curvature Wellbore: PIan: 3N-16A Design: 3N -16A (wp07) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/ -W Northing Easting DLS Vert Section (ft) (*) (1 (ft) ft (ft) (ft) (ft) (ft) (°1100ft) 4,491.60 55.95 127.43 3,463.69 3,404.09 - 1,325.56 1,949.26 6,012,478.63 520,323.07 0.22 2,355.50 4,591.60 55.95 127.57 3,519.68 3,460.08 - 1,376.00 2,015.00 6,012,428.36 520,388.92 0.12 2,437.97 4,691.60 56.10 127.80 3,575.57 3,515.97 - 1,426.70 2,080.63 6,012,377.83 520,454.67 0.24 2,520.49 4,788.60 55.93 128.02 3,629.79 3,570.19 - 1,476.12 2,144.08 6,012,328.57 520,518.24 0.26 2,600.49 9 5/8" 4,791.60 55.92 128.03 3,631.47 3,571.87 - 1,477.65 2,146.04 6,012,327.04 520,520.20 0.26 2,602.96 4,891.60 56.07 127.72 3,687.40 3,627.80 - 1,528.54 2,211.47 6,012,276.32 520,585.75 0.30 2,685.42 4,906.10 55.93 127.65 3,695.51 3,635.91 - 1,535.89 2,220.99 6,012,268.99 520,595.28 1.08 2,697.38 Tie -on @ 4906' MD, 3696' TVD: 25' FSL, 2187' FWL - Sec28,T13N,R09E 4,906.12 55.93 127.65 3,695.52 3,635.92 - 1,535.90 2,221.00 6,012,268.98 520,595.30 0.00 2,697.40 7" TOW 4,918.10 57.29 129.25 3,702.11 3,642.51 - 1,542.12 2,228.83 6,012,262.78 520,603.14 15.93 2,707.33 Start 20.00 hold at 4918.10 MD 4,938.10 57.29 129.25 3,712.92 3,653.32 - 1,552.77 2,241.86 6,012,252.17 520,616.20 0.00 2,724.03 Start Turn 3.00 4,999.99 57.29 131.11 3,746.37 3,686.77 - 1,586.36 2,281.65 6,012,218.68 520,656.06 2.52 2,775.57 5,038.10 57.29 132.25 3,766.96 3,707.36 - 1,607.68 2,305.60 6,012,197.42 520,680.06 2.52 2,807.17 Start DLS 4.50 TFO - 179.87 5,099.99 54.50 132.24 3,801.66 3,742.06 - 1,642.13 2,343.53 6,012,163.07 520,718.08 4.50 2,857.59 5,199.99 50.00 132.23 3,862.87 3,803.27 - 1,695.26 2,402.06 6,012,110.08 520,776.73 4.50 2,935.38 5,299.99 45.50 132.21 3,930.09 3,870.49 - 1,744.99 2,456.86 6,012,060.49 520,831.65 4.50 3,008.21 5,399.99 41.00 132.19 4,002.90 3,943.30 - 1,791.01 2,507.61 6,012,014.61 520,882.51 4.50 3,075.63 5,499.99 36.50 132.17 4,080.87 4,021.27 - 1,833.02 2,553.98 6,011,972.71 520,928.98 4.50 3,137.22 5,599.99 32.00 132.14 4,163.51 4,103.91 - 1,870.79 2,595.69 6,011,935.05 520,970.78 4.50 3,192.60 5,699.99 27.50 132.10 4,250.30 4,190.70 - 1,904.06 2,632.49 6,011,901.87 521,007.65 4.50 3,241.44 5,799.99 23.00 132.06 4,340.73 4,281.13 - 1,932.65 2,664.14 6,011,873.37 521,039.37 4.50 3,283.43 5,899.99 18.50 131.98 4,434.21 4,374.61 - 1,956.36 2,690.45 6,011,849.72 521,065.74 4.50 3,318.31 5,986.85 14.59 131.89 4,517.46 4,457.86 - 1,972.89 2,708.85 6,011,833.24 521,084.18 4.50 3,342.67 Start 1270.50 hold at 5986.85 MD 5,999.99 14.59 131.89 4,530.18 4,470.58 - 1,975.10 2,711.32 6,011,831.03 521,086.65 0.00 3,345.93 6,099.99 14.59 131.89 4,626.95 4,567.35 - 1,991.92 2,730.07 6,011,814.26 521,105.44 0.00 3,370.75 6,199.99 14.59 131.89 4,723.73 4,664.13 - 2,008.75 2,748.83 6,011,797.49 521,124.24 0.00 3,395.57 6,299.99 14.59 131.89 4,820.50 4,760.90 - 2,025.57 2,767.58 6,011,780.71 521,143.03 0.00 3,420.39 6,399.99 14.59 131.89 4,917.27 4,857.67 - 2,042.39 2,786.34 6,011,763.94 521,161.83 0.00 3,445.21 6,499.99 14.59 131.89 5,014.05 4,954.45 - 2,059.21 2,805.10 6,011,747.16 521,180.62 0.00 3,470.03 6,599.99 14.59 131.89 5,110.82 5,051.22 - 2,076.03 2,823.85 6,011,730.39 521,199.42 0.00 3,494.85 6,699.99 14.59 131.89 5,207.59 5,147.99 - 2,092.86 2,842.61 6,011,713.61 521,218.21 0.00 3,519.67 6,799.99 14.59 131.89 5,304.37 5,244.77 - 2,109.68 2,861.36 6,011,696.84 521,237.01 0.00 3,544.49 6,899.99 14.59 131.89 5,401.14 5,341.54 - 2,126.50 2,880.12 6,011,680.07 521,255.80 0.00 3,569.30 6,999.99 14.59 131.89 5,497.92 5,438.32 - 2,143.32 2,898.88 6,011,663.29 521,274.60 0.00 3,594.12 7,099.99 14.59 131.89 5,594.69 5,535.09 - 2,160.14 2,917.63 6,011,646.52 521,293.40 0.00 3,618.94 7,199.99 14.59 131.89 5,691.46 5,631.86 - 2,176.97 2,936.39 6,011,629.74 521,312.19 0.00 3,643.76 7,257.34 14.59 131.89 5,746.97 5,687.37 - 2,186.61 2,947.14 6,011,620.12 521,322.97 0.00 3,658.00 Start DLS 4.50 TFO -54.94 7,299.99 15.77 126.10 5,788.13 5,728.53 - 2,193.62 2,955.83 6,011,613.14 521,331.67 4.50 3,669.07 3/30/2010 1:31:31PM Page 4 COMPASS 2003.16 Build 69 1 . 0 Halliburton Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 3N -16 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Project: Kuparuk River Unit MD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Site: Kuparuk 3N Pad North Reference: True Well: 3N -16 Survey Calculation Method: Minimum Curvature Welibore: PIan: 3N-16A Design: 3N -16A (wp07) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /S +EI -W Northing Easting OLS Vert Section (ft) ( °) (1 (ft) ft (ft) (ft) (ft) (ft) (°/100ft} 7,399.99 19.00 115.57 5,883.57 5,823.97 - 2,208.66 2,981.51 6,011,598.17 521,357.39 4.50 3,698.82 7,499.99 22.66 108.16 5,977.03 5,917.43 - 2,221.69 3,014.52 6,011,585.21 521,390.42 4.50 3,733.72 7,599.98 26.56 102.77 6,067.94 6,008.34 - 2,232.64 3,054.65 6,011,574.37 521,430.58 4.50 3,773.56 7,601.28 26.62 102.71 6,069.10 6,009.50 - 2,232.77 3,055.21 6,011,574.24 521,431.14 4.50 3,774.11 Upper Kalubik 7,699.98 30.62 98.69 6,155.73 6,096.13 - 2,241.44 3,101.66 6,011,565.69 521,477.60 4.50 3,818.09 7,724.95 31.65 97.83 6,177.10 6,117.50 - 2,243.29 3,114.43 6,011,563.87 521,490.38 4.50 3,829.90 Lower Kalubik 7,799.98 34.78 95.50 6,239.87 6,180.27 - 2,248.02 3,155.25 6,011,559.23 521,531.21 4.50 3,867.03 7,867.19 37.61 93.71 6,294.10 6,234.50 - 2,251.19 3,194.80 6,011,556.17 521,570.76 4.50 3,902.25 Kup D 7,899.98 39.00 92.92 6,319.84 6,260.24 - 2,252.36 3,215.10 6,011,555.05 521,591.06 4.50 3,920.09 7,972.73 42.11 91.32 6,375.10 6,315.50 - 2,254.09 3,262.36 6,011,553.44 521,638.32 4.50 3,961.09 Kup C4 7,999.98 43.28 90.77 6,395.13 6,335.53 - 2,254.42 3,280.83 6,011,553.15 521,656.79 4.50 3,976.94 8,013.74 43.87 90.50 6,405.10 6,345.50 - 2,254.53 3,290.32 6,011,553.07 521,666.28 4.50 3,985.04 Kup C1 8,040.06 45.00 90.00 6,423.89 6,364.29 - 2,254.60 3,308.74 6,011,553.03 521,684.70 4.50 4,000.70 Start 100.00 hold at 8040.06 MD 8,072.88 45.00 90.00 6,447.10 6,387.50 - 2,254.60 3,331.95 6,011,553.09 521,707.91 0.00 4,020.39 Kup B 8,099.98 45.00 90.00 6,466.26 6,406.66 - 2,254.60 3,351.11 6,011,553.14 521,727.07 0.00 4,036.64 8,140.02 45.00 90.00 6,494.57 6,434.97 - 2,254.60 3,379.42 6,011,553.21 521,755.37 0.00 4,060.65 51/2x31/2" 8,140.06 • 45.00 90.00 6,494.60 . 6,435.00 - 2,254.60 3,379.45 • 6,011,553.21 521,755.40 0.00 4,060.67 3N -16A KupA5 (wp07) Targets Target Name • hiUmiss target Dip Angle Dip Dir. TVD +NI-S +E/ -W Northing Easting - Shape ( °) (°) (ft) (ft) (ft) (ft) (ft) 3N -16A KupA5 (wp07) 0.00 0.00 6,494.60 - 2,254.60 3,379.45 6,011,553.21 521,755.40 - plan hits target center - Circle (radius 200.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') (1 8,140.02 6,494.58 5 1/2 x 3 1/2" 3 -1/2 6 -1/8 4,906.12 3,695.52 7" TOW 7 8 -1/2 4,788.60 3,629.79 9 5/8" 9 -5/8 12 -1/4 3/30/2010 1:31:31PM Page 5 COMPASS 2003.16 Build 69 ' 1 r t A L 0 6 Halliburton HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 3N -16 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Project: Kuparuk River Unit MD Reference: PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)) Site: Kuparuk 3N Pad North Reference: True Well: 3N -16 Survey Calculation Method: Minimum Curvature Welibore: PIan: 3N-16A Design: 3N -16A (wp07) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) ( ) 6,588.10 Kup Al 0.00 7,601.28 6,069.10 Upper Kalubik 0.00 7,724.94 6,177.10 Lower Kalubik 0.00 6,546.10 Kup A2 0.00 6,629.10 Miluveach 0.00 7,867.18 6,294.10 Kup D 0.00 8,013.74 6,405.10 Kup C1 0.00 6,520.10 Kup A3 0.00 7,972.73 6,375.10 Kup C4 0.00 6,509.10 Kup A5 0.00 8,072.88 6,447.10 Kup B 0.00 Plan Annotations Measured Vertical Local Coordinates 1 Depth Depth +N / -S +E1 -W (ft) (ft) (ft) (ft) Comment 4,906.10 3,695.51 - 1,535.89 2,220.99 Tie -on © 4906' MD, 3696' TVD: 25' FSL, 2187' FWL - Sec28,T13N,R09E 4,918.10 3,702.11 - 1,542.12 2,228.83 Start 20.00 hold at 4918.10 MD 4,938.10 3,712.92 - 1,552.77 2,241.86 Start Tum 3.00 5,038.10 3,766.96 - 1,607.68 2,305.60 Start DLS 4.50 TFO - 179.87 5,986.85 4,517.46 - 1,972.89 2,708.85 Start 1270.50 hold at 5986.85 MD 7,257.34 5,746.97 - 2,186.61 2,947.14 Start DLS 4.50 TFO -54.94 8,040.06 6,423.89 - 2,254.60 3,308.74 Start 100.00 hold at 8040.06 MD 8,140.06 6,494.60 - 2,254.60 3,379.45 TD Intermediate © 8140' MD, 6495' TVD: 695' FNL, 1937' FEL 3/30/2010 1:31:31PM Page 6 COMPASS 2003.16 Build 69 �, ,. f 0 i t o ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N -16 Plan: 3N -16A 3N -16A (wp07) • Sperry Drilling Services Clearance Summary Anticollision Report 30 March, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3N Pad - 3N -16 - Plan: 3N -16A - 3N -16A (wp07) Well Coordinates: 6,013,550.99 N, 1,658,402.43 E (70° 26' 54.90" N, 149° 51' 11.76" W) • Datum Height: Plan :3N -16A @ 59.60ft (D16 (34.1 +25.5)) Scan Range: 4,906.10 to 8,140.02 ft. Measured Depth. Scan Radius is 1,011.45 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ConocoPhillips (Alaska) Inc. -Kup2 ANTI - COLLISION SETTINGS Date: 2010-03-29T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Interpolation Method: MD, interval: 25.00 Error System: ISCWSA Depth Range From: 4906.10 To 8140.02 Scan Method: Tray. Cylinder North Centre Distance: 1011.45 Depth From Depth To Survey/Plan Tool Error Surface: Elliptical Conic Reference: Plan: 3N -16A (wp07) (3N -16 /Plan: 3N -16A) 91.60 4906.10 3N -16 (3N -16) GCT -MS Warning Method: Rules Based 4906.10 8140.02 3N -16A (wp07) (Plan: 3N -16A) MWD+IFR- AK -CAZ-SC GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 0 30 O 330 ? 30 300 4 / i 80 __ / / / " " 300 i t / III / f/ 4111 / i .1* ° �:��1 ti +Q� 3 0 �♦ �A�� f / From Colour To MD /, %, � � "1 ° � ` �,�� i Aii,..„ , ' r / '. 'Pe i 4906 5000 270 •�a 90 2 70 ( �� so 5000 5250 �\ �� , `� „dr , , , , "J. , ,„ , ,..._ .. re 4;i 5250 5500 i i ; 4 . . t o 5500 5750 / If:6k / , _ �i 5750 6000 111 i / . 1 240 / 120 ;� i / . / j / 6000 6500 � , .. j j 6500 7000 240 120 7000 8150 444 ilia in. .:::. : rl ell ` - - -- **ill 1, 150 180 10 210 41 11141.41i ll i 0 150 Travelling Cylinder Azimuth (TFO+AZI) 11 vs Centre to Centre Separation [50 ft/in] 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [200 ft/in[ SECTION DETAILS Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 1 4906.10 55.93127.653695.51 - 1535.892220.99 0.00 0.002697.38 2 4918.10 57 .29129.253702.11 - 1542.122228.83 15.90 45.00 2707.33 Details: 3N - North American Datum 1983 Alaska Zone 4 3 4938.10 57 .29129.253712.92 - 1552.772241.86 0.00 0.002724.03 4 5038.10 57.29 132.25 3766.96 - 1607.68 2305.60 2.52 90.00 2807.17 5 5986.94 14.59 131.87 4517.551972.87 2708.90 4.50 - 179.86 3342.70 Ground Level: 34.10 6 7257.35 14.59 131.87 5747.00- 2186.44 2947.18 0.00 0.00 3657.94 +N1 - +E/ - Northing Easting Latittude Longitude Slot 7 8040.02 45.00 90.006423.89 - 2254.373308.76 4.50 - 54.924000.60 0.00 0.00 6013550.99 1658402.43 70° 26' 54.896 N 149° 51' 11.761 W 8 8140.02 45.00 90.006494.60.2254.373379.47 0.00 0.00 4060.57 3N -16A KupA5 (wp07) ConocoPhillips (Alaska) Inc. -Kup2 HALL1BURTDN Kuparuk River Unit Anticollision Report for 3N -16 - 3N -16A (wp07) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3N Pad - 3N -16 - Plan: 3N -16A - 3N -16A (wp07) Scan Range: 4,906.10 to 8,140.02 ft. Measured Depth. Scan Radius is 1,011.45 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Kuparuk 3N Pad • 3N - 16 - 3N - 16 - 3N - 16 4916 011S 4,918.E - 0.92 4425.00 0.150 Clearance Factor FAN. - Major Risk Survey tool program From (ft) To (ft) Survey /Plan Survey Tool 91.60 4,906.10 GCT -MS 4,906.10 8,140.02 3N- 16A(wp07) MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 30 March, 2010 - 13:52 Page 2 of 4 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTON Kuparuk River Unit Anticollision Report for 3N -16 - 3N -16A (wp07) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to PIan:3N -16A @ 59.60ft (D16 (34.1 +25.5)). Northing and Easting are relative to 3N -16. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150,00 °, Grid Convergence at Surface is: 0.14 °. Ladder Plot L EGEND S C 3N -16, 3N -16, 3N -16V1 . . 900 -B- 3N-08, 3N -08, 3N -08 V8 0 0 $ 3N -08, 3N -08A, 3N -08AV4 c') 3N -09, 3N -09, 3N -09 V1 - 0 F 4 3N -10, 3N -10, 3N -10 V1 O '..= - - 3N -11, 3N -11, 3N -11 V1 as 600 - -6- 3N- 12,3N- 12,3N -12V1 Q i ; ; 3N -13, 3N -13, 3N -13 V1 N 3N -14, 3N -14, 3N -14 V1 f'-- N -4- 3N -14, 3N -14A, 3N-14A V12 -e- 3N -14, 3N- 14APB1, 3N- 14APB1 V7 N U 3N -15, 3N -15, 3N -15 V1 o 300 3N- 17,3N- 17,3N -17 V1 O -$ 3N -18, 3N -18, 3N -18 V1 c -- 3N -18, 3N -18L1, 3N -18L1 V1 • O U , --9- 3N- 18,3N- 18L1PB1,3N- 18L1PB1V1 1 � i 3N -19, 3N -19, 3N -19 V4 0 1 3N -19, 3N- 19PB1, 3N -19PB1 V12 -9- 3N- 16A(wp07) 0 1500 3000 4500 6000 7500 Measured Depth (1500 ft /in) 30 March, 2010 - 13:52 Page 3 of 4 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALL 1 BU RTON Kuparuk River Unit Anticollision Report for 3N -16 - 3N -16A (wp07) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10.00- _ _ ...:.... i i LEGEND • 1 44- 3N -16, 3N -16, 3N -16 V1 $ 3N-08, 3N-08, 3N-08 V8 7.50- - � _ �_ -9- 3N -08, 3N -08A, 3N-08AV4 O _ -4- 3N -09, 3N -09, 3N-09 V1 S- 3N -10, 3N -10, 3N -10 V1 , ^...,, 625- -6- 3N- 11,3N- 11,3N -11 V1 -A- 3N -12, 3N -12, 3N -12 V1 as 3N-13, 3N -13, 3N -13 V1 g 5.00 - , o $ 3N -14, 3N -14, 3N -14 V1 Ill -4- 3N -14, 3N -14A, 3N- 14AV12 $ 3N -14, 3N- 14APB1, 3N- 14APB1 W r -- 3.75 :....... _ . 1 3N -15, 3N -15, 3N -15 V1 3N -17, 3N -17, 3N -17 V1 $ 3N -18, 3N -18, 3N -18 V1 2.50 - - - -4- 3N-18, 3N -18L1, 3N -18L1 V1 - I - I . -0- 3N-18, 3N -18L1 PB1, 3N -18L1 PB1 V1 1.25 -M- 3N-19, 3N-19, 3N-19 V4 - - 3N-19, 3N- 19PB1, 3N -19PB1 V12 $ 3N- 16A(wp07) 0.00_ . I 1 1 1 1 1 1 1 1 1 I I I I I I I 1 1 1 1 1 11 1 1 I I I I I I I I I I I I I 1 l l l l l I I I I 1 1 1 1 I I I I I I I 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Measured Depth (1500 Win) 30 March, 2010 - 13 :52 Page 4 of 4 COMPASS • • 3N -16A Drilling Hazards High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD tool while higher MW's required drilling across pay interval. Pump and rotate out on trips as a last resort. Barite Sag Low Use Good drilling practices as documented in well plan and keep track of mud properties in line with mud program. Hole instability while drilling High Use enough MW to stabilize Kalubick without sustaining losses Kalubick Shale section Lost Circulation Moderate Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree as needed. ORIGW.AtL 3N -16A SIDETRA( - &wel ConocoPhillip_ 3 -' /2" TRMAXX -CMT SSSV w/ 2.812" "X" 7" x 9 -5/8" annulus Arctic profile (5.176" O.D.) @ packed in 1986 w/ +1- 2,106' MD 29 bbls cmt + 60 bbls diesel 3 -'' /2" x 1" KBMG, (5.39" O.D.) Est. TOC @ 3,820' ::: - :: EUE 8RD Mod,Camco GLM inside 7" AL ; ..;. ; i; ; 9 -5/8" 36# J -55 casing @ 4,797' MD / 3,638' TVD TOL @ +/- 4,700' MD �� Sidetrack KOP w/ window in 7" @ +/- 4,920' MD MD GLM Placement 3,036' 3 -' /2" x 1" KBMG GLM (inside 7" csg.) 5,078' 3 -1/4" x 1" KBG2 -9 GLM (inside 5 -1/2" csg.) 6,281' 3 -' /2" x 1" KBG2 -9 GLM (inside 5 -1/2" csg.) 3aker "K -1" CIBP 7,114' 3 -'h" x 1" KBG2 -9 GLM (inside 5 -1/2" csg.) 7,640' 3 -' /2" x 1" KBG2 -9 GLM (inside 5-1/2" csg.) lelow set point for (This mandrel will have the annulus to tubing shear) hipstock @ 4,920' 3 -' /2" 9.3 #, L -80, IBTM w/ Est. TOC on 3.865" O.D. Special Clearance 7" csg. @ Tubing chemical cut couplings to top of liner with 3,818' MD _ +/_ @ 8 252' 3.5 ", 9.3# L -80 EUE above liner top Brown `HB -1' Packer @ 8,636' 'ubing cmt retainer :' ` TOC @ +/- 6,625' MD @ 8,656' MD Perfs @ * ,;;'' :> .... > s':; 8,778' — 8,799' ; Z .' `` : Brown `1B' Packer @ 8,825' 2.75" "X" Ni pp In tubing tail 3 -1/2" x 5 -1/2" I ry I Bttm of tubing @ Retainer Production Packer 8,854' MD @ 7,975' MD G378 Perfs @ 8,896' — 8,957' Estimated BHP 4 PPG : : �i " 5 -1/2 ST -L 15.5# Casing 7" 26# J -55 ORIGINAL set @ 8,125' MD @9,189'MD6,815'TVD /6 shoe_ • • 3N -16a Schlumberger CemCADE Preliminary Job Design 5-1/2" Liner wp07 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 16 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date: 04/07/2010 Volumes are based on 25% excess - equivalent hole size of above a 6 -1/8 hole reamed Prepared by: Mike Martin to 7.5 ". Displacement is calculated with a 4.0 "- 14.0# drill string. Location: Anchorage, AK Phone: (907) 263 -4207 Mobile: (907) 748 -6900 Tail Slurry Minimum thickening time: 170 min. (pump time plus 120 min.) email: martin13 @slb.com 15.8 ppg Class G + 0.2 %D46, 0.3 %D65, 0.1 %B155, 0.4% D167 - 1.16 ft3 /sk Annular Volume: 0.1426 ft /ft x (8140' - 6625') x 1.25 (25% excess) = 271 ft Shoe Volume: 0.1336 ft /ft x 80' x 1.00 (no excess) = 11 ft Totals: 271 ft + 11 ft = 282 ft < Liner Top at 282 ft 1.16 ft /sk = 243 sks 4,680' MD Round up to 250 sks BHST = 156 F, Estimated BHCT = 119 `F. Window (BHST calculated using a gradient of 2.1 T /100 ft. from surface) 7 ", 26.0# casing at 4,920' MD PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time < 5.5", 15.5# casing Stage (bpm) Volume (min) Time (bbl) (min) in 6 -1/8" OH CW100 5.0 30.0 6.0 6.0 MUDPUSH II 5.0 30.0 6.0 12.0 Unislurry Tail 5.0 50.0 10.0 22.0 Drop liner dart/plug 0.0 0.0 5.0 27.0 Top of Slurry at Sea Water 5.0 10.0 2.0 29.0 < 6,625' MD Mud 5.0 40.0 8.0 37.0 Slow, pick up plug 2.0 10.0 5.0 42.0 Mud 5.0 62.2 12.4 56.4 Mud 3.0 9.0 3.0 59.4 Top of C Sand MUD REMOVAL at - 7,973' MD Recommended Mud Properties: 9.0 ppg, P < 10, T < 10. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, P = 20 - 28, T = 25 - 30 TD at 8,140' MD (6,495' TVD) Centralizers: None run Mark of Schlumberger ORIGINAL Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 20, 2010 1:32 PM To: 'Greener, Mike R.' Subject: RE: Corrections to permit for 3N -16A Agree with the wording now. The CBL will give us the final word. We have some leeway if the TOC is a bit deep and the bond looks good. I am sure the reservoir folks will be keen to see what the cement looks like between the Kuparuk C and A sands too. They don't want a short circuit when they start injecting. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Greener, Mike R. [mailto:Mike.R.Greener @conocophillips.com] Sent: Tuesday, April 20, 2010 1:05 PM To: Schwartz, Guy L (DOA) Cc: Ryan, Owen M Subject: RE: Corrections to permit for 3N -16A So line 24 should read: 24. If cement top is NOT 500' above the top of the Kuparuk "C" formation (expected formation top at 7,942' MD / 6,375' TVD), then consult with drilling engineer and state on plan forward to ensure we have the adequate amount of cement above the formation as determined by the state . Mike Greener From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, April 20, 2010 11:18 AM To: Greener, Mike R. Subject: RE: Corrections to permit for 3N -16A Mike, By regulation the TOC is supposed to be 500' above the significant Hydrocarbon zone (not 100') per 20 AAC 25.030 (d) (5) When I was discussing the 100' of cement I was referring to having 100' of good cement isolation as verified by the CBL.. it is possible to have 500' of crap cement and not isolate anything!!! . The TOC still should be 500' above the Kuparuk zone.... The idea though is to have zonal isolation ... we can look at the CBL and make that determination when the time comes. Guy Schwartz Senior Petroleum Engineer AOGCC 4/20/2010 Page 2 of 2 i • 793 -1226 (office) 444 -3433 (cell) From: Greener, Mike R. [mailto: Mike .R.Greener ©conocophillips.com] Sent: Tuesday, April 20, 2010 10:54 AM To: Schwartz, Guy L (DOA) Cc: Ryan, Owen M Subject: Corrections to permit for 3N -16A Changes to completion procedure for 3N -16A 20. Set storm packer and change out the 11 "x3 by 7 -1/16" x 5M spool and then re-run the tbg head. Test BOP. 21. PU all tubing and completion equipment and run in hole. 22. POOH with completion string and rack back. This time period should give the cement enough to cure before running the bond log. 23. Rig up wireline and run cement bond log. 5u T. 24. If cement top is NOT 100' above the top of the Kuparuk "C" formation (expected top at 7,942' MD / 6,375' TVD), then consult with drilling engineer and state on plan forward to ensure we have the cement top the required 100' above the formation. 25. PU and run completion packer on wireline. A Completion packer is to be set within 200' above the top of the Kuparuk "C" formation. (6,175' TVD to 6,374' TVD) 26. RIH with the 3 -1/2" tubing. Space out and land. Test tubing, PBR and liner to 2500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 2500 psi. Bleed off all pressures. 27. Install a TWC. ND BOPE. NU and test the 3 -1/8" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to + 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid. Install a BPV. R/D and M/O. Mike Greener 4/20/2010 Cr) 03 * *ix + 447 `� tJ r x _ � t e \ �` .uf t Q� . - {• "' • en, rid 't .: e,. J 0 co N. l°7 e- `+� N. c + \ • c� ' .ti p ,ar f. rrA o> ! :f� c• o Q Co ' ? ' 47 .111 Tom' `*? •.-,' , � ! yyy�� oss / , `(,`� j i � 4 co e° r r e t C? C`4 ( C7 4 all • " ri- -_. O 0 { Lo 0 I 0 ?i {9 ('-t 0 ? C. 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EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO 2 6000000 _} • 3N -16A AEO 1 5950000 5900000 40 CFR 147.102 (b)(3) • 5850000 400000 500000 600000 700000 800000 TRANSMITTAL LETTER CHECK WELL NAME 20 -7 PTD# 2--/C Development v Service Exploratory Stratigraphic Test Non-Conventional Well ( ( ,c< i t 1' �<< � �Ci FIELD: � � � POOL: Circle ✓ Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 6 0 ❑❑ „ „ N ., „ 0) 0 N a co E o „ o ° I a I OI rn L a, rn CC c o a) ° @ a w' a, ; (0 co o E O N , as, rn as o, ° � o, a)' 7 U m U L' E, E as, Oi ° N' co 3 a, Q m 1 a c, a L0 o' a H' °, I CV ° N� a), 6.. a) a; a) ' H o, c p. U w - o ctS, ca ' j0 0, a as, o. a - �, N V), (0 c 0 o , I ' a P ., .o E '3 cc) z1 O ' c ' �, '` �, co; ° 3' a) N N °) 0 - d a) ct' � , W , °' N' CO' > as' Q O as 0' co o_ c ° Q' 9 > o ' Y co O M C m 0 o Z Q y 0 a 0 c co _ p - 0, a) D o co .J >. N' - o c7 1-, as E O N , c N c) ' E' V/ Q , I 0 , , , 0 O p 0) Z, ' I (p M C. 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