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209-115
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-60A COLVILLE RIV UNIT CD2-60A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 CD2-60A 50-103-20511-01-00 209-115-0 W SPT 6977 2091150 1744 1976 1976 1976 1976 705 750 750 750 4YRTST P Austin McLeod 6/30/2024 MITIA 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:COLVILLE RIV UNIT CD2-60A Inspection Date: Tubing OA Packer Depth 1220 3300 3240 3240IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240630192442 BBL Pumped:2.5 BBL Returned:2.5 Thursday, July 25, 2024 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-60 (PTD#209-115) Date:Thursday, July 11, 2024 11:15:38 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, July 11, 2024 11:10 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-60 (PTD#209-115) Chris, Operations reports they plan to keep CD2-60A on water only injection for the foreseeable future. If CPAI decides to WAG the well in the future, a 30-day monitor on MI will be conducted at the time. proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Wednesday, July 3, 2024 5:51 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-60 (PTD#209-115) Chris, The 30-day monitor on water will end on July 7th. The well looks stable. CPAI will conduct a 30-day monitor on MI. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Kate From: Dodson, Kate Sent: Wednesday, February 28, 2024 1:25 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-60 (PTD#209-115) Chris, Previous reservoir surveillance suggested that CD2-60A may not have been providing injection support to offset producers. Based on current offset well performance and potential changes in reservoir interactions, the decision to reinstate injection in CD2-60A is being progressed. CPAI would like to restart the plan from 2016 beginning with diagnostics and progressing to 30-day monitor on water. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, May 15, 2016 12:49 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv <n1617@conocophillips.com> Subject: CRU CD2-60 (PTD#209-115) Update 5/15/2016 Chris, CRU CD2-60 (PTD# 209-115) is an injector we previously reported for suspect IA pressure increase while on miscible injection. The 30 day monitor on water injection was started, however, it was shut-in August 2, 2015 and a downhole gauge was installed. CPAI has since determined that CD2-60 does not need utilized at this time. For that reason, CPAI intends to secure the well with a plug and postpone investigation. Due to recurrent hydrate formation in the well, CPAI intends to flush the wellbore and near wellbore area by injecting water into the well for 3 days before doing the wellwork to mitigate the potential for gas entering the tubing and forming hydrates. Attached is a wellbore schematic and 90 day TIO trend. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer ConocoPhillips Alaska, Inc. Temp. Slope Phone: 907-659-7126 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-60 (PTD#209-115) Date:Friday, July 5, 2024 9:02:16 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, July 3, 2024 5:51 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-60 (PTD#209-115) Chris, The 30-day monitor on water will end on July 7th. The well looks stable. CPAI will conduct a 30-day monitor on MI. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Kate From: Dodson, Kate Sent: Wednesday, February 28, 2024 1:25 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-60 (PTD#209-115) Chris, Previous reservoir surveillance suggested that CD2-60A may not have been providing injection support to offset producers. Based on current offset well performance and potential changes in reservoir interactions, the decision to reinstate injection in CD2-60A is being progressed. CPAI would like to restart the plan from 2016 beginning with diagnostics and progressing to 30-day monitor on water. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, May 15, 2016 12:49 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv <n1617@conocophillips.com> Subject: CRU CD2-60 (PTD#209-115) Update 5/15/2016 Chris, CRU CD2-60 (PTD# 209-115) is an injector we previously reported for suspect IA pressure increase while on miscible injection. The 30 day monitor on water injection was started, however, it was shut-in August 2, 2015 and a downhole gauge was installed. CPAI has since determined that CD2-60 does not need utilized at this time. For that reason, CPAI intends to secure the well with a plug and postpone investigation. Due to recurrent hydrate formation in the well, CPAI intends to flush the wellbore and near wellbore area by injecting water into the well for 3 days before doing the wellwork to mitigate the potential for gas entering the tubing and forming hydrates. Attached is a wellbore schematic and 90 day TIO trend. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer ConocoPhillips Alaska, Inc. Temp. Slope Phone: 907-659-7126 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from kate.dodson@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-60 (PTD#209-115) Date:Friday, March 1, 2024 7:39:44 AM From: Dodson, Kate <Kate.Dodson@conocophillips.com> Sent: Wednesday, February 28, 2024 1:25 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-60 (PTD#209-115) Chris, Previous reservoir surveillance suggested that CD2-60A may not have been providing injection support to offset producers. Based on current offset well performance and potential changes in reservoir interactions, the decision to reinstate injection in CD2-60A is being progressed. CPAI would like to restart the plan from 2016 beginning with diagnostics and progressing to 30-day monitor on water. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, May 15, 2016 12:49 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv <n1617@conocophillips.com> Subject: CRU CD2-60 (PTD#209-115) Update 5/15/2016 Chris, CRU CD2-60 (PTD# 209-115) is an injector we previously reported for suspect IA pressure increase while on miscible injection. The 30 day monitor on water injection was started, however, it was shut-in August 2, 2015 and a downhole gauge was installed. CPAI has since determined that CD2-60 does not need utilized at this time. For that reason, CPAI intends to secure the well with a plug and postpone investigation. Due to recurrent hydrate formation in the well, CPAI intends to flush the wellbore and near wellbore area by injecting water into the well for 3 days before doing the wellwork to mitigate the potential for gas entering the tubing and forming hydrates. Attached is a wellbore schematic and 90 day TIO trend. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer ConocoPhillips Alaska, Inc. Temp. 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PTD 2041500 Type Inj N Tubing 1310 1600 1600 1600 Type Test P Packer TVD 6998 BBL Pump 3.6 IA 50 2200 2160 2160 Interval 4 Test psi 1750 BBL Return 2.5 OA 110 130 130 130 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040720 Type Inj N Tubing 1350 1350 1350 1350 Type Test P Packer TVD 7001 BBL Pump 3.6 IA 50 2000 1950 1940 Interval 4 Test psi 1750 BBL Return 2.3 OA 0 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2091150 Type Inj N Tubing 1000 1275 1275 1275 Type Test P Packer TVD 6978 BBL Pump 3.8 IA 60 2000 1950 1940 Interval 4 Test psi 1745 BBL Return 3.7 OA 380 400 400 400 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: CD2-56 CD2-57 Notes: CD2-60A Notes:Tubing plug set at 13,201' MD Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/12/22 Form 10-426 (Revised 01/2017)2022-0612_MIT_CRU_CD2-pad_3wells 9 9 9 9 9 9 9 - 5HJJ CD2-60A PT-is Zociuso Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, June 8, 2018 5:02 PM 1<`` 6�/if' To: Regg, James B (DOA);Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOCC Prudhoe Bay Subject: 10-426 Forms for CRU CD2 pad MITIAs Attachments: MIT CRU CD2 Pad pg 1 06-06-18.xlsx; MIT CRU CD2 Pad pg 2 06-05-18.xlsx; MIT CRI CD2 Pad pg 1 06-05-18.xlsx; MIT CRU CD2 Pad 06-07-18.xlsx; MIT CRU CD2 Pad pg 06-06-18.xlsx; MIT CRU CD2- 07,56 & 60 NON injectors 06-07-18.xlsx All, Attached are the 10-426 forms for AOGCC inspector witnessed MITs performed on Coleville River Unit CD2 pad betwe n 6/5/2018 and 6/7/2018. Please let us know if you have any questions. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED -JUN 2 zult 1 • I i • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggCc(alaska.qov AOGCC.Inspectors(rDalaska.aov phoebe.brooksCctalaska.aov chris.wallaceaalaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Alpine/CRU/CD2 Pad ,E',1�'R(1 G DATE: 06/07/18 `T� f OPERATOR REP: Duffy/Weimer AOGCC REP: N/A Well CD2-07 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031870 Type Inj N Tubing 1050 1050 1050 1050 Type Test P Packer TVD 6912 BBL Pump 1.4 IA 610 2010 1950 1940 Interval 4 Test psi 1728 BBL Return 1.3 OA 475 475 475 475 Result P Notes: Inspector Brian Bixby declined witness Well CD2-56 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2041500 Type lnj N Tubing 2400 2400 2400 2400 Type Test P Packer TVD 6923 BBL Pump 2.1 IA 225 1900 1860 1850 Interval 4 Test psi 1731 BBL Return 1.9 OA 60 60 60 60 Result . P Notes: Inspector Brian Bixby declined witness Well CD2-60A - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2091150 - Type Inj N , Tubing 225 475 475 475 Type Test P V Packer TVD 6978 - BBL Pump 2.5 - IA 280 2000- 1960- 1950 - Interval 4 Test psi 1745 - BBL Return 2.3 ' OA 430 440 440 440 Result P l'''I Notes: Inspector Brian Bixby declined witness Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes:, Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes IIS, W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive III I=Industrial Wastewater 0=Other(describe in notes) i, N=Not Injecting Form 10-426(Revised 01/2017) MIT CRU CD2-0756 60 NON injectors 06-07-18 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, May 15, 2016 12:49 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: CRU CD2-60 (PTD#209-115) Update 5/15/2016 Attachments: CD2-60A.pdf; CD2-60_TIO Plot_90 days.docx Chris, CRU CD2-60(PTD#209-115) is an injector we previously reported for suspect IA pressure increase while on miscible injection. The 30 day monitor on water injection was started, however, it was shut-in August 2, 2015 and a downhole gauge was installed. CPAI has since determined that CD2-60 does not need utilized at this time. For that reason, CPAI intends to secure the well with a plug and postpone investigation. Due to recurrent hydrate formation in the well, CPAI intends to flush the wellbore and near wellbore area by injecting water into the well for 3 days before doing the wellwork to mitigate the potential for gas entering the tubing and forming hydrates. Attached is a wellbore schematic and 90 day TIO trend. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer ConocoPhillips Alaska, Inc. Temp.Slope Phone:907-659-7126 SCANNED MAY 1 8 20f6 • • Well Name CD2-60 Notes: Start Date 2/15/2016 Days 90 End Date 5/15/2016 Annular Communication Surveillance 1NHP 453— - •50 40J - •5:• •4:• 3500 - 3CCC _ • U- • 253C • 2C0C - :0 1:71C • 100C 500 • - 7: C: • - Ja--le Feb-18 M-16 .4;7-16 teay-1 C 12 DG I MGI ca c a - -I 13L PD :4 Jan-30 Date Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, June 26, 2015 5:15 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine WAG injector CD2-60A (PTD 209-115) Report of suspect IA pressure increase Attachments: image001.png; CD2-60A wellbore schematic.pdf; CD2-60A 90 day TIO 6-26-15.JPG Chris, CD2-60A Alpine WAG injector (PTD 209-115) has exhibited suspect IA pressure increase while on miscible injection. CPAI intends to leave the well on miscible injection while using DHD to conduct initial diagnostics to include an MIT-IA, pack off tests and an IA draw down test. Depending upon the results of the diagnostics CPAI intends to leave the well on miscible injection for a 30 day monitor period, WAG the well to water for a 30 day monitor period, or shut in and freeze protect the well. At the conclusion of the monitor period CPAI will provide a follow up email with the plan forward and submit any required paperwork. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. JULS���F,Q 015 Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 illWELLS TEAM ConocoPhillips 1 w I I I I W 4] = II 4, U col(LI a' •1 Q. •, U. o N m = n i; a o a) y w 0o N w C -, a 14 W C) rN 1 '' J w LI s c) l O O O I I I I I i r I i ID I LI C CO ' ?1' 4,...,C1 ...L.1.3;,,/ GO ".(,. in 0 Y ea CO V cm 47 o U L N 6) 7 O t C Q U/ _ N W w a � CD CD N O N CI CO CO 0 M CO0 C 4 = O 'm a. H m IIIA EE cu UCD CD CD CD o CI W i iii i 03 03 U. CJ " Ul O UI CO 4i V - Z O 0 •, •, r fv NI Y '`' rb 'ri S u t N p Odie Wall,, C C isd N p w • 0 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. CQ p q - 1 L Well History File Identifier Organizing (done) ❑ Two -sided 111 1111111111! 11111 ❑ Rescan Needed 111 111111 II RESC N DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Di ettes, No. q ❑ Maps: Greyscale Items: I ()our- Other, No/Type: CI) I I 0 L ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non- Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: dIED Date: 1 1 1 /s/ ryl Project Proofing H111E1111 N ll I 1 th BY: Maria Date: - /s/ Scanning Preparation 01_ x 30 = la 0 + 1 = TOTAL PAGES 7 g BY: Date: 1 , J ryl (Count does not include cover sheet) /s/ Production Scanning 1111111111111 II III Stage 1 Page Count from Scanned File: '7 (Count does include cover eet) Page Count Matches Number in Scanni g Preparation: YES NO BY: Date: 1 j 1 /s/ yyi f 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. 111111111111 I 1 111 ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 II 10/6/2005 Well History File Cover Page.doc • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED April 01, 2011 4 e'p) A rka & Res Cons. Cornrnissim Commissioner Dan Seamount ' n 3rAg ti�ti: Alaska Oil & Gas Commission 54 0101IED APR 8 2011 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ©q_ I rr��_6b�I Commissioner Dan Seamount: C1) ,d Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" _ n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 5'10" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 2-60A 50103205110100 2091150 6" n/a _ 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 DATA SUBMITTAL COMPLIANCE REPORT 1/31/2011 Permit to Drill 2091150 Well Name /No. COLVILLE RIV UNIT CD2 -60A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20511 -01 -00 MD 21001 TVD 7453 Completion Date 10/17/2009 Completion Status WAGIN Current Status WAGIN U1 Y ) REQUIRED INFORMATION L.,' Mud Log No Samples No Directional Survey Yes . DATA INFORMATION III Types Electric or Other Logs Run: RES / DENS / NEUTRON (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty! Med /Frmt Number � aN a Scale Media No Start Stop CH Received Comments n"f ED C Lis 18898 duction /Resistivity 14243 20960 Open 11/5/2009 Plus graphics EMF, CGM and PDF of EWR logs i .g Induction /Resistivity 25 Col 14264 21001 Open 11/5/2009 MD ROP, DGR, EWR, ALD, CTN .g Induction /Resistivity 25 Col 7372 7453 Open 11/5/2009 TVD ROP, DGR, EWR, ALD, CTN J D C Directional Survey 36 21001 Open !apt Directional Survey 36 21001 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments 0 ADDITIONAL INFORMATION Well Cored? / N Daily History Received? bYN Chips Received? N, Formation Tops N Analysis Yom" Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/31/2011 Permit to Drill 2091150 Well Name /No. COLVILLE RIV UNIT CD2 -60A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20511 -01 -00 MD 21001 TVD 7453 Completion Date 10/17/2009 Completion Status WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: — — Date: 3 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 P.I. Supervisor TO: Jim Regg eff 7(Z7(i v SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2 -60A FROM: Jeff Jones COLVILLE RIV UNIT CD2 -60A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv.._T 2 — NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV UNIT CD2 -60A API Well Number: 50- 103 - 20511 -01 -00 Inspector Name: JeffJones Insp Num: mitJJ100719133905 Permit Number: 209 -115 -0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2- 60A 'Type Inj. W ' TVD 1 6977 ' IA 1060 3150 ' 3100 3100 P.T.D 2091150 'TypeTest SPT Test psi 1744 OA 330 390 390 390 Interval 4YRTST Pte, P - Tubing 2360 2360 2360 2360 Notes: 2.4 BBLS diesel pumped. 1 well inspected; no exceptions noted. Monday, July 26, 2010 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I �' DATE: Tuesday, January 12, 2010 �' TO: Jim f SUBJECT: Mechanical Integrity Tests P.I. Supervisor CONOCOPHILLIPS ALASKA INC CD2 -60A FROM: Jeff Jones COLVILLE RIV UNIT CD2 -60A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .:39 r� � NON - CONFIDENTIAL Comm Well Name: COLVILLE RIV UNIT CD2 -60A API Well Number: 50 -103 -20511 -01-00 Inspector Name: JeffJones Insp Num:. mitJJ100112141614 Permit Number: 209 -115 -0 Inspection Date: 12/4/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2 -60A Type Inj. W'� TVD 6978 r IA 980 2500 2460 2460 ' P.T.D 2091150" TypeTest SPT Test psi 1744.5 */ OA 420 500 500 500 Interval INITAL P/F P Tubing 1725 1750 1725 ( 1725 Notes: 2 BBLS diesel pumped. I well inspected; no exceptions noted. Tuesday, January 12, 2010 Page 1 oft STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG El WDSPL ❑ Other ❑ No. of Completions: Service El Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: October 17, 2009 209 - 115 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 7, 2009 50 103 - 20511 - 01 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2162' FNL, 1491' FEL, Sec. 2, T11 N, R4E, UM October 14, 2009 CD2 - 60A - Top of Productive Horizon: 8. KB (ft above MSL): 52.4' RKB 15. Field /Pool(s): 2142' FSL, 1745' FWL, Sec. 14, T11 N, R4E, UM GL (ft above MSL): 15.9' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1653' FSL, 693' FEL, Sec. 23, T11 N, R4E, UM 21001' MD / 7453' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 371743 y 5974194 Zone 4 ' 21001' MD / 7453' TVD ADL 380075, 380077 TPI: x - 369513 y - 5962696 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 372262 y 5956880 Zone 4 nipple @ 2273' MD / 1887' TVD 380075 18. Directional Survey: Yes ii 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) 1847' MD / 1647' 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 Res /Dens /Neutron 14264' MD / 7373' 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 36.7' 114' 36.7' 114' 42" pre - installed 9.625" 36# J -55 36.7' 3276' 36.7' 2373' 12.25" 550 sx AS Lite, 241 sx Class G 7" 26# L -80 36.7' 14331' 36.7' 7379' 8.5" 315 sx Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER D) 4.5" 13257' 12897' MD / 78' TVD and open hole completion 14264'- 21001' MD 7373' - 7453' TVD 13141' MD / 7079' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na �/ F GEIV D NOV 1 3 ?009 27. PRODUCTION TEST �t Date First Production Method of Operation (Flowing, gas lift, etc.) Alaska Oil Ga Con OfrirllisSlOfr waiting on facility hook - up A__ Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHI?h€agB GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water _ (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. -'• �� , is MEW. fi NONE Form 10 - 407 Revised 7/2009 CONTINUED ON NOV . 1 3 Submit original only 7, ., '41 7 G 28. GEOLOGIC MARKERS (List all formations and marke 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1847' 1647' needed, and submit detailed test information per 20 AAC 25.071. C -30 3359.5' 2412' C -20 4100.5' 2785' K -3 6335' 3847' K -2 6813.5' 4079' Nanuq 9970.1' 5602' Top HRZ 12645.5' 6866' K -1 13096.5' 7061' Kuparuk 13204' 7103' Alpine A 14517' 7394' N/A Formation at total depth: Alpine A 30. LIST OF ATTACHMENTS Summary of Daily Operations, directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson © 265 - 6318 a Printed Name /) / t% l� G. L. Ivord Title: Alaska Drilling Manager /,� // P., Signature /�/. . Phone t�5 - ma Date lVf i ., [ / e 7 / prepared by: Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 7/2009 v.,- WNS 0 C D2 -60A C+DI1C C} 11 s .((r Well l o sPI /O Attributes ALPINE � Well St�ws Max � Inc1 M Angle & MD Act Bt _..._ , V Ind (1 MD (ftKB) Act m (ftKB) 92.89 20.921_/8 21,001.0 Comment I1-125 (ppm) (Date Annotation "End Date KB -Grd (ft) Rig Release Date nCon s N RL 9N AL c 900, 3200 8,5GRAM SSSV: WRDP Last WO' 44 3/ 7/10/2005 Well 9 9 1x ' Schem al Ac'wal Annotation Depth (ftKB) End Date Annotation Last Mod ... E d Date Last Tag - 'Annotation Reason WELL SIDETRACKED Imosbor 11/3/2009 Casing Strings Casing Description String 0... ( String ID ... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 0.0 114.0 114.0 62.50 H-40 WELDED Insulated 48" Casing Description String O... !Strip ID... To g piton g g p MKS) Set Depth (T... Set Depth (ND) .. String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 0.0 3,276.0 2,373.0 36.00 J -55 BTC _..�._ — — -- Casing Description (String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (ND). String Wt... String... String Top Thrd ` i?;'': PRODUCTION 7 6.151 0.0 14,3310 7,378.7 26.00 L - 80 BTCM HANGER, 31 .�, .._.._� ...__ _.. —_... _._ Y Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String WI... String ... String Top Thrd OPEN HOLE A 6 1/8 14,264.0 21,001.0 Tubing Strings Tubing Description String 0... String ID ... Top (ORB) Set Depth (1... Set Depth (TVD) . String Wt.. String .. String Top Thrd CONDUCTOR Tubing WI 41/2 3 -958 I 31 2 1 - 13,257.1 /,124.4 12.60 L-80 I IBOM _ Insulated 48., Completion Details 0-114 ._ .. __ Top Depth (TVD) Top Intl Top (ftKB) MKS) ( °) Item Description Comment ID (In) 31.2 31.2 0.00 HANGER FMC Gen V Tubing Hanger 3.958 NIPPLE, 2273 2,272.9 1,887.3 60.47 NIPPLE Camco Nipple w/ DB Profile 3 812" ID 3.812 12,897.4 6,977.8 64 41 PACKER Baker 4 1/2" X 7" Premier Packer 3.875 " 13,140.9 7,078.6 6698 PACKERS Baker4 1/2 "X 7" Premier Packer - - -- 3.875 13,201.5 7,102.1 66.35 NIPPLE HESXN Nipple 3.725 suRFACE. 13,255.7 7,123.8 66.59 SHOE Mule Shoe 3.875 Comment 0 3.276 _ __ -.. , . Other In Hole,Wireline retrievable plugs valves pumps, fish, etc.) To Top ( ftKB De ) th (TVD)Top Intl (ORB) ( °) Dlrseripgon Run Date ID (in) . : - -_ _.. P( ) 8425 WHIPSTOCK WHIPSTOCK ANCHOR WK - BILLET 10/4/2009 0.000 GAS LIFT. . 18264 7.3730 -.. 12,706 ii. Notes: General & Safety - _ __ __ _ End Date Annotation 11/3/2009 NOTE' VIEW SCHEMATIC ad/Alaska Schematic9.0 I PACKER. 12897 '...- i, — PACKERS_ : -% 13,141 , _... r .';. ... E NIPPLE, 13,201-- SHOE, 13,256 -- Mandrel Details _ -- Top Depth Top Port (TVD) Ines OD Valve Latch i SAC TRO Run Stn To • B (ftKB) (1 Make Mod I (in) Seen Type Type (n) (pa) Run Date Con... 1 12,786.2 6,929.5 64.19 CAMCO KBG - 2 1 GAS LIFT OV 8EK 0 250 0.0 10/19/2009 WHIPSTOCK, . _ -.... _.._.:.. _ _ _ _._. -- ..._....... 14,264 i PRODUCTION, i i 0- 14,331 OPEN HOLE A, 14,264.21,001l • .:.. TO (CD2 -60A), \ • 21,001 WNS 0 CD2 -60A r^ i COfoo3Phi tps Well Attributes -- -- Max 1 Angle & MD ITO Wellbore API/UWI Field Name Well Status Inc' C) MD (ftKB) Act Bhn (EKE) i11ra`i€V ` � � 501032051101 ALPINE IINJ I 9289 20,92178 t,8lbcd�•n4p•. _ 21 O 001 Comment - II - 2S (ppm) Date Annotation End DateKB - Grd (ft) 1Rig Release Date .•. ell ContgHORIZONTAL 002 61A 1 1/3.006 9 E . AM_ SSSV WRDP Last WO: 44 37 1 //1012005 Schematic Actual Annotation Depth (ftKB) End Date Annotation L t Mod ... End Date Last Tag: Reason: WELL SIDETRACKED 1 Imosbor 11/3/2009_ Casin • Strin • s Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd — CONDUCTOR 16 15.062 0.0 114.0 114.0 62.50 H-40 WELDED Insulated 48" Casing Description String 0... String D - . - Top (ftKB) Set Depth (E.. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 0.0 3,276.0 2,373.0 36.00 J - 55 BTC - - -- Cu rig Description String 0.. Str — - - i . Depth (ND) String Wt... String String Top Thrd � - String ID ... Top (ftKB) Set Depth (f... Set De P ( I 9 9 •�• •i9 W ' PRODUCTION 7 6.151 0.0 14,331.0 7,378 7 26.00 L BTCM HANGER. 31 Casing Description String 0... String ID _. Top (ftKB) Set Depth (f... Set Depth (ND) . IStr ng Wt... String ... String Top Thrd OPEN HOLE A 6 1/8 14,264.0 21 001 0 Tubing Strings . . .. -i Tubing Description String 0... String ID ...ITOp (ftKB) (Set Depth (f...ISet Depth (ND) . String Wt... String !String Top Thrd CONDUCTOR Tubing WI _ 41/2 3958 31.2 13,257 1 7124.4 1260 L IBTM__ insulated 4W, - --- . . Completion Details 0 -114 Top Depth (N0) Top Incl Top (ftKB) (ftKB) (*) Item Description Comment ID (in) - 31.2 31.2 0.00 HANGER FMC Gen V Tubing Hanger 3.958 NIPPLE, 2,273 2,272.9 1,887.3 60 47 NIPPLE Cameo Nipple wJ DB Profile 3.812" ID 3.812 � ti 1 2,897.4 6,977.8 64.41 PACKER Baker 4 1/2" X 7" Premier Packer 3.875 ?' 13,140.9 7,078.6 66.98 PACKERS Baker 4 1/2" X 7" Premier Packer 3.875 I ' 13,201.5 7,102.1 66.35 NIPPLE �HES XN Nipple 3.725 SURFACE, 13.255.7 7.123.$ 66.59 SHOE Mule Shoe 3.8D(I75 0 - 3.276 .... — _. __. — _ - - Other In Hole (Wi reline retrievable p lugs, valves, p umps, fish, etc.) Top Depth T Top Comment R Date I � PLR 1 KB P -.. _....�.__ WHIPSTOCK - ANCHOR BILLE I 10/4/2009 0.000 GAS LIFT, _ 0 14,264 7 84.25 WHIPSTOCK a _ -_ 2.708 Notes: General Safety „5 '% ,,, I .. End Date Annotation 11.3/2009 NOTE: VIEW SCHEMATIC W /Alaska Schematic9.0 PACKER, 12,697 PACKERS, 13,141 b. t/ NIPPLE, 13,201 SHOE, 13,256 -- Mandrel Details Top Depth Top 1 Port ('VD) Intl 1 OD Valve Latch Size TRO Run Stn To _MKS) (ftKB) (°l I Make _.,. Yodel (in) Sery TYPn Typo On/ (psi) Run Date Corn... 1 12,786 2' 6,929.5 64 19 CAMCO KBG-2 1 GAS LIFT OV BEK 0.250 0.0 10/19/2009 WHIPSTOCK, e . , 1 ' — _ __ _.:.:_. _. „„,,,,,,,..„ _ .x. 14,264 l.., • PRODUCTION, 0- 14,331 e OPEN HOLE A, 14,264- 21,001 TD(CD2- 60A).� w'Sd 21,001 , • • r- ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad CD2 -60A 501032051101 Sperry Drilling Services Definitive Survey Report 22 October, 2009 4 :; ?: i HALLIBURTON init , 1 Sperry Drilling Services (D0 • S ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co - ordinate Reference: Well CD2 -60 Project Western North Slope TVD Reference: CD2 -60A (15.9 +36.54) @ 52.44ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: ? CD2 -60A (15.9 +36.54) @ 52.44ft (Doyon 19) Well : CD2 - 60 North Reference: True Wellbore: CD2 -60A Survey Calculation. Method: Minimum Curvature Design: CD2 -60A Database: CPAI EDM Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD2 - 60 Well Position +N /-S 0.00 ft Northing: 5,973,941.18ft Latitude: 70° 20' 14.646 N +E / -W 0.00 ft Easting: 1,511,776.53ft Longitude: 151° 2' 37.792 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.90ft Welibore CD2 - 60A Magnetics : Model Name : Sample Date Declination Dip Angle - . Field Strength BGGM2007 10/29/2009 21.29 80.71 57,621 ■ Design CD2 - 60A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 14,255.10 Vertical Section: ' Depth From (TVD) +N/-S +E/-W Direction - ;! (ft1 (ft) (ft) r) 36.54 0.00 0.00 150.00 Survey Program Date 10/21/2009 From To (ft) (ft) Survey (Weilbore) Tool Name Description Survey Date 84.07 617.07 CD2 -60 gyro (CD2- 6OPB1) CB- GYRO -SS Camera based gyro single shot 6/17/2005 1: 744.25 11,756.11 CD2 -60PB1 (CD2- 6OPB1) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 6/17/2005 t 11,756.11 14,255.10 CD2 -60 (CD2 -60) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 7/6/2005 12: 14,264.00 20,921.80 CD2 -60A (CD2 -60A) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 10/7/2009 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( (ft) Survey Tool Name 36.54 0.00 0.00 36.54 -15.90 0.00 0.00 5,973,941.18 1,511,776.53 0.00 0.00 UNDEFINED 84.07 0.00 0.00 84.07 31.63 0.00 0.00 5,973,941.18 1,511,776.53 0.00 0.00 CB- GYRO -SS (1) 168.07 0.80 184.00 168.07 115.63 -0.58 -0.04 5,973,940.60 1,511,776.47 0.95 0.49 CB- GYRO -SS (1) 258.07 3.30 185.00 258.00 205.56 -3.79 -0.31 5,973,937.40 1,511,776.15 2.78 3.13 CB- GYRO -SS (1) 347.07 6.00 193.00 346.70 294.26 -10.88 -1.58 5,973,930.34 1,511,774.76 3.11 8.63 CB- GYRO -SS (1) 438.07 9.00 193.00 436.91 384.47 -22.45 -4.25 5,973,918.81 1,511,771.89 3.30 17.32 CB- GYRO -SS (1) 528.07 11.50 182.00 525.48 473.04 -38.28 -6.15 5,973,903.02 1,511,769.72 3.52 30.08 CB- GYRO -SS (1) 617.07 14.50 182.00 612.19 559.75 -58.29 -6.85 5,973,883.03 1,511,768.68 3.37 47.05 CB- GYRO -SS (1) 744.25 16.88 188.22 734.63 682.19 -92.48 -10.04 5,973,848.90 1,511,764.90 2.29 75.07 MWD +IFR -AK- CAZ -SC (2) 834.09 17.19 196.26 820.54 768.10 - 118.14 -15.63 5,973,823.34 1,511,758.88 2.64 94.50 MWD +IFR -AK- CAZ -SC (2) 929.14 20.23 195.79 910.56 858.12 - 147.44 -24.03 5,973,794.19 1,511,749.97 3.20 115.67 MWD +IFR -AK- CAZ -SC (2) 10/22/2009 9:38:24AM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co - ordinate Reference: Well CD2 -60 Project Western North Slope TVD Reference: ! CD2 -60A (15.9 +36.54) @ 52.44ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Well: CD2 - 60 North Reference: True Wellbore: CD2 - 60A Survey Calculation Method: Minimum Curvature Design: CD2 - 60A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +NI-S +E!-W Northing Easting DLS Section (ft) r) C) (ft) (ft) (ft) (ft) (ft) (ft) (°!100') (ft) Survey Tool Name 1,024.16 23.34 196.52 998.78 946.34 - 181.30 -33.86 5,973,760.50 1,511,739.56 3.29 140.09 MWD +IFR -AK- CAZ -SC (2) 1,119.29 28.42 193.77 1,084.34 1,031.90 - 221.39 -44.61 5,973,720.61 1,511,728.12 5.49 169.42 MWD +IFR -AK- CAZ -SC (2) 1,213.24 32.65 194.09 1,165.25 1,112.81 - 267.70 -56.11 5,973,674.51 1,511,715.84 4.51 203.78 MWD +IFR -AK- CAZ -SC (2) 1,309.22 34.10 194.48 1,245.40 1,192.96 - 318.87 -69.14 5,973,623.58 1,511,701.93 1.53 241.58 MWD +IFR -AK- CAZ -SC (2) 1,404.71 35.80 195.38 1,323.66 1,271.22 - 371.72 -83.24 5,973,570.98 1,511,686.93 1.86 280.30 MWD +IFR -AK- CAZ -SC (2) 1,500.53 38.34 195.36 1,400.11 1,347.67 - 427.41 -98.55 5,973,515.57 1,511,670.67 2.65 320.87 MWD +IFR -AK- CAZ -SC (2) 1,595.97 41.37 195.22 1,473.37 1,420.93 - 486.40 - 114.67 5,973,456.86 1,511,653.53 3.18 363.90 MWD +IFR -AK- CAZ -SC (2) 1,690.65 44.57 193.39 1,542.64 1,490.20 - 548.93 - 130.59 5,973,394.62 1,511,636.55 3.63 410.09 MWD +IFR -AK- CAZ -SC (2) 1,785.98 49.02 193.45 1,607.89 1,555.45 - 616.50 - 146.71 5,973,327.34 1,511,619.27 4.67 460.55 MWD +IFR -AK- CAZ -SC (2) 1,881.27 51.93 192.89 1,668.53 1,616.09 - 688.06 - 163.45 5,973,256.08 1,511,601.31 3.09 514.15 MWD +IFR -AK- CAZ -SC (2) 1,976.70 53.12 192.87 1,726.59 1,674.15 - 761.89 - 180.33 5,973,182.56 1,511,583.17 1.25 569.65 MWD +IFR -AK- CAZ -SC (2) 2,071.95 55.82 192.29 1,781.93 1,729.49 - 837.54 - 197.20 5,973,107.22 1,511,565.00 2.88 626.73 MWD +IFR -AK- CAZ -SC (2) 2,166.23 58.31 192.91 1,833.19 1,780.75 - 914.75 - 214.47 5,973,030.32 1,511,546.41 2.70 684.96 MWD +IFR -AK- CAZ -SC (2) 2,261.85 60.53 193.49 1,881.83 1,829.39 - 994.89 - 233.27 5,972,950.52 1,511,526.24 2.38 744.97 MWD +IFR -AK- CAZ -SC (2) 2,357.29 60.01 192.35 1,929.16 1,876.72 - 1,075.67 - 251.80 5,972,870.08 1,511,506.33 1.17 805.65 MWD +IFR -AK- CAZ -SC (2) 2,452.68 59.31 192.59 1,977.35 1,924.91 - 1,156.05 - 269.58 5,972,790.02 1,511,487.18 0.77 866.38 MWD +IFR -AK- CAZ -SC (2) 2,544.14 60.49 193.57 2,023.21 1,970.77 - 1,233.12 - 287.49 5,972,713.28 1,511,467.95 1.59 924.17 MWD +IFR -AK- CAZ -SC (2) 2,642.47 62.13 194.08 2,070.42 2,017.98 - 1,316.88 - 308.10 5,972,629.89 1,511,445.90 1.73 986.40 MWD +IFR -AK- CAZ -SC (2) 2,737.61 62.12 193.93 2,114.90 2,062.46 - 1,398.48 - 328.46 5,972,548.66 1,511,424.15 0.14 1,046.89 MWD +IFR -AK- CAZ -SC (2) 2,833.34 61.21 193.57 2,160.34 2,107.90 - 1,480.32 - 348.49 5,972,467.18 1,511,402.73 1.01 1,107.75 MWD +IFR -AK- CAZ -SC (2) 2,928.07 60.04 194.01 2,206.80 2,154.36 - 1,560.49 - 368.16 5,972,387.36 1,511,381.68 1.30 1,167.34 MWD +IFR -AK- CAZ -SC (2) 3,023.13 60.61 194.07 2,253.87 2,201.43 - 1,640.62 - 388.20 5,972,307.60 1,511,360.27 0.60 1,226.72 MWD +IFR -AK- CAZ -SC (2) 3,118.31 62.14 193.67 2,299.46 2,247.02 - 1,721.72 - 408.22 5,972,226.86 1,511,338.86 1.65 1,286.95 MWD +IFR -AK- CAZ -SC (2) 3,213.28 62.17 193.22 2,343.82 2,291.38 - 1,803.40 - 427.75 5,972,145.54 1,511,317.94 0.42 1,347.91 MWD +IFR -AK- CAZ -SC (2) 3,288.91 62.34 193.34 2,379.03 2,326.59 - 1,868.54 - 443.12 5,972,080.67 1,511,301.45 0.27 1,396.64 MWD +IFR -AK- CAZ -SC (2) 3,383.64 61.69 193.88 2,423.48 2,371.04 - 1,949.84 - 462.81 5,971,999.72 1,511,280.38 0.85 1,457.21 MWD +IFR -AK- CAZ -SC (2) 3,479.25 61.27 194.32 2,469.13 2,416.69 - 2,031.32 - 483.27 5,971,918.62 1,511,258.52 0.60 1,517.54 MWD +IFR -AK- CAZ -SC (2) 3,574.02 60.70 194.58 2,515.10 2,462.66 - 2,111.57 - 503.95 5,971,838.74 1,511,236.47 0.65 1,576.70 MWD +IFR -AK- CAZ -SC (2) 3,669.27 60.40 194.02 2,561.93 2,509.49 - 2,191.95 - 524.44 5,971,758.73 1,511,214.61 0.60 1,636.06 MWD +IFR -AK- CAZ -SC (2) 3,764.58 59.64 194.54 2,609.56 2,557.12 - 2,271.95 - 544.80 5,971,679.10 1,511,192.88 0.93 1,695.17 MWD +IFR -AK- CAZ -SC (2) 3,859.79 59.10 195.25 2,658.06 2,605.62 - 2,351.12 - 565.86 5,971,600.30 1,511,170.47 0.86 1,753.21 MWD +IFR -AK- CAZ -SC (2) 3,954.81 58.46 194.94 2,707.32 2,654.88 - 2,429.58 - 587.02 5,971,522.23 1,511,147.96 0.73 1,810.57 MWD +IFR -AK- CAZ -SC (2) 4,050.19 57.59 195.67 2,757.82 2,705.38 - 2,507.62 - 608.37 5,971,444.57 1,511,125.27 1.12 1,867.47 MWD +IFR -AK- CAZ -SC (2) 4,145.55 56.61 196.45 2,809.62 2,757.18 - 2,584.56 - 630.52 5,971,368.03 1,511,101.81 1.24 1,923.03 MWD +IFR -AK- CAZ -SC (2) 4,239.29 57.48 196.34 2,860.61 2,808.17 - 2,660.02 - 652.72 5,971,292.97 1,511,078.32 0.93 1,977.28 MWD +IFR -AK- CAZ -SC (2) 4,333.95 58.25 196.82 2,910.96 2,858.52 - 2,736.84 - 675.59 5,971,216.56 1,511,054.14 0.92 2,032.38 MWD +IFR -AK- CAZ -SC (2) 4,429.60 58.12 197.20 2,961.39 2,908.95 - 2,814.56 - 699.37 5,971,139.26 1,511,029.03 0.36 2,087.80 MWD +IFR -AK- CAZ -SC (2) 4,524.54 57.69 196.90 3,011.83 2,959.39 - 2,891.46 - 722.95 5,971,062.79 1,511,004.13 0.53 2,142.60 MWD +IFR -AK- CAZ -SC (2) 4,621.13 58.40 198.15 3,062.95 3,010.51 - 2,969.60 - 747.63 5,970,985.08 1,510,978.12 1.32 2,197.93 MWD +IFR -AK- CAZ -SC (2) 4,718.02 60.41 196.99 3,112.27 3,059.83 - 3,049.11 - 772.80 5,970,906.03 1,510,951.60 2.32 2,254.21 MWD +IFR -AK- CAZ -SC (2) 10/22/2009 9:38:24AM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: '; ConocoPhillips(Alaska) Inc. -WNS Local Co - ordinate Reference: Well CD2 -60 Project Western North Slope TVD Reference: ! CD2 -60A (15.9 +36.54) @ 52.44ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: ! CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Well: CD2 - 60 North Reference: True w ®nrmre CD2 -60A Survey Calculation Method: Minimum Curvature Design: CD2 -60A Database: CPAI EDM Production s .. Survey Map: Map Vertical MD Inc Az.I TVD TVDSS +N -S +FJ-W Northing Fasting ! DLS Section (ft) ,. r) (1 (ft) (ft) (f) (ft) (ft) (ft) (° /100') (ft) } Survey Too Na me , , , , , - 796.40 5,970,828.05 1,510,926.65 0.80 2,310.30 MWD +IFR -AK- CAZ -SC 2 4,811.88 61.04 196.52 3,158.17 3,105.73 - 3,127.51 ( ) 4,907.24 61.28 197.33 3,204.16 3,151.72 - 3,207.42 - 820.72 5,970,748.57 1,510,900.97 0.79 2,367.35 MWD +IFR -AK- CAZ -SC (2) 5,002.41 61.42 196.66 3,249.79 3,197.35 - 3,287.29 - 845.13 5,970,669.14 1,510,875.20 0.64 2,424.31 MWD +IFR -AK- CAZ -SC (2) 5,096.96 61.96 196.77 3,294.63 3,242.19 - 3,367.01 - 869.07 5,970,589.85 1,510,849.89 0.58 2,481.38 MWD +IFR -AK- CAZ -SC (2) 5,191.89 62.31 196.54 3,339.00 3,286.56 - 3,447.42 - 893.13 5,970,509.88 1,510,824.47 0.43 2,538.99 MWD +IFR -AK- CAZ -SC (2) 5,287.09 62.88 196.92 3,382.82 3,330.38 - 3,528.35 - 917.45 5,970,429.37 1,510,798.75 0.70 2,596.92 MWD +IFR -AK- CAZ -SC (2) 5,382.18 63.22 196.24 3,425.92 3,373.48 - 3,609.59 - 941.64 5,970,348.57 1,510,773.18 0.73 2,655.18 MWD +IFR -AK- CAZ -SC (2) 5,477.25 63.78 195.78 3,468.34 3,415.90 - 3,691.37 - 965.11 5,970,267.21 1,510,748.32 0.73 2,714.27 MWD +IFR -AK- CAZ -SC (2) 5,571.98 63.95 195.40 3,510.07 3,457.63 - 3,773.29 - 987.96 5,970,185.70 1,510,724.06 0.40 2,773.78 MWD +IFR -AK- CAZ -SC (2) 5,667.44 64.30 194.85 3,551.73 3,499.29 - 3,856.20 - 1,010.37 5,970,103.19 1,510,700.23 0.63 2,834.38 MWD +IFR -AK- CAZ -SC (2) 5,762.36 64.06 194.14 3,593.07 3,540.63 - 3,938.93 - 1,031.76 5,970,020.86 1,510,677.43 0.72 2,895.33 MWD +IFR -AK- CAZ -SC (2) 5,857.27 65.20 194.38 3,633.73 3,581.29 - 4,022.04 - 1,052.88 5,969,938.12 1,510,654.89 1.22 2,956.75 MWD +IFR -AK- CAZ -SC (2) 5,952.31 64.25 193.32 3,674.31 3,621.87 - 4,105.48 - 1,073.46 5,969,855.06 1,510,632.89 1.42 3,018.72 MWD +IFR -AK- CAZ -SC (2) 6,045.10 64.38 192.58 3,714.53 3,662.09 - 4,186.97 - 1,092.20 5,969,773.90 1,510,612.75 0.73 3,079.93 MWD +IFR -AK- CAZ -SC (2) 6,142.23 63.63 191.76 3,757.10 3,704.66 - 4,272.31 - 1,110.60 5,969,688.90 1,510,592.89 1.08 3,144.63 MWD +IFR -AK- CAZ -SC (2) 6,238.13 62.05 190.14 3,800.88 3,748.44 - 4,356.08 - 1,126.82 5,969,605.43 1,510,575.24 2.23 3,209.06 MWD +IFR -AK- CAZ -SC (2) 6,332.53 60.90 189.01 3,845.96 3,793.52 - 4,437.86 - 1,140.62 5,969,523.91 1,510,560.04 1.61 3,272.99 MWD +IFR -AK- CAZ -SC (2) 6,428.50 61.18 190.14 3,892.43 3,839.99 - 4,520.66 - 1,154.59 5,969,441.37 1,510,544.65 1.07 3,337.71 MWD +IFR -AK- CAZ -SC (2) 6,523.39 60.89 190.31 3,938.38 3,885.94 - 4,602.36 - 1,169.32 5,969,359.94 1,510,528.52 0.34 3,401.10 MWD +IFR -AK- CAZ -SC (2) 6,618.34 61.19 190.97 3,984.36 3,931.92 - 4,684.01 - 1,184.66 5,969,278.57 1,510,511.78 0.69 3,464.14 MWD +IFR -AK- CAZ -SC (2) 6,713.43 60.97 191.52 4,030.34 3,977.90 - 4,765.64 - 1,200.89 5,969,197.23 1,510,494.15 0.56 3,526.72 MWD +IFR -AK- CAZ -SC (2) 6,808.91 61.00 192.84 4,076.65 4,024.21 - 4,847.25 - 1,218.51 5,969,115.94 1,510,475.14 1.21 3,588.59 MWD +IFR -AK- CAZ -SC (2) 6,901.14 61.09 192.48 4,121.30 4,068.86 - 4,925.99 - 1,236.20 5,969,037.52 1,510,456.11 0.36 3,647.94 MWD +IFR -AK- CAZ -SC (2) 6,999.30 61.27 193.85 4,168.62 4,116.18 - 5,009.73 - 1,255.78 5,968,954.14 1,510,435.09 1.24 3,710.66 MWD +IFR -AK- CAZ -SC (2) 7,095.04 61.53 194.69 4,214.46 4,162.02 - 5,091.19 - 1,276.50 5,968,873.05 1,510,412.98 0.82 3,770.85 MWD +IFR -AK- CAZ -SC (2) 7,190.27 61.88 194.56 4,259.60 4,207.16 - 5,172.33 - 1,297.68 5,968,792.30 1,510,390.42 0.39 3,830.53 MWD +IFR -AK- CAZ -SC (2) 7,284.95 62.61 194.16 4,303.69 4,251.25 - 5,253.50 - 1,318.45 5,968,711.50 1,510,368.25 0.86 3,890.44 MWD +IFR -AK- CAZ -SC (2) 7,380.50 62.87 194.25 4,347.45 4,295.01 - 5,335.84 - 1,339.30 5,968,629.54 1,510,346.00 0.28 3,951.32 MWD +IFR -AK- CAZ -SC (2) 7,475.81 62.61 192.79 4,391.11 4,338.67 - 5,418.21 - 1,359.11 5,968,547.52 1,510,324.78 1.39 4,012.76 MWD +IFR -AK- CAZ -SC (2) 7,571.24 62.66 191.42 4,434.97 4,382.53 - 5,501.08 - 1,376.88 5,968,464.98 1,510,305.60 1.28 4,075.63 MWD +IFR -AK- CAZ -SC (2) 7,666.18 63.15 190.78 4,478.22 4,425.78 - 5,584.01 - 1,393.15 5,968,382.34 1,510,287.91 0.79 4,139.32 MWD +IFR -AK- CAZ -SC (2) 7,762.19 63.35 191.01 4,521.43 4,468.99 - 5,668.20 - 1,409.35 5,968,298.45 1,510,270.26 0.30 4,204.13 MWD +IFR -AK- CAZ -SC (2) 7,856.79 61.86 189.47 4,564.96 4,512.52 - 5,750.85 - 1,424.29 5,968,216.08 1,510,253.91 2.14 4,268.24 MWD +IFR -AK- CAZ -SC (2) 7,949.65 60.96 189.76 4,609.40 4,556.96 - 5,831.24 - 1,437.91 5,968,135.94 1,510,238.91 1.01 4,331.05 MWD +IFR -AK- CAZ -SC (2) 8,046.92 59.61 189.33 4,657.61 4,605.17 - 5,914.55 - 1,451.92 5,968,052.89 1,510,223.48 1.44 4,396.19 MWD +IFR -AK- CAZ -SC (2) 8,142.13 58.53 188.98 4,706.55 4,654.11 - 5,995.18 - 1,464.91 5,967,972.51 1,510,209.10 1.18 4,459.52 MWD +IFR -AK- CAZ -SC (2) 8,237.25 58.33 189.35 4,756.35 4,703.91 - 6,075.18 - 1,477.82 5,967,892.74 1,510,194.82 0.39 4,522.35 MWD +IFR -AK- CAZ -SC (2) 8,330.57 58.48 189.85 4,805.24 4,752.80 - 6,153.56 - 1,491.08 5,967,814.61 1,510,180.23 0.48 4,583.60 MWD +IFR -AK- CAZ -SC (2) 8,427.35 59.12 190.13 4,855.37 4,802.93 - 6,235.08 - 1,505.44 5,967,733.35 1,510,164.47 0.71 4,647.02 MWD +IFR -AK- CAZ -SC (2) 8,522.35 59.78 189.71 4,903.66 4,851.22 - 6,315.67 - 1,519.53 5,967,653.02 1,510,149.00 0.79 4,709.77 MWD +IFR -AK- CAZ -SC (2) 10/22/2009 9 :38 :24AM Page 4 COMPASS 2003.16 Build 69 • . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -INNS Local Co - ordinate Reference: Well CD2 -60 Project .. Western North Slope TVD Reference: CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: ! CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Well: CD2 - 60 North Reference: True Wellbore: _ " CD2 - 60A Survey Calculation Method: ' Minimum Curvature Design: CD2 - 60A Database:. CPAI EDM Production Survey Map . Map Vertical MD Inc Azi . TVD TVDSS +N/-S +E!-W Northing Easting. ', - DLS . Section (ft) r) (°1 (ft) (1» (ft) (ft) (ft) (ft) ( °l1�'l ` (ft) Survey Tool Name 8,616.36 59.84 188.80 4,950.94 4,898.50 - 6,395.87 - 1,532.60 5,967,573.06 1,510,134.56 0.84 4,772.69 MWD +IFR -AK- CAZ -SC (2) 8,712.63 60.14 189.41 4,999.09 4,946.65 - 6,478.19 - 1,545.79 5,967,490.99 1,510,119.96 0.63 4,837.38 MWD +IFR -AK- CAZ -SC (2) 8,806.04 60.56 188.99 5,045.30 4,992.86 - 6,558.32 - 1,558.77 5,967,411.10 1,510,105.61 0.60 4,900.29 MWD +IFR -AK- CAZ -SC (2) 8,902.89 60.99 189.16 5,092.58 5,040.14 - 6,641.78 - 1,572.10 5,967,327.89 1,510,090.85 0.47 4,965.90 MWD +IFR -AK- CAZ -SC (2) 8,998.21 61.47 188.88 5,138.46 5,086.02 - 6,724.30 - 1,585.20 5,967,245.61 1,510,076.33 0.57 5,030.82 MWD +IFR -AK- CAZ -SC (2) 9,092.87 61.97 188.64 5,183.31 5,130.87 - 6,806.69 - 1,597.90 5,967,163.46 1,510,062.23 0.57 5,095.82 MWD +IFR -AK- CAZ -SC (2) 9,187.91 61.60 189.39 5,228.24 5,175.80 - 6,889.40 - 1,611.02 5,967,080.99 1,510,047.69 0.80 5,160.89 MWD +IFR -AK- CAZ -SC (2) 9,283.33 61.19 189.96 5,273.92 5,221.48 - 6,971.99 - 1,625.10 5,966,998.67 1,510,032.20 0.68 5,225.37 MWD +IFR -AK- CAZ -SC (2) 9,378.67 61.47 192.05 5,319.67 5,267.23 - 7,054.09 - 1,641.07 5,966,916.85 1,510,014.83 1.95 5,288.49 MWD +IFR -AK- CAZ -SC (2) 9,474.14 62.10 192.86 5,364.81 5,312.37 - 7,136.24 - 1,659.21 5,966,835.04 1,509,995.28 1.00 5,350.56 MWD +IFR -AK- CAZ -SC (2) 9,568.38 62.10 193.10 5,408.90 5,356.46 - 7,217.39 - 1,677.92 5,966,754.22 1,509,975.18 0.23 5,411.49 MWD +IFR -AK- CAZ -SC (2) 9,672.04 61.25 193.83 5,458.09 5,405.65 - 7,306.13 - 1,699.16 5,966,665.87 1,509,952.42 1.03 5,477.72 MWD +IFR -AK- CAZ -SC (2) 9,759.44 60.98 193.98 5,500.31 5,447.87 - 7,380.42 - 1,717.55 5,966,591.92 1,509,932.76 0.34 5,532.85 MWD +IFR -AK- CAZ -SC (2) 9,854.82 61.26 194.25 5,546.37 5,493.93 - 7,461.41 - 1,737.92 5,966,511.29 1,509,911.01 0.38 5,592.81 MWD +IFR -AK- CAZ -SC (2) 9,949.54 61.67 194.58 5,591.62 5,539.18 - 7,542.01 - 1,758.64 5,966,431.07 1,509,888.91 0.53 5,652.25 MWD +IFR -AK- CAZ -SC (2) 10,045.16 60.57 194.12 5,637.80 5,585.36 - 7,623.12 - 1,779.39 5,966,350.33 1,509,866.77 1.23 5,712.12 MWD +IFR -AK- CAZ -SC (2) 10,139.79 60.48 191.52 5,684.37 5,631.93 - 7,703.44 - 1,797.67 5,966,270.34 1,509,847.12 2.39 5,772.54 MWD +IFR -AK- CAZ -SC (2) 10,234.63 60.76 191.18 5,730.90 5,678.46 - 7,784.47 - 1,813.93 5,966,189.61 1,509,829.47 0.43 5,834.58 MWD +IFR -AK- CAZ -SC (2) 10,329.71 61.09 190.89 5,777.10 5,724.66 - 7,866.03 - 1,829.84 5,966,108.34 1,509,812.17 0.44 5,897.26 MWD +IFR -AK- CAZ -SC (2) 10,425.32 61.43 191.65 5,823.08 5,770.64 - 7,948.24 - 1,846.22 5,966,026.43 1,509,794.38 0.78 5,960.27 MWD +IFR -AK- CAZ -SC (2) 10,520.40 61.93 191.82 5,868.18 5,815.74 - 8,030.19 - 1,863.24 5,965,944.79 1,509,775.95 0.55 6,022.73 MWD +IFR -AK- CAZ -SC (2) 10,615.88 61.96 192.53 5,913.09 5,860.65 - 8,112.56 - 1,881.02 5,965,862.75 1,509,756.77 0.66 6,085.17 MWD +IFR -AK- CAZ -SC (2) 10,711.07 62.05 192.87 5,957.77 5,905.33 - 8,194.55 - 1,899.49 5,965,781.09 1,509,736.89 0.33 6,146.94 MWD +IFR -AK- CAZ -SC (2) 10,806.40 62.37 193.98 6,002.22 5,949.78 - 8,276.58 - 1,919.07 5,965,699.42 1,509,715.91 1.08 6,208.19 MWD +IFR -AK- CAZ -SC (2) 10,901.48 62.65 194.31 6,046.10 5,993.66 - 8,358.37 - 1,939.69 5,965,618.00 1,509,693.90 0.43 6,268.71 MWD +IFR -AK- CAZ -SC (2) 10,996.42 63.15 194.20 6,089.35 6,036.91 - 8,440.28 - 1,960.50 5,965,536.46 1,509,671.69 0.54 6,329.25 MWD +IFR -AK- CAZ -SC (2) 11,092.18 63.43 194.20 6,132.40 6,079.96 - 8,523.21 - 1,981.48 5,965,453.91 1,509,649.29 0.29 6,390.57 MWD +IFR -AK- CAZ -SC (2) 11,184.90 63.06 194.34 6,174.14 6,121.70 - 8,603.45 - 2,001.89 5,965,374.04 1,509,627.51 0.42 6,449.86 MWD +IFR -AK- CAZ -SC (2) 11,280.24 62.37 194.30 6,217.84 6,165.40 - 8,685.55 - 2,022.85 5,965,292.32 1,509,605.15 0.72 6,510.48 MWD +IFR -AK- CAZ -SC (2) 11,375.49 61.62 192.82 6,262.57 6,210.13 - 8,767.29 - 2,042.57 5,965,210.93 1,509,584.03 1.58 6,571.42 MWD +IFR -AK- CAZ -SC (2) 11,470.59 61.21 192.48 6,308.07 6,255.63 - 8,848.77 - 2,060.86 5,965,129.78 1,509,564.35 0.53 6,632.84 MWD +IFR -AK- CAZ -SC (2) 11,565.39 60.80 192.07 6,354.02 6,301.58 - 8,929.80 - 2,078.48 5,965,049.08 1,509,545.33 0.57 6,694.19 MWD +IFR -AK- CAZ -SC (2) 11,660.82 60.39 192.53 6,400.88 6,348.44 - 9,011.02 - 2,096.19 5,964,968.18 1,509,526.23 0.60 6,755.68 MWD +IFR -AK- CAZ -SC (2) 11,756.11 59.73 193.55 6,448.44 6,396.00 - 9,091.47 - 2,114.82 5,964,888.07 1,509,506.23 1.16 6,816.03 MWD +IFR -AK- CAZ -SC (2) 11,760.07 59.72 193.53 6,450.43 6,397.99 - 9,094.79 - 2,115.62 5,964,884.76 1,509,505.37 0.50 6,818.51 MWD +IFR -AK- CAZ -SC (3) 11,784.88 59.43 195.34 6,463.00 6,410.56 - 9,115.51 - 2,120.96 5,964,864.14 1,509,499.68 6.40 6,833.78 MWD +IFR -AK- CAZ -SC (3) 11,816.72 59.89 196.85 6,479.08 6,426.64 - 9,141.91 - 2,128.57 5,964,837.88 1,509,491.61 4.34 6,852.84 MWD +IFR -AK- CAZ -SC (3) 11,860.21 60.32 197.58 6,500.76 6,448.32 - 9,177.92 - 2,139.73 5,964,802.06 1,509,479.84 1.76 6,878.45 MWD +IFR -AK- CAZ -SC (3) 11,912.42 60.60 197.43 6,526.50 6,474.06 - 9,221.24 - 2,153.40 5,964,758.99 1,509,465.44 0.59 6,909.13 MWD +IFR -AK- CAZ -SC (3) 11,957.19 61.08 197.28 6,548.31 6,495.87 - 9,258.56 - 2,165.06 5,964,721.88 1,509,453.14 1.11 6,935.62 MWD +IFR -AK- CAZ -SC (3) 10/22/2009 9:38:24AM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co - ordinate Reference: Well CD2 -60 Project Western North Slope TVD Reference: ? CD2 -60A (15.9 +36.54) @ 52.44ft (Doyon 19) Site CD2 Alpine Pad MD Reference: CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Well: CD2 - 60 North Reference: True Wel'bore: CD2 - 60A Survey Calculation Method: > Minimum Curvature Design: ' ' CD2 -60A Database: CPAI EDM Production Survey Map Map > Vertical Inc Azi TVD TVDSS +N -S +E!-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) - (ft) (ft) (ft) (ft) ( (ft) Survey Tool Name 12,006.81 62.72 198.81 6,571.68 6,519.24 - 9,300.17 - 2,178.62 5,964,680.51 1,509,438.87 4.28 6,964.88 MWD +IFR -AK- CAZ -SC (3) 12,102.03 62.44 198.97 6,615.53 6,563.09 - 9,380.14 - 2,205.98 5,964,601.03 1,509,410.14 0.33 7,020.45 MWD +IFR -AK- CAZ -SC (3) 12,197.29 63.21 199.73 6,659.04 6,606.60 - 9,460.10 - 2,234.06 5,964,521.57 1,509,380.69 1.08 7,075.65 MWD +IFR -AK- CAZ -SC (3) 12,292.21 62.75 199.26 6,702.16 6,649.72 - 9,539.81 - 2,262.28 5,964,442.36 1,509,351.11 0.66 7,130.57 MWD +IFR -AK- CAZ -SC (3) 12,386.82 61.79 200.03 6,746.18 6,693.74 - 9,618.68 - 2,290.43 5,964,363.99 1,509,321.61 1.24 7,184.80 MWD +IFR -AK- CAZ -SC (3) 12,481.98 62.75 197.55 6,790.47 6,738.03 - 9,698.41 - 2,317.55 5,964,284.74 1,509,293.13 2.52 7,240.29 MWD +IFR -AK- CAZ -SC (3) 12,577.30 62.29 195.87 6,834.45 6,782.01 - 9,779.40 - 2,341.87 5,964,204.19 1,509,267.43 1.64 7,298.27 MWD +IFR -AK- CAZ -SC (3) 12,672.62 63.42 193.14 6,877.95 6,825.51 - 9,861.51 - 2,363.10 5,964,122.47 1,509,244.80 2.81 7,358.77 MWD +IFR -AK- CAZ -SC (3) 12,767.69 63.10 188.16 6,920.75 6,868.31 - 9,944.91 - 2,378.79 5,964,039.35 1,509,227.68 4.69 7,423.15 MWD +IFR -AK- CAZ -SC (3) 12,862.36 64.34 183.72 6,962.68 6,910.24 - 10,029.31 - 2,387.56 5,963,955.12 1,509,217.47 4.40 7,491.86 MWD +IFR -AK- CAZ -SC (3) 12,957.70 64.53 180.83 7,003.83 6,951.39 - 10,115.24 - 2,390.97 5,963,869.27 1,509,212.58 2.74 7,564.57 MWD +IFR -AK- CAZ -SC (3) 13,053.08 66.13 182.25 7,043.64 6,991.20 - 10,201.87 - 2,393.30 5,963,782.70 1,509,208.76 2.16 7,638.43 MWD +IFR -AK- CAZ -SC (3) 13,148.37 67.05 182.53 7,081.50 7,029.06 - 10,289.24 - 2,396.95 5,963,695.41 1,509,203.62 1.00 7,712.27 MWD +IFR -AK- CAZ -SC (3) 13,243.86 66.54 181.86 7,119.12 7,066.68 - 10,376.94 - 2,400.31 5,963,607.79 1,509,198.75 0.84 7,786.54 MWD +IFR -AK- CAZ -SC (3) 13,288.87 66.74 181.40 7,136.97 7,084.53 - 10,418.25 - 2,401.49 5,963,566.51 1,509,196.87 1.04 7,821.72 MWD +IFR -AK- CAZ -SC (3) 13,339.40 66.93 178.89 7,156.85 7,104.41 - 10,464.70 - 2,401.60 5,963,520.07 1,509,195.95 4.58 7,861.89 MWD +IFR -AK- CAZ -SC (3) 13,385.10 67.46 177.92 7,174.57 7,122.13 - 10,506.81 - 2,400.43 5,963,477.95 1,509,196.40 2.27 7,898.95 MWD +IFR -AK- CAZ -SC (3) 13,434.59 68.24 175.83 7,193.23 7,140.79 - 10,552.57 - 2,397.93 5,963,432.16 1,509,198.12 4.22 7,939.83 MWD +IFR -AK- CAZ -SC (3) 13,479.63 69.55 173.71 7,209.45 7,157.01 - 10,594.41 - 2,394.10 5,963,390.26 1,509,201.23 5.27 7,977.98 MWD +IFR -AK- CAZ -SC (3) 13,529.74 71.05 171.98 7,226.34 7,173.90 - 10,641.22 - 2,388.22 5,963,343.36 1,509,206.31 4.42 8,021.46 MWD +IFR -AK- CAZ -SC (3) 13,575.22 72.19 171.09 7,240.68 7,188.24 - 10,683.91 - 2,381.86 5,963,300.58 1,509,211.93 3.12 8,061.60 MWD +IFR -AK- CAZ -SC (3) 13,625.06 73.52 168.48 7,255.37 7,202.93 - 10,730.77 - 2,373.42 5,963,253.58 1,509,219.57 5.67 8,106.41 MWD +IFR -AK- CAZ -SC (3) 13,670.51 74.73 167.38 7,267.81 7,215.37 - 10,773.52 - 2,364.27 5,963,210.68 1,509,227.98 3.54 8,148.00 MWD +IFR -AK- CAZ -SC (3) 13,720.25 75.32 166.34 7,280.66 7,228.22 - 10,820.31 - 2,353.35 5,963,163.71 1,509,238.10 2.34 8,193.99 MWD +IFR -AK- CAZ -SC (3) 13,765.73 76.16 165.17 7,291.86 7,239.42 - 10,863.03 - 2,342.50 5,963,120.82 1,509,248.21 3.10 8,236.41 MWD +IFR -AK- CAZ -SC (3) 13,815.30 77.42 163.86 7,303.19 7,250.75 - 10,909.54 - 2,329.62 5,963,074.10 1,509,260.29 3.62 8,283.13 MWD +IFR -AK- CAZ -SC (3) 13,860.04 77.97 162.30 7,312.72 7,260.28 - 10,951.35 - 2,316.90 5,963,032.07 1,509,272.30 3.62 8,325.70 MWD +IFR -AK- CAZ -SC (3) 13,910.81 78.83 160.66 7,322.93 7,270.49 - 10,998.51 - 2,301.10 5,962,984.66 1,509,287.28 3.59 8,374.44 MWD +IFR -AK- CAZ -SC (3) 13,958.21 79.45 159.34 7,331.86 7,279.42 - 11,042.25 - 2,285.18 5,962,940.65 1,509,302.45 3.03 8,420.28 MWD +IFR -AK- CAZ -SC (3) 14,005.99 80.69 158.42 7,340.10 7,287.66 - 11,086.15 - 2,268.22 5,962,896.47 1,509,318.65 3.21 8,466.78 MWD +IFR -AK- CAZ -SC (3) 14,051.40 82.15 157.03 7,346.88 7,294.44 - 11,127.70 - 2,251.20 5,962,854.64 1,509,334.95 4.42 8,511.27 MWD +IFR -AK- CAZ -SC (3) 14,101.28 82.45 155.21 7,353.56 7,301.12 - 11,172.90 - 2,231.19 5,962,809.11 1,509,354.18 3.67 8,560.42 MWD +IFR -AK- CAZ -SC (3) 14,148.74 82.57 153.80 7,359.75 7,307.31 - 11,215.37 - 2,210.93 5,962,766.30 1,509,373.70 2.96 8,607.33 MWD +IFR -AK- CAZ -SC (3) 14,196.18 83.38 152.19 7,365.55 7,313.11 - 11,257.32 - 2,189.56 5,962,724.00 1,509,394.36 3.78 8,654.35 MWD +IFR -AK- CAZ -SC (3) 14,255.10 83.97 150.35 7,372.04 7,319.60 - 11,308.67 - 2,161.41 5,962,672.18 1,509,421.62 3.26 8,712.89 MWD +IFR -AK- CAZ -SC (3) 14,264.00 84.25 150.12 7,372.96 7,320.52 - 11,316.35 - 2,157.01 5,962,664.42 1,509,425.88 4.06 8,721.74 MWD +IFR -AK- CAZ -SC (4) 14,306.40 85.24 150.30 7,376.84 7,324.40 - 11,352.99 - 2,136.04 5,962,627.42 1,509,446.22 2.37 8,763.96 MWD +IFR -AK- CAZ -SC (4) 14,366.68 85.05 150.55 7,381.94 7,329.50 - 11,405.23 - 2,106.39 5,962,574.69 1,509,474.97 0.52 8,824.03 MWD +IFR -AK- CAZ -SC (4) 14,467.35 85.66 150.97 7,390.09 7,337.65 - 11,492.79 - 2,057.38 5,962,486.32 1,509,522.47 0.73 8,924.36 MWD +IFR -AK- CAZ -SC (4) 14,561.26 85.85 152.20 7,397.05 7,344.61 - 11,575.15 - 2,012.81 5,962,403.20 1,509,565.61 1.32 9,017.97 MWD +IFR -AK- CAZ -SC (4) 10/22/2009 9:38:24AM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co- ordinate Reference: Well CD2 -60 Project Western North Slope TVD Reference: - CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: - CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Well: CD2 -60 North Reference: True Wellbore:- ," _ CD2 -60A Survey Calculation Method:. Minimum Curvature Design: CD2 -60A Database: CPAI EDM Production 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) ( °11W).:, - (ft) Surrey Tool Name 14,656.18 86.09 157.57 7,403.72 7,351.28 - 11,660.86 - 1,972.64 5,962,316.83 1,509,604.30 5.65 9,112.28 MWD +IFR -AK- CAZ -SC (4) 14,703.04 86.96 159.44 7,406.56 7,354.12 - 11,704.37 - 1,955.50 5,962,273.03 1,509,620.69 4.39 9,158.53 MWD +IFR -AK- CAZ -SC (4) 14,751.43 87.52 161.41 7,408.89 7,356.45 - 11,749.91 - 1,939.31 5,962,227.22 1,509,636.10 4.23 9,206.07 MWD +IFR -AK- CAZ -SC (4) 14,846.02 89.37 164.49 7,411.46 7,359.02 - 11,840.30 - 1,911.59 5,962,136.38 1,509,662.26 3.80 9,298.20 MWD +IFR -AK- CAZ -SC (4) 14,942.80 88.81 165.39 7,413.00 7,360.56 - 11,933.74 - 1,886.45 5,962,042.53 1,509,685.79 1.10 9,391.70 MWD +IFR -AK- CAZ -SC (4) 14,992.42 88.69 166.35 7,414.08 7,361.64 - 11,981.85 - 1,874.34 5,961,994.23 1,509,697.07 1.95 9,439.41 MWD +IFR -AK- CAZ -SC (4) 15,037.03 89.12 168.41 7,414.93 7,362.49 - 12,025.37 - 1,864.60 5,961,950.55 1,509,706.07 4.72 9,481.98 MWD +IFR -AK- CAZ -SC (4) 15,133.97 90.73 173.42 7,415.06 7,362.62 - 12,121.06 - 1,849.29 5,961,854.62 1,509,719.73 5.43 9,572.50 MWD +IFR -AK- CAZ -SC (4) 15,227.72 91.47 177.25 7,413.26 7,360.82 - 12,214.46 - 1,841.67 5,961,761.10 1,509,725.74 4.16 9,657.20 MWD +IFR -AK- CAZ -SC (4) 15,324.96 91.47 173.73 7,410.76 7,358.32 - 12,311.36 - 1,834.03 5,961,664.10 1,509,731.72 3.62 9,744.93 MWD +IFR -AK- CAZ -SC (4) 15,418.80 90.73 170.11 7,408.96 7,356.52 - 12,404.23 - 1,820.84 5,961,571.02 1,509,743.31 3.94 9,831.96 MWD +IFR -AK- CAZ -SC (4) 15,516.27 90.48 167.71 7,407.93 7,355.49 - 12,499.87 - 1,802.10 5,961,475.08 1,509,760.41 2.48 9,924.15 MWD +IFR -AK- CAZ -SC (4) 15,609.92 91.47 164.03 7,406.34 7,353.90 - 12,590.65 - 1,779.24 5,961,383.93 1,509,781.70 4.07 10,014.20 MWD +IFR -AK- CAZ -SC (4) 15,707.25 89.93 160.87 7,405.15 7,352.71 - 12,683.43 - 1,749.90 5,961,290.67 1,509,809.45 3.61 10,109.22 MWD +IFR -AK- CAZ -SC (4) 15,802.51 89.25 159.84 7,405.83 7,353.39 - 12,773.14 - 1,717.88 5,961,200.43 1,509,839.93 1.30 10,202.93 MWD +IFR -AK- CAZ -SC (4) 15,898.32 88.75 156.86 7,407.50 7,355.06 - 12,862.17 - 1,682.54 5,961,110.81 1,509,873.73 3.15 10,297.70 MWD +IFR -AK- CAZ -SC (4) 15,993.36 90.67 153.99 7,407.98 7,355.54 - 12,948.59 - 1,643.02 5,961,023.74 1,509,911.76 3.63 10,392.30 MWD +IFR -AK- CAZ -SC (4) 16,089.33 89.06 149.88 7,408.21 7,355.77 - 13,033.25 - 1,597.88 5,960,938.32 1,509,955.43 4.60 10,488.19 MWD +IFR -AK- CAZ -SC (4) 16,183.57 89.93 149.85 7,409.04 7,356.60 - 13,114.75 - 1,550.57 5,960,856.03 1,510,001.33 0.92 10,582.42 MWD +IFR -AK- CAZ -SC (4) 16,279.46 90.67 149.85 7,408.54 7,356.10 - 13,197.67 - 1,502.41 5,960,772.30 1,510,048.06 0.77 10,678.31 MWD +IFR -AK- CAZ -SC (4) 16,374.87 90.61 149.77 7,407.47 7,355.03 - 13,280.13 - 1,454.43 5,960,689.04 1,510,094.61 0.10 10,773.71 MWD +IFR -AK- CAZ -SC (4) 16,468.48 88.99 149.51 7,407.80 7,355.36 - 13,360.90 - 1,407.12 5,960,607.47 1,510,140.53 1.75 10,867.32 MWD +IFR -AK- CAZ -SC (4) 16,564.42 88.44 149.69 7,409.95 7,357.51 - 13,443.63 - 1,358.59 5,960,523.93 1,510,187.63 0.60 10,963.23 MWD +IFR -AK- CAZ -SC (4) 16,659.97 89.93 147.90 7,411.31 7,358.87 - 13,525.34 - 1,309.09 5,960,441.39 1,510,235.72 2.44 11,058.74 MWD +IFR -AK- CAZ -SC (4) 16,752.91 89.62 146.62 7,411.68 7,359.24 - 13,603.51 - 1,258.83 5,960,362.37 1,510,284.63 1.42 11,151.57 MWD +IFR -AK- CAZ -SC (4) 16,851.67 88.81 149.81 7,413.03 7,360.59 - 13,687.44 - 1,206.82 5,960,277.57 1,510,335.18 3.33 11,250.26 MWD +IFR -AK- CAZ -SC (4) 16,945.65 88.81 150.85 7,414.98 7,362.54 - 13,769.08 - 1,160.31 5,960,195.15 1,510,380.28 1.11 11,344.22 MWD +IFR -AK- CAZ -SC (4) 17,042.62 89.43 152.45 7,416.47 7,364.03 - 13,854.41 - 1,114.27 5,960,109.05 1,510,424.85 1.77 11,441.14 MWD +IFR -AK- CAZ -SC (4) 17,136.38 88.94 152.11 7,417.80 7,365.36 - 13,937.40 - 1,070.66 5,960,025.33 1,510,467.02 0.64 11,534.81 MWD +IFR -AK- CAZ -SC (4) 17,232.03 89.25 151.76 7,419.31 7,366.87 - 14,021.79 - 1,025.67 5,959,940.19 1,510,510.56 0.49 11,630.39 MWD +IFR -AK- CAZ -SC (4) 17,327.54 88.69 151.52 7,421.03 7,368.59 - 14,105.82 - 980.30 5,959,855.40 1,510,554.47 0.64 11,725.85 MWD +IFR -AK- CAZ -SC (4) 17,422.93 89.31 151.34 7,422.70 7,370.26 - 14,189.59 - 934.69 5,959,770.87 1,510,598.63 0.68 11,821.19 MWD +IFR -AK- CAZ -SC (4) 17,518.45 90.23 152.11 7,423.08 7,370.64 - 14,273.71 - 889.45 5,959,686.00 1,510,642.43 1.26 11,916.67 MWD +IFR -AK- CAZ -SC (4) 17,614.02 89.00 152.04 7,423.72 7,371.28 - 14,358.14 - 844.69 5,959,600.81 1,510,685.72 1.29 12,012.17 MWD +IFR -AK- CAZ -SC (4) 17,709.34 89.06 151.47 7,425.34 7,372.90 - 14,442.10 - 799.59 5,959,516.10 1,510,729.38 0.60 12,107.43 MWD +IFR -AK- CAZ -SC (4) 17,803.13 89.18 153.78 7,426.78 7,374.34 - 14,525.37 - 756.47 5,959,432.10 1,510,771.05 2.47 12,201.11 MWD +IFR -AK- CAZ -SC (4) 17,900.48 89.49 154.41 7,427.91 7,375.47 - 14,612.94 - 713.94 5,959,343.83 1,510,812.07 0.72 12,298.20 MWD +IFR -AK- CAZ -SC (4) 17,992.09 91.53 151.44 7,427.09 7,374.65 - 14,694.49 - 672.26 5,959,261.58 1,510,852.35 3.93 12,389.67 MWD +IFR -AK- CAZ -SC (4) 18,090.82 91.78 148.61 7,424.24 7,371.80 - 14,779.97 - 622.95 5,959,175.28 1,510,900.17 2.88 12,488.35 MWD +IFR -AK- CAZ -SC (4) 18,184.35 91.28 148.21 7,421.74 7,369.30 - 14,859.61 - 573.98 5,959,094.81 1,510,947.77 0.68 12,581.81 MWD +IFR -AK- CAZ -SC (4) 10/22/2009 9 :38 :24AM Page 7 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: -; ConocoPhillips(Alaska) Inc. -WNS Local Co- ordinate Reference: Well CD2 -60 Project Western North Slope ND Reference: CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: %- CD2 -60A (15.9 +36.54) © 52.44ft (Doyon 19) Well: CD2 -60 North Reference: True Wellbore:, CD2 -60A Su Calculation Method: Minimum Curvature Design: CD2 -60A Database: CPA! EDM Production Survey Map Map Vertical MD Inc Azi ND ND +N/ + - SS -S E/ W ' Northing Easting I , DLS Section =:. (ft) r) (°) (ft) (ft) ! (ft) (ft) (ft) (ft) ( °11001) (ft) Survey Tool N ame 18,281.08 90.54 148.97 7,420.20 7,367.76 - 14,942.16 - 523.57 5,959,011.42 1,510,996.75 1.10 12,678.50 MWD +IFR -AK- CAZ -SC (4) 18,377.80 88.01 149.00 7,421.43 7,368.99 - 15,025.03 - 473.74 5,958,927.71 1,511,045.15 2.62 12,775.19 MWD +IFR -AK- CAZ -SC (4) 18,472.57 87.89 149.37 7,424.82 7,372.38 - 15,106.37 - 425.23 5,958,845.56 1,511,092.26 0.41 12,869.89 MWD +IFR -AK- CAZ -SC (4) 18,568.13 87.95 149.71 7,428.29 7,375.85 - 15,188.69 - 376.82 5,958,762.43 1,511,139.24 0.36 12,965.38 MWD +IFR -AK- CAZ -SC (4) 18,663.34 88.20 149.44 7,431.49 7,379.05 - 15,270.74 - 328.63 5,958,679.57 1,511,186.01 0.39 13,060.54 MWD +IFR -AK- CAZ -SC (4) 18 58.33 89.06 MWD+IFR-AK-CAZ-SC 4 ,7 0 149.16 7,433.76 7,381.32 -15,352.40 -280.15 5,958,597.10 1,511,233.08 0.95 13,155.49 M FR AK- CAZ -SC ( ) 18,854.32 88.38 148.24 7,435.90 7,383.46 - 15,434.39 - 230.29 5,958,514.27 1,511,281.52 1.19 13,251.43 MWD +IFR -AK- CAZ -SC (4) 18,950.05 89.25 148.89 7,437.88 7,385.44 - 15,516.05 - 180.38 5,958,431.77 1,511,330.02 1.13 13,347.11 MWD +IFR -AK- CAZ -SC (4) 19,043.28 91.29 147.32 7,437.44 7,385.00 - 15,595.20 - 131.12 5,958,351.79 1,511,377.91 2.76 13,440.28 MWD +IFR -AK- CAZ -SC (4) 19,141.37 91.59 147.38 7,434.98 7,382.54 - 15,677.76 -78.22 5,958,268.34 1,511,429.38 0.31 13,538.23 MWD +IFR -AK- CAZ -SC (4) 19,236.07 92.65 147.85 7,431.47 7,379.03 - 15,757.68 -27.53 5,958,187.58 1,511,478.69 1.22 13,632.78 MWD +IFR -AK- CAZ -SC (4) 19,331.33 91.97 147.78 7,427.63 7,375.19 - 15,838.24 23.17 5,958,106.17 1,511,527.99 0.72 13,727.90 MWD +IFR -AK- CAZ -SC (4) 19,376.80 91.04 148.31 7,426.44 7,374.00 - 15,876.80 47.22 5,958,067.20 1,511,551.38 2.35 13,773.32 MWD +IFR -AK- CAZ -SC (4) 19,426.62 88.87 147.60 7,426.48 7,374.04 - 15,919.03 73.66 5,958,024.53 1,511,577.08 4.58 13,823.11 MWD +IFR -AK- CAZ -SC (4) 19 522.95 86.83 146.14 7,430.09 7,377.65 -15,999.63 126.26 5,957,943.04 1 511 628.30 2.60 13 919.22 MWD +IFR -AK- CAZ -SC (4) 19,617.70 86.96 147.96 7,435.22 7,382.78 - 16,079.02 177.72 5,957,862.78 1,511,678.38 1.92 14,013.70 MWD +IFR -AK- CAZ -SC (4) 19,713.64 86.09 149.08 7,441.04 7,388.60 - 16,160.69 227.73 5,957,780.28 1,511,726.97 1.48 14,109.43 MWD +IFR -AK- CAZ -SC (4) 19,808.91 86.28 149.81 7,447.38 7,394.94 - 16,242.55 276.05 5,957,697.61 1,511,773.88 0.79 14,204.48 MWD +IFR -AK- CAZ -SC (4) 19,875.27 89.62 154.65 7,449.75 7,397.31 - 16,301.20 306.93 5,957,638.44 1,511,803.75 8.86 14,270.72 MWD +IFR -AK- CAZ -SC (4) 19,904.49 88.44 154.84 7,450.25 7,397.81 - 16,327.63 319.40 5,957,611.81 1,511,815.76 4.09 14,299.84 MWD +IFR -AK- CAZ -SC (4) 19,999.76 86.03 155.21 7,454.84 7,402.40 - 16,413.88 359.57 5,957,524.88 1,511,854.45 2.56 14,394.62 MWD +IFR -AK- CAZ -SC (4) 20,094.87 85.91 154.82 7,461.53 7,409.09 - 16,499.88 399.65 5,957,438.22 1,511,893.04 0.43 14,489.14 MWD +IFR -AK- CAZ -SC (4) 20,191.05 88.32 155.26 7,466.37 7,413.93 - 16,586.96 440.18 5,957,350.46 1,511,932.07 2.55 14,584.82 MWD +IFR -AK- CAZ -SC (4) 20,286.10 91.22 155.44 7,466.75 7,414.31 - 16,673.34 479.82 5,957,263.43 1,511,970.21 3.06 14,679.44 MWD +IFR -AK- CAZ -SC (4) 20,379.56 92.71 154.04 7,463.55 7,411.11 - 16,757.80 519.67 5,957,178.29 1,512,008.61 2.19 14,772.52 MWD +IFR -AK- CAZ -SC (4) 20,474.18 91.04 152.62 7,460.45 7,408.01 - 16,842.31 562.12 5,957,093.08 1,512,049.60 2.32 14,866.92 MWD +IFR -AK- CAZ -SC (4) 20,570.30 90.23 151.47 7,459.38 7,406.94 - 16,927.20 607.17 5,957,007.43 1,512,093.19 1.46 14,962.98 MWD +IFR -AK- CAZ -SC (4) 20,667.68 89.56 150.50 7,459.56 7,407.12 - 17,012.36 654.40 5,956,921.48 1,512,138.95 1.21 15,060.34 MWD +IFR -AK- CAZ -SC (4) 20,762.95 90.36 151.38 7,459.63 7,407.19 - 17,095.64 700.68 5,956,837.43 1,512,183.78 1.25 15,155.59 MWD +IFR -AK- CAZ -SC (4) 20,857.79 90.17 151.65 7,459.19 7,406.75 - 17,178.99 745.91 5,956,753.32 1,512,227.57 0.35 15,250.40 MWD +IFR -AK- CAZ -SC (4) 20,921.80 92.89 151.09 7,457.48 7,405.04 - 17,235.15 776.57 5,956,696.65 1,512,257.26 4.34 15,314.36 MWD +IFR -AK- CAZ -SC (4) 21,001.00 92.89 151.09 7,453.49 7,401.05 - 17,304.39 814.81 5,956,626.76 1,512,294.30 0.00 15,393.45 PROJECTED to TD 10/22/2009 9:38:24AM Page 8 COMPASS 2003.16 Build 69 S Conoco Phillips Time Log & Summary We //view Web Reporting Report Well Name: CD2 - 60 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 9/10/2009 12:00:00 PM Rig Release: 9/13/2009 3:00:00 PM Time Logs Date' From To Dur1- - - S. Depth E. Depth Phase Code Subcode T -- "' Comment 09/10/2009 24 hr Summary Rig Maintenance while next well being prepared 12:00 00:00 12.00 SITEP RIGMNT RGRP P Rig Maintenance - Inspect & check #1 Mud pump bearings, Clean & Paint Top drive, Clean & Prep Iron Roughneck f/ repairs, Rig & Test all 2" hoses to 5000 psi f/ 10 min 09/11/2009 Rig Maintenance 00:00 12:00 12.00 SITEP RIGMNT RGRP P Cont. rig maintenance - inspect MP #1 check bearing clearence - Cont. clean & paint TD - Cont. clean & paint iron ruffneck - Cont. pressure test 2" high pressure hoses 12:00 00:00 12.00 SITEP RIGMNT RGRP P Continue rig maintenance, Change out Iron roughneck jaw, Work on Boiler, Paint top drive, Work on replacing old section of chain on skate, Adjust service loop, Remove rotary table cover to repair lock pins, Mud pump mainteance, Inspect drag chain 09/12/2009 00:00 12:00 12.00 SITEP RIGMNT RGRP P Cont. rig maintenance - Paint TD - work on tbg - PM on mud pumps(chnage out valves & seats) - Work on iron ruffneck - finish replacing chain on pipe skate 12:00 00:00 12.00 SITEP RIGMNT RGRP P Cont. rig maintenance, Flush & Change oil in rotary table & Gear box, Install lock pins f/ rotary table, Continue welding projects, Install covers on rotary table, remove drawworks gaurds and change out grease line fittings, Continue mud pump work, Install Iron roughneck on tracks 09/13/2009 Rig maintenance - Released rig f/ maintenance @ 1500 hrs. 9/13/09 - Prep for move to CD2-48 WO 00:00 15:00 15.00 SITEP RIGMNT SVRG P Finish up rig maintenance - P/M on mud pumps - Scrub & paint pit room - Paint mud manifold - finish service on rotary table - Prep rig for move to CD2 -48 WO 09/22/2009 Begin rig move f/ CD2 -56 Page 1 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase ` Code Subcode T Comment 23:00 00:00 1.00 MIRU MOVE MOB P Blow down water & steam lines - Cut high line power - Prep to move pit/motor complex 09/23/2009 Move in & rig up - Clean pits & take on 10.6 ppg CaCl2 brine - RU to kill well - PJSM on killing well Kill well pumping 35 bbls hi -vis CaCl2 @ 10.6 ppg followed by 200 bbls CaCl2 to fill tbg - Shut in & monitor pressure - Cont. with well kill pumping 240 bbls 10.6 ppg CaCl2 - obtain sample © btms up 8.0 ppg - Cont. pumping 150 bbls - obseverd 10.5 ppg sample @ 90 bbls pumped of the additional 150 bbls.- Shut in & monitor pressure SIDPP 180 SICp 180 psi - (lost appriox 132 bbls fluid during well kill) performed s series of bleed & monitor pressure until well was dead (Modified exhale test) 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Move out Pit & Motor complexes - skid rig on subbase - back sub off of well 02:00 03:00 1.00 0 0 MIRU MOVE MOB P Swap well gaurds from CD2 -57 to CD2- 59 - Install Drillers side wind wall back onto sub 03:00 05:00 2.00 0 0 MIRU MOVE MOB P Move rig to CD2 -60L1 - center rig over well - Skid rig to drill position - spot up Pit & Motor Complexes - Move in pipe shed 05:00 06:00 1.00 0 0 MIRU MOVE RURD P Connect Steam, air and water service lines - Highline power on @ 0600 hrs. Accepted rig @ 0600 hours. 06:00 10:30 4.50 0 0 MIRU MOVE RURD P Clean Pits 3,5, &6 - Load CACL Brine in pits - Install temperary windwall in cellar - Tested rig gas detectors - Electrician / Drill site Operator confirmed rig ESD working. 10:30 11:30 1.00 0 0 MIRU WELLPF OTHR P RU and test FMC Lubricator 250/2000 psi - Pull BPV - RD Lubricator - SITP =1150 psi - IA pressure 650 psi 11:30 13:00 1.50 0 0 MIRU WELLPF RURD P RU hardlines, hoses and manifold for well kill operations - Condition CACL brine in pits to 10.6 ppg - Mixed 35 bbl high vis spacer w/ 10.6 ppg brine 13:00 13:15 0.25 0 0 SLOT WELLPF SFTY P Held PreJob safety and Opts meeting on planned well kill procedures ** Drill Site Operator advised of up coming operations 13:15 13:30 0.25 0 0 SLOT WELLPF PRTS P Fill lines & pressure test to 2500 psi - Good test Page 2 of 26 I • Time Logs Date From To Dur S. Depth E. Depth? Phase Code Subcode T Comment 13:30 00:00 10.50 0 0 SLOT WELLPF KLWL P Pumped kill weight fluid (10.6 ppg CaCl2) - ICP 1100 psi - 35 bbls hi -vis pill followed by 200 bbls 10.6 ppg @ 3 bbls /min to fill tbg to shot holes @ 13,017' - Shut in well & monitor pressure - SIDPP 0 SICP 940 psi - all returns outside to tiger tank - Cont. circ btms up f/ 13,017' (240 bbls) - Shut down & shut in well monitor pressure - SIDPP - 180 psi - SICP - 400 psi - Sample of return fliud wt. 8.0 ppg - Lost approx. 100 bbls fluid to well while circulating - Open well & circ 150 bbls @ 2 bbls /min - observed 10.5 ppg in sample taken @ 90 bbls pumped - Shut down & shut in well monitor pressure SIDPP 180 psi SICP 180 psi - Lost approx. 32 bbls ( lost total of approx. 132 bbls during kill) - Preformed a series of bleed & monitor pressure - Bleed #1 - bled annulus pressure down to 40 psi & Shut in well - SIDPP 80 psi SICP 40 psi - after 20 mins. SIDPP 140 psi SICP 120 psi - Bleed # 2 - Bled 2 bbls from annulus - took 6 mins to bleed - Shut in well - SIDPP 40 psi SICP 30 psi after 20 mins. SIDPP 100 psi SICP 80 psi - Bleed #3 - bled 2 bbls from annulus took 8 mins to bleed - Shut in well SIDPP 20 psi SICP 20 psi after 25 mins. SIDPP 40 psi SICP 60 psi - Bleed #4 bled 2 bbls form annulus took 12 1/2 mins to bleed - shut in SIDPP 20 psi SICP 0 after 2 hrs. SIDPP 0 SICP 0 09/24/2009 Finish BOPE test - RD - Pull BVP - MU landing jt. into hanger - Back out lock down - pulled to 125K - 1/2" movement worked tubing hanger to 125k - pumped oil into void between tubing hanger seals - wrapped and steamed wellhead - pulled on string - hanger began moving out of wellhead with 180K on wt. indicator - Work pipe attempting to pull packer free - working up to 260 k - monitoring well on trip tank while working pipe - static losses 6 bbls /hr. - shut off hole fill pump - Observed gas breaking out of brine - well began to flow - began to circ btms up - gas break out increasing - shut in well - Circ btms up through choke @ 2 bbls /min @ 400 pis (added tubes to brine) shut down pump - open well - observed flow @ 12 % - momitor well - flow dropped off to 2% - worked pipe pulling up to 260 k still unable to pull packer free - Observed well - well still flowing @ 2 % - Shut in well & performed exhale test 00:00 01:00 1.00 0 0 SLOT WHDBO OWFF P Monitor well SITP =0 SICP =O - Open return line to pits - check for flow - Well dead - Blow down and rig down Lines and manifold 01:00 01:30 0.50 0 0 SLOT WHDBO RURD P RU FMC lubricator and Pull BPV - Rig Down lubricator 01:30 03:00 1.50 0 0 SLOT WHDBO NUND P PJSM - Remove tree - inspect ACME threads - Install Blanking plug in hanger 03:00 04:30 1.50 0 0 SLOT WHDBO NUND P NU BOP Stack - flow nipple and flowline Page 3 of 26 Time Logs Date `` From To Dur - S. Depth E. Deoth Phase Code Subcode T Comment 04:30 12:00 7.50 0 0 SLOT WHDBO BOPE P RU and test BOPE - Annular Preventor 250/2500 - Rams, choke, kill, manifold , TD, and floor safety valves 250 /3500 psi - Perform Accumulator test - Chuck Scheve AOGCC waived witnessing tests. Choke manifold valves # 8 & 3 failed low pressure tests. Changed out gates and seats - retested valves, good tests. 12:00 13:00 1.00 0 0 SLOT WHDBO BOPE P LD landing joint and blanking plug - blow down choke and kill lines - Pull BPV 13:00 16:15 3.25 0 0 SLOT WELLPF PULL P Engage tubing hanger with landing joint(a) - xo to top drive - Back Out Lock Down Studs - pulled to 125K - 1/2" movement worked tubing hanger to 125k - rechecked lock down studs, ok - pumped oil into void between tubing hanger seals - wrapped and steamed wellhead - pulled on string - hanger began moving out of wellhead with 180K on wt. indicator Page 4 of 26 di Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 00:00 7.75 0 0 SLOT WELLPF PULL P Work pipe attempting to pull packer free - working up u to 260 k - monitoring well on trip tank while working pipe - static losses 6 bbls /hr. - shut off hole fill pump - Observed gas breaking out of brine - well began to flow - began to circ btms up - gas break out increasing - shut in well - Circ btms up through choke @ 2 bbls/min @ 400 pis (added lubes to brine) shut down pump - open well - observed flow @ 12 % - momitor well - flow dropped off to 2% - worked pipe pulling up to 260 k still unable to pull packer free - Observed well - well still flowing @ 2 % - Shut in well & performed exhale test - ISIDDP 80 psi ISICP 85 psi monitor pressure for 1 hr. DPP 60 psi CP 55 psi - Open choke & bled off 3 bbls - Shut in well - ISIDPP - 20 psi ISICP 0 psi - monitor pressure - for 30 mins.- DP 30 psi CP 25 psi - Open choke & bled off 3 bbls. - ISIDPP 20 psi ISICP 0 psi - Monitor pressure for 30 mins. DP 20 psi CP 0 psi - Open well & observed slight flow - fluid level began to drop slowly - Prep to monitor on TT & work pipe Note- Hole took 55 bbls static losses while working pipe & 55 bbls while circ btms up - Gained 12 bbls while working pipe after cicr btms up - Got 9 bbls back during exhale test - total losses to well 89 bbls 09/25/2009 Conduct exhale test. Bled pressure to 0 psi. Open well, observe gas breaking out w /slight flow. Flow quit observed well on TT and worked pipe to 260 K - RU Halliburton E -line - RIH & cut tbg @ 13,000' - POOH & RD wireline - MU landing joint into tbg hanger - Pull & LD tbg hanger - 249 jts 4 1/2" tbg - Gas lift mandrel assembly - DB nipple 00:00 03:00 3.00 0 0 SLOT WELLPF OWFF P Conduct exhale test. Bled pressure to 0 psi. Open well, observe gas breaking out of slight flow. Flow quit static loss, observed well on TT and worked pipe to 160K - no movement @ packer 03:00 11:15 8.25 0 0 SLOT WELLPF CPBO P Held PJSM, RU Halliburton E -line - pressure test lubricator to 500 psi - RIH w/ Radial torch Cutter - made corrilation passes - put cutter on depth - Cut tubing @13,000' MD. Monitor well on trip tank throughout - static losses - 3-4 BPH. POOH w/ E -line - RD wireline equipment LD lubricator - clear tools from rig floor Page 5 of 26 Time Logs Date • From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:00 0.75 0 0 SLOT WELLPF PULL P PU landing joint A and engaged hanger - Back Out Lock Down Studs - Pulled hanger and confirmed tubing cut - 200 K PUW. Monitor well and observed static loss of 3 BPH. Landed hanger - Break out top drive and laid down xo, floor safety valve & pup joint - SOW =125k. Pull hanger to floor and Laid down tubing hanger and landing joint - Monitor well - static losses of —4 bph observed 12:00 12:15 0.25 13,000 13,000 SLOT WELLPF SFTY P PJSM on laying down tubing 12:15 00:00 11.75 13,000 2,157 SLOT WELLPF PULL P Pull out of hole w/ 4 1/2" tbg - laid down 249 jts plus GLM assembly - DB nipple (10,843') Note - Hole still taking fluid - lost 95 bbls last 24 hrs.( 26 bbls static & 69 bbls on trip out w/ tbg) - Total losses to date 290 bbls 09/26/2009 Finish pulling & laying 4 1/2" tbg - 299 jts plus cut off jt.- RU & test Hydrill to 250 & 2500 psi - VBR's to 250 & 3500 psi w/ 4" test jt.- MU fishing assembly # 1 - RIH - Tag top of fish @ 12,998' - work over fish to 13,006' - Jar on packer (no movement on packer) Attempt to release grapple f/ fish - unable to release work pipe - appears that packer is moving up hole 00:00 02:30 2.50 2,157 0 SLOT WELLPF PULL P Continue to POOH laying down tubing - All fish accounted for - Cutoff joint = 19.35' - ETOF = 12,998' Rig down tubing equipment - clean rig floor 02:30 03:30 1.00 0 0 SLOT WHDBO BOPE P Install test plug and 4" test joint - Tested Annular Preventor 250/2500 psi - Upper and Lower VBR's 250/3500 - Pull test plug - Set wear ring 03:30 05:30 2.00 0 282 SLOT FISH PULD P MU Fishing BHA #1 - Dressoff shoe, bushing, 5 3/4" overshot ext., 5 3/4" Overshot dressed w/ 4.5" spiral grapple, 4 3/4" Bumper sub, m4 3/4" jar, (8) 4 3/4" DC's, Accelerator, XO 05:30 14:15 8.75 282 12,900 SLOT FISH TRIP P Pick up 21 joints of 4" drill pipe from shed - RIH to 12,900' slow last 30' of each stand due to fluid running over drill pipe 14:15 15:15 1.00 12,900 13,006 SLOT FISH FISH P Lay down 2 joints of drill pipe - Establish ccirculation 1.5 bpm @ 140 psi PUW 255K SOW 137K ROT wt. 185K RIH - tagged TOF @ 12,997' - Work over fish to 13,006' 15:15 18:15 3.00 13,006 13,006 SLOT FISH FISH P Jar on fish staged up from jarring @ 275K and pulling to 330K to jarring @ 350K and pulling to 390K - no movement of packer 18:15 00:00 5.75 13,006 12,991 SLOT FISH FISH P Attempt to release grapple f/ fish - Unable to release working pipe - appears fish is moving up hole - continue to work & jar pipe Page 6 of 26 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode, T Comment 09/27/2009 24 hr Summary Worked fish free - POOH - laid down fish recovered remainder of completion string (Note left slips, slip housings and all seal elements on packer in hole) MU clean out assembly - Cut & slip drill line - RIH w/ clean out assembly to 6792' 00:00 02:15 2.25 12,991 12,991 SLOT FISH TRIP P Continue to work pipe - fish moving up hole - PUW 268K SOW 135K - flow check well, slight static loss — 2 bph 02:15 10:45 8.50 12,991 282 SLOT FISH TRIP P POOH on elevators from 12,991' to 282' - Worked through tight spot @ 5848' - Flow check well @ 8292' & 282' - observed slight static losses 10:45 15:00 4.25 282 0 SLOT FISH PULD P Layed down XO & accelerator - Stood back 1 stand of DC's - Lay down 5 DC's (boxes flared) Layed down Jars and Bumper Sub - Pulled fish to rig floor - recovered remainder of completion equipment - Cutoff joint, pup jt, Packer, pup jt., full joint, XN nipple, pup jt., WLEG. Closed blind rams - welder made two cuts to lay down Baker Loc'd tools - Clear tools from rig floor **slips, slip housings and all seal elements on packer left in hole 15:00 17:00 2.00 0 595 SLOT FISH PULD P Move tools to rig floor - MU Fishing BHA #2 - 6 1/8" bit, (2) 4 3/4" boot baskets, csg scraper, bit sub, (2) string magnets, 4 3/4" Bumper sub, jars, XO, 18 jts of 4" HWDP 17:00 17:15 0.25 595 595 SLOT RIGMNT SFTY P PJSM on cut & slip drill line 17:15 18:30 1.25 595 595 SLOT RIGMNT SLPC P Cut & slip 50' drill line service TD 18:30 19:30 1.00 595 2,022 SLOT FISH TRIP P RIH w/ clean out assembly f/ 595' to 2022' ( picking up 45 jts. 4" Dp f/ pipe shed) 19:30 19:45 0.25 2,022 2,404 SLOT FISH TRIP P RIH w/ clean out assembly f/ 2202' to 2404' w/ DP f/ derrick 19:45 20:15 0.50 2,404 2,404 SLOT RIGMNT RGRP T Electrician chnage out switch on Iron Ruffneck 20:15 00:00 3.75 2,404 6,792 SLOT FISH TRIP P Cont. RIH w/ CO assembly f/ 2404' to 6792' (filling pipe every 20 stds) PU wt. 155 SO wt. 120 09/28/2009 Cont. RIH w/ clean out assembly to 14,316' - Circ btms up & work junk bskts - Obseverd heavy gas break out @ btms up - Shut in well w/ annuluar & finish circ out gas - Monitor well - Circ btms up # 2 - Observed gas break out @ btms up - shut in & monitor well - perform exhale test - pressures coming down - Circ btms #3 - observed gas break out @ btms up (less than 2 previous btms up) perform exhale test # 2 - pressures coming down as before - Open well & monitor on TT- gained 24 bbls & well dead in 4 hrs.- no gas break out & fluid level 3 -4" below flow line - Begin trip out w/ clean out assembly 00:00 04:15 4.25 6,792 14,316 SLOT FISH TRIP P RIH with BHA #2 from 6,792' to 14,316' - worked through tight spots at 13,140' and 13,390' Page 7 of 26 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:45 1.50 14,316 14,316 SLOT FISH CIRC P Establish circulation - staged pumps up to 4.5 bbls /min @ 1080 psi - @ btms up had gas boiling and breaking out at surface - lost 55 bbls of mud to hole while circulating 05:45 07:30 1.75 14,316 14,316 SLOT FISH OWFF P Shut down pump observed fluid in annulus dropping slightly - Shut in well - circulate 50 bbls through full open choke 3 bpm / 530 psi - returns dirty with solids -11.3 ppg - when fluid cleaned up shut down pumps - closed choke monitor pressures - for 20 minutes SICP =61 psi SIDP =27 psi - bled 5 bbls to trip tank (10 min.) and shut in choke - monitored well for 15 minutes - SICP =28 psi SIDP =25 psi - Open choke bleed down annulus - open annular preventor - monitor well 07:30 11:15 3.75 14,316 14,316 SLOT FISH CIRC T Circulate and condition brine 4 bpm / 920 psi - had gas breaking out of brine throughout second bottoms up - increased gas observed at bottoms up - continued to circulate until returns clear of gas Lost 52 bbls of brine to hole 11:15 12:30 1.25 14,316 14,316 SLOT FISH OWFF T Shut down pumps - shut in well and perform Exhale test - Bled 5 bbls of brine to trip tank (7:50 min.) shut in well - observe pressures for 20 minutes - SICP =100 psi SIDPP =100 psi - Bled 4 bbls to trip tank (8:35 min.) shut in choke - Observed pressures for 20 minutes SICP =56 psi SIDPP =56 psi 12:30 14:30 2.00 14,316 14,316 SLOT FISH CIRC T Circulate hole - 4 bpm / returns stayed clean until) bottoms up - circulate out gas - ( less volume than previous 2 BU) returns cleaned up in 40 bbls past bottoms up 14:30 19:30 5.00 14,316 14,316 SLOT FISH OWFF T Monitor well on TT - gained 24 bbls - Well dead in 4 hrs.- observed fluid level drop 3 to 4 " below flow line for last hour - No gas break out 19:30 00:00 4.50 14,316 9,463 SLOT FISH FISH P Blow down top drive, kill & choke lines, & choke manifold - POOH on TT f/ 14316' to 9463' Hole taking good fill - monitor well @ 20 stds out - well dead fulid level 2 -3" below flow line Lost 122 bbls while circulationg - gained 24 bbls while monitoring well - total losses for day 98 bbls - total losses to well 461 bbls of 10.5 ppg CaCl2 Page 8 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/29/2009 24 hr Summary POOH & LD clean out assembly - Flush stack - Test Hydril to 250 & 2500 psi - MU Baker cmt. retainer RIH & Set @ 14,275' - Test to 1000 psi - Estabish injection rate 2 bbls /min @ 1830 psi - Circ btms up Observed some gas break out - RU cement equipment 00:00 04:00 4.00 9,463 595 SLOT FISH TRIP P Cont. POOH w/ clean out assembly - f/ 9463' to 595' - Flow ck @ HWDP - well static 04:00 05:30 1.50 595 0 SLOT FISH PULD P POOH w/ clean out assembly - stand back HWDP - Break bit - LD - XO, jars, bumper sub, string magnets, csg scraper, & junk baskets - recovered 3 large pieces of packer slips & several smaller pieces of meatl f/ packer - 05:30 07:00 1.50 0 0 SLOT WHDBO BOPE P PU test jt. & pull wear bushing - Set stack washing wear bushing & PU stack wash & flush stack - function rams & Hrydril - LD stack washer & pull wear bushing no recovery of any metal 07:00 08:00 1.00 0 0 SLOT WHDBO BOPE P Set test plug & test Hydril to 250 & 2500 psi as per regulation after use for well control. - Pull test plug & set drilling wear bushing q g 08:00 08:15 0.25 0 0 SLOT CEMEN" SFTY P PJSM on MU cement retainer 08:15 18:00 9.75 0 14,218 SLOT CEMEN "TRIP P MU Baker cement retainer & RIH to 14,218' (149 stds) - PU wt. 280 SO wt140- 18:00 19:15 1.25 14,218 14,275 SLOT CEMEN" PRTS P LD single on std # 150 - Get on depth w/ retainer @ 14,275' - Set retainer - Pressure test to 1000 psi - Good test 19:15 20:00 0.75 14,275 14,275 SLOT CEMEN "CIRC P Sting into retainer & establish injection rate - 2 bbls /min @ 1830 psi w/ 10.5 ppg CaCl2 brine 20:00 22:30 2.50 14,275 14,275 SLOT CEMEN" CIRC P LD single & Circ DP & annulus volume @ 4 bbls /min @ 840 psi - Observed some gas break out @ btms up - shut down & monitor well - Well static - fluid level just below flow line Blow down top drive 22:30 00:00 1.50 14,275 14,275 SLOT CEMEN" RURD P RU head pin, valves, & hoses for cement job 09/30/2009 Performed squeeze cement job through cement retainer @ 14,275' - w /30 bbls 15.8 ppg - Pu & reverse circ 1.5 DP volume & then circ long way adding lubes to brine - POOH w/ retainer running tool - RU & attempt to test 7" casing - unable to get high pressure test bleed off 625 psi in 4 mins.- RU & test BOPE - Slip & cut drill (line - MU test packer Page 9 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code ? Subcode T Comment 00:00 01:30 1.50 14,275 14,275 SLOT CEMEN" SQEZ P Held pre -job safety meeting and cemented per schedule. Pumped 5 bbls water & Tested lines to 3500 psi. Pumped 15 bbls Biozan water - Mixed and pumped 20 bbl Mud push @ 11.5 ppg followed by 30 bbls Class G tail cmrt @ 15.8 ppg - Pumped 5 bbls water behind followed by 15 bbls Biozan water displaced with 55.6 bbl Of 10.5 ppg CaCl2 brine - Stung back into retainer and displaced continued to displace w/ 125.6 bbls 10.5 ppg CaCl2 brine - Placing 30 bbls cmt through retainer intinal rate 2 bbls /min @ 870 psi - final rate 1 bbl /min @ 3050 psi - Unstung f/ retainer - monitor well static - CIP @ 0130 hrs. 01:30 03:00 1.50 14,275 14,275 SLOT CEMEN "CIRC P Rig up and reverse at 4 bpm and 880 psi. Blow down kill line 03:00 05:15 2.25 14,275 14,275 SLOT CEMEN" CIRC P Circulate at 4 bpm and 1020 psi. Monitor well - static. Rig down and blow down lines 05:15 10:00 4.75 14,275 7,158 SLOT CEMEN TRIP P Pull out of the hole on elevators from 14,275' to 7,158' Fluids out of balance. Pump slug at 8110' and pull 10 stands to 7158'. Drill pipe still pulling wet. Attempt to circulate and drill pipe plug at 1300 psi. 10:00 12:00 2.00 7,158 7,158 SLOT CEMEN CIRC P Pre -job safety meeting and rig up to reverse circulate. Reverse and clear drill pipe. Reverse at 4 bpm and 640 psi. Rig up to circulate the long way and circulate bottoms up at 6 bpm and 940 psi. Pump pill and blow down top drive 12:00 14:30 2.50 7,158 0 SLOT CEMEN" TRIP P Finiish POOH f/ 7158' w/ cement retainer running tool 14:30 15:30 1.00 0 0 SLOT DRILL PRTS P Close bind rams & pressure test 7" casing - to 250 psi (good) & 3500 psi (No good lost 625 psi in 4 mins. ) Checked surface equipment & retest to 3500 psi No Good lost 600 psi in 5 mins. 15:30 16:00 0.50 0 0 SLOT WHDBO BOPE P Pull wear bushing & set test plug Page 10 of 26 I 4 Time Logs Date From . To Dur? S. Depth E. Depth Phase Code Subcode T Comment 16:00 22:00 6.00 0 0 SLOT WHDBO BOPE P RU & test BOPE - Hydril to 250 & 2500 psi - VBpipe rams, choke & kill line valves, choke manifold valves, to drive IBOP's - dart, & floor safety valve, with 4" test jt to 250 & 3500 psi - performed accumulator recovery test - pulled test jt & tested blind rams to 250 & 3500 psi - Pulled test plug & changed to 41 /2" test jt. Tested Hydril to 250 & 2500 psi - tested VB rams to 250 & 3500 psi - Pull test jt. installed wear bushing 22:00 22:15 0.25 0 0 SLOT RIGMN7 SFTY P PJSM on cut & slip of drill line 22:15 23:30 1.25 0 0 SLOT RIGMN7 SLPC P Cut & slip 60' drill line - service TD, drawworks, & iron ruffneck 23:30 00:00 0.50 0 13 SLOT DRILL PULD P PJSM - MU Baker retrieveamatic packer & XO 10/01/2009 RIH w/ Baker retrievamatic packer & test casing @ 5052', 9995' to 3500 psi Good tests - test @ 13,109' - Leaked off -Pull up to 12,950' & test to 3500 psi Good test - RIH to13,109' pump down DP to test down to cmt retainer to 3500 psi - lost 400 psi in 20 mins.- released packer & POOH Observed DP connection on 2nd std out was backed off 3 threads ( possible cause of slow leak on test) Retorque pipe POOH & check make up on next 20 stds.- Finish POOH & LD packer 00:00 06:45 6.75 13 5,032 SLOT DRILL TRIP P RIH w/ Baker retrieve -a -matic packer to 5032' * Note: Observed chucks of cement falling out of std # 10 - Pulled back to packer - Rabbited DP to remove cement from DP 06:45 08:00 1.25 5,032 5,032 SLOT DRILL PRTS P Set packer @ 5032' - RU & test casing f/ 5032' to surface to 3500 psi for 30 mins.(Good test) 08:00 10:45 2.75 5,032 9,995 SLOT DRILL TRIP P Cont. RIH w/ packer f/ 5032' to 9995' 10:45 12:00 1.25 9,995 9,995 SLOT DRILL PRTS P Set packer @ 9995' - Ru & test casing f/ 9995' to surface to 3500 psi for 30 mins. ( Good test) 12:00 13:00 1.00 9,995 13,142 SLOT DRILL TRIP P RIH w/ packer f/ 9995' to 13.142' - string took wt. @ 13,142' - 13:00 13:30 0.50 13,142 13,109 SLOT DRILL PRTS P PU to 13,109' & set packer - RU & Attempt to test casing f/ 13,109' to sufrace to 3500 psi - wouldn't hold pressure * Note- Baker Premier Packer setting depth was 13,032' 13:30 14:00 0.50 13,109 12,950 SLOT DRILL TRIP P Pulled back f/ 13,109' to 12,950' 14:00 15:00 1.00 12,950 12,950 SLOT DRILL PRTS P RU & test casing f/ 12,950' to surface to 3500 psi for 30 mins. (Good Test) 15:00 16:00 1.00 12,950 13,109 SLOT DRILL TRIP P Release packer- RIH to 13,109' checking torque on DP connections Page 11 of 26 4111 1110 Time Logs Date From To Dur S. Depth E. Depth Phase Code ` Subcode T : Comment 16:00 16:30 0.50 13,109 10,109 SLOT DRILL PRTS P MU top drive & Set packer @ 13,100' - Test 7" casing f/ 13,100 to cement retainer @ 14,275' pumping down DP - pressure bled down 400 psi in 20 mins. 16:30 00:00 7.50 10,109 0 SLOT DRILL TRIP P Release packer -Blow down TD, kill & choke lines - POOH w/ packer f/ 13,109' - Found DP connection backed out 3 threads (possible source of slow leak during test) retorqued DP & checked connections coming out of hole for 1st. 20 stds. - continued to POOH w/ packer - LD packer & XO 10/02/2009 Cont.RIH W/ clean out assembly to 13,096' - Wash & ream to 14,282' top of retainer (tagged soft cmt @ 14,275' - Circ 2 X btms up @ 9 bbl /min - Rotate & recpicate pipe - Perform FITto 12.6 ppg EMW - POOH & LD clean out assembly 00:00 01:30 1.50 0 595 SLOT DRILL PULD P PJSM - MU clean out assembly (bit, scraper, 2 junk bskts. - bit sub, 2 string magnets, bumper sub, jars, XO, 18 HWDP) RIH to 595' 01:30 07:15 5.75 595 7,172 SLOT DRILL TRIP P PJSM - RIH w/ clean out assembly - picking up 207 jts 4" DP f/ pipe shed to 7172' ( fill pipe every 20 stds) 07:15 09:45 2.50 7,172 13,096 SLOT DRILL TRIP P Cont. RIH w/ CO assembly f/ 7172' to 13,096' w/ DP f/ derrick(fill pipe every 20 stds) 09:45 13:30 3.75 13,096 14,282 SLOT DRILL WASH P Wash & ream f/ w/ bit & scraper f/ 13,096' to 14,282' (tagged soft cmt @ 14,275' - tagged up on retainer @ 14,282') @ 5 bbls /min @ 1350 psi w/ 50 rpm's - PU wt. 255 k SO wt 135 k Rot wt. 170 k - torque 13,000 ft/lbs 13:30 14:45 1.25 14,282 14,282 SLOT DRILL CIRC P Circ 2 X btms up @ 9 bbls /min @ 2800 psi w/ 50 rpm's - shut down TD 7& circ @ 9 bbls /min @ 2600 psi 14:45 15:45 1.00 14,282 14,043 SLOT DRILL TRIP P Flow ck static - POOH f/ 14,282' to 14,043' - PU wt. 250 k - Blow down TD - Pull air slips 15:45 16:45 1.00 14,043 14,043 SLOT DRILL FIT P RU & perform FIT @ 14,264' MD 7373' TVD - 800 psi w/ 10.5 ppg brine - 12.6 ppg EMW - lost 15 psi in 30 mins. - RD - blow down kill line 16:45 23:00 6.25 14,043 46 SLOT DRILL TRIP P Cont. POOH w/ clean out assembly f/ 14,043' to 595' (top of HWDP - flow ck(static) Std back HWDP 23:00 00:00 1.00 46 0 SLOT DRILL PULD P Change to 3 1/2" elevators & LD C/O BHA - recovered 2 large pieces of metal f/ packer on string magnets & several small pieces of metal in junk bskts. 10/03/2009 Cut & slip DL - MU whip stock assembly - RIH to 13,168' - Orient WS - Circ &Attempt to go in hole - unable to pass below 13,168' - Circ - POOH w/ WS assembl 00:00 00:30 0.50 0 0 SLOT DRILL PULD P Clera rig floor of bit, scraper,junk bskts, & string magnes Page 12 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ` Comment 00:30 02:00 1.50 0 0 SLOT DRILL SLPC P Cut & slip drill line 60' - service drawworks,top drive & iron ruffneck 02:00 06:30 4.50 0 127 SLOT WHPST PULD P MU whipstock assembly - 6 1/8" window mill, 5 7/8" watermellon mill, flex jt. 6.151" watermellon mill, XO, 1 jt. HWDP, XO, float sub, MWD componets ( DM HOC, SP4 MWD, TM HOC) - plug in & unload MWD - Shallow pulse test MWD - PU 7" btm. trip anchor & whipstock slide - MU to window mill - Obtain MWD offset data - PU bumper sub to 127' 06:30 16:00 9.50 127 13,168 SLOT WHPST TRIP P RIH w/ whipstck assembly w/ 18 jts HWDP f/127' to 676' - Cont. RIH w/ WS assembly w/ 4" DP f/ 676' to 13,168' (filling pipe every 20 stds) 16:00 16:45 0.75 13,168 13,168 SLOT WHPST OTHR P Orient whipstock - attempt slack off - unable to get pass 13,168' - Circ @ 230 gpm @ 1570 psi & work pipe - Still unable to get past 13,168' (btm of anchor) top of window mill @ 13,149' - top of lower WM mill ( 5 7/8" OD) @ 13,143' - Top of upper WM mill (6.151" OD) @ 13,131' 16:45 17:15 0.50 13,168 13,168 SLOT WHPST CIRC T Circ @ 230 gpm @ 1570 psi - PU wt. 245 SO wt 145 17:15 00:00 6.75 13,168 2,579 SLOT WHPST TRIP T Blow down top drive - Flow ck (static) POOH on TT f/ 13,168' to 2579' 10/04/2009 Finish POOH w/ WS assembly - LD WS assembly - MU Clean out assembly w/ mills - RIH - Ream through tight spots @ 13,147' - 13,728' to 13,787' - RIH & tag top of retainer @ 14,282' - Pump sweep & circ btms up - POOH w/ CO assembly - LD CO assembly - C &S drill line - MU whipstock assembly 00:00 01:00 1.00 2,579 127 SLOT WHPST TRIP T Cont. POOH w/ WS assembly f/ 2579' to 676' - Flow ck (static) Std back HWDP to 127' 01:00 03:00 2.00 127 47 SLOT WHPST PULD T LD MWD -& whipstock anchor /slide assembly - MU clean out assembly w/ window & string mills 03:00 09:00 6.00 47 13,147 SLOT DRILL TRIP T RIH w/ CO assembly w/ HWDP to 596' - Cont. RIH w/ CO assembly on 4" DP f/ 596' to 13,147' (string took wt.) 09:00 10:45 1.75 13,147 13,280 SLOT DRILL REAM T MU top drive - ream f/ 13,147' to 13,280' - pumping @ 6 bbls /min @ 1420 psi w/ 80 rpm's 10:45 11:00 0.25 13,280 13,725 SLOT DRILL TRIP T RIH f/ 13,280' to 13,725' (string took wt) 11:00 11:30 0.50 13,725 13,767 SLOT DRILL REAM T MU top drive - Ream f/ 13,725' to 13,767' - pumping @ 6 bbls /min @ 1500 psi w/ 80 rpm's 11:30 12:00 0.50 13,767 14,282 SLOT DRILL TRIP T RIH f/ 13,767' to 14,282' (tagged top of retainer) 12:00 13:30 1.50 14,282 14,282 SLOT DRILL CIRC T Pumped Hi -vis sweep & circ btms up @ 8 bbls /min @ 2410 psi w/ 60 rpm's w/ 12 k torque - increase pump to 8.5 bbls /min @ 2660 psi w/ no rotation - PU wt 240 SO wt 138 Page 13 of 26 410 4110 Time Logs Date From To Dur S. Depth E. Depth Phase `'Code Subcode T Comment 13:30 14:00 0.50 14,282 14,282 SLOT DRILL OWFF T Monitor well (static) Blow down TD 14:00 19:15 5.25 14,282 47 SLOT DRILL TRIP T POOH w/ CO assembly f/14,282' to 596' - Flow ck @ HWDP (static) Std back HWDP 19:15 20:15 1.00 47 0 SLOT DRILL PULD T LD CO assembly 20:15 20:30 0.25 0 0 SLOT RIGMNT SFTY T PJSM on cut & slip drill line - 20:30 21:45 1.25 0 0 SLOT RIGMNT SLPC T Cut & slip drill line 60' - Service top drive 21:45 00:00 2.25 0 127 SLOT WHPST PULD T MU whipstock assembly new window mill (6 /18" OD)- lower WM mill (5 7/8" OD) flex jt - Upper WM mill (6.151" OD) Xo - 1 jt. HWDP -XO- float sub - MWD componets ( DM HOC - SP4 MWD - TM HOC) - Plug in & unload MWD - Pluse test MWD - Pull up & MU btm trip anchor & whipstock slide to window mill - Obtain MWD offset 317.2? - 10/05/2009 RIH w/ WS assembly - Orient & set whipstock - Milled window f/ 14,264' to 14,277' (top & tbm of window) Milled to 14,316' ( putting top string mill 20" below btm of window) Pumped 2 hi -vis sweeps w/ super sweep & circ btms up while polishing window V 12,264' to 12,277' - slid toTD @ 14,316' with & with out pump window is smooth & no problem going to btm - Pull up to 14,205' - Monitor well 15 mins. (static) blow down TD & POOH f/ 14,205' to 12,296' on TT - PU wt. 255 k 00:00 00:15 0.25 127 127 SLOT WHPST PULD T MU bumper sudb & XO to 127' 00:15 09:00 8.75 127 14,220 SLOT WHPST TRIP T RIH w/ whipstock assembly w/ HWDP to 676' - Cont. RIH w /4" DP f/ 676' to 14,220' 09:00 10:15 1.25 14,220 14,282 SLOT WHPST WPST P PU 1 jt. 4" DP for milling - RIH to 14, 252' - Orient whipstock to 45? right of highside - MU std #143 & wash down to 14,276' - reorient WS to 45? right of highside - MWD survey 250 gpm @ 1840 psi - Set bottom anchor @ 14,282' - shear off of whipstock slide w/ window(brass bolt sheared @ 35 i K 10:15 20:00 9.75 14,282 14,316 SLOT WHPST WPST P Begin milling window @ 14,264' & milled to 14,316' @ 300 gpm @ 2550 psi w/ 80 rpms @ 15,500 ft/lbs torque rr° Note - Top of window @ 14,264' bottom of window @ 14,277' - with a61-11‘C milled depth of 14,316' - Top l� / watermellon mill is 20' below btm of window Page 14 of 26 I • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:45 1.75 14,316 14,316 SLOT WHPST CIRC P Pump hi -vis sweep w/ super sweep added & circ btms up @ 300 gpm @ 2350 psi w/ 80 rpm's @ 15.5 k torque - while working through window w/ mills - Pumped 2nd sweep & circ 2nd btms up - as sweeps come back observed very small amout of very small metal pieces form milling - worked mills through window & tagged btm w/ pumps @ 300 gpm @ 2350 psi - PU wt. 255 SO wt. 125 - Slide mills through window & tagged btm w/ no pump - PU wt. 275 SO wt. 140 - Window is smooth going through & coming back out 21:45 22:15 0.50 14,316 14,205 SLOT WHPST TRIP P Pull up to 14,205' ( std back 1 std DP & LD 1 DP 't. - Monitor well 15 1 DP) mins (static) blow down top drive 22:15 00:00 1.75 14,205 12,296 SLOT WHPST TRIP P POOH w/ milling assembly f/ 14,205' to 12,296' - PU wt. 255 10/06/2009 Continue to POOH w/ Milling Assembly U 127' MD - Read MWD Data and L/D Milling Assembly (Lower Mill 1/4" Under Gauge) - Test BOPE U 250/2500 and 250/3500 Psi - AOGCC Inspector Jeff Jones Waived Witnessing of BOPE Test - P/U BHA #9 and Attempt to Read MWD Data - Troubleshoot Communication Problem b/w Geo -Pilot and MWD - Replace Geo - Pilot, M/U Remainder of BHA #9 - Break In Geo -Pilot Bearings and Shallow Pulse Test MWD Tools 00:00 05:45 5.75 12,296 127 SLOT WHPST TRIP P Continue to POOH w/ Milling Assembly U 658' MD - Stand Back 2 Stands of HWDP then L/D 4 Stands of HWDP U 127' MD 05:45 07:15 1.50 127 0 SLOT WHPST PULD P Read MWD Data and L/D Milling Assembly 07:15 08:00 0.75 0 0 SLOT WHDBO PULD P Clean & Clear Rig Floor / Prep for BOPE Test - Pull Wear Ring and Install Junk Catcher in Well Head 08:00 09:45 1.75 0 0 SLOT WHDBO BOPE P Flush BOPE and Well Head - Blow Down & Pull Junk Catcher Ib, 09:45 15:30 5.75 0 0 SLOT WHDBO BOPE P Test BOPE w/ 4" and 4 1/2" Test Joints as Follows: Test Annular 1 Preventer U 250/2500 Psi, Upper and Lower Variable Pipe Rams U 250/3500 Psi, Test Choke Manifold Valves 1 -16, Auto /Manual IBOP, HCR & Manual Choke and Kill Valves, Dart, TIW, and 4" Demco to 250/3500 Psi - AOGCC Inspector Jeff Jones Waived Witnessing the Test 15:30 16:00 0.50 0 0 SLOT WHDBO BOPE P Pull Test Plug and Install Wear Ring 16:00 19:00 3.00 0 117 PROD2 DRILL PULD P P/U BHA #9 as Follows: 6 1/8" Bit, Geo - Pilot, NMFDC, Smart Stab, GR, Smart Stab, MWD Dir, ALD, CTN, PWD, HOC - Attempt to Upload MWD and Read Tools - Geo -Pilot _ Read Unsuccessful Page 15 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 22:45 3.75 117 117 PROD2 DRILL PULD T Troubleshoot GP /MWD Communication Error - Isolate GP and Test Flex Collar - Test GP - Replace GP - MWD Data upload /Read Successful 22:45 00:00 1.25 117 157 PROD2 DRILL PULD P Continue to P/U BHA #9: Stab, 2 - NMFDC, XO - Break in GP Bearings and Pulse Test MWD Tools 10/07/2009 PJSM - Load Nuclear Sources and Continue to P/U BHA #9 - RIH t/ 14,297' MD - Displace Wellbore Fluid t/ 10.3 PPG Flo -Pro - OWFF - Perform FIT t/ 12.6 PPGE - Wash /Ream t/ 14,316' MD - Drill 6 1/8" Hole t/ 14,448' MD 00:00 00:45 0.75 157 414 PROD2 DRILL PULD P PJSM - Load Nuclear Sources and P/U Remainder of BHA #9 t/ 414' MD 00:45 07:00 6.25 414 14,297 PROD2 DRILL TRIP P RIH V 14,297' MD, Filling Pipe Every 20 Stands 07:00 09:45 2.75 14,297 14,297 PROD2 DRILL CIRC P PJSM - Displace Wellbore Fluids t/ 10.3 PPG Flo -Pro - 200 GPM @ 1950 Psi 09:45 10:15 0.50 14,297 14,297 PROD2 DRILL OWFF P OWFF - Initially Slight Flow then Static 10:15 11:00 0.75 14,297 14,297 PROD2 DRILL FIT P R/U and Perform FIT t/ 12.6 PPGE (Successful) 11:00 11:30 0.50 14,297 14,316 PROD2 DRILL REAM P Wash /Ream f/ 14297' - 14316' MD (Bottom) - 200 GPM @ 1780 Psi, 40 RPM 11:30 00:00 12.50 14,316 14,448 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 14316' - 14448' MD P/U 230 , S/O 140, Rot 190 Torque On /Off 15,000/14,500 @ 60 RPM 220 GPM @ 2500 Psi / ECD 11.66 10/08/2009 Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 14,448' - 15,350' MD 00:00 12:00 12.00 14,448 14,563 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 14448' - 14563' MD P/U 230 , S/O 150, Rot 189 Torque On /Off 12,500/12,500 @ 50 RPM 200 GPM @ 2100 Psi / ECD 11.99 12:00 00:00 12.00 14,563 15,350 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 14563' - 15350' MD P/U 242, S/O 141, Rot 189 Torque On /Off 16,000/13,000 @ 140 RPM 220 GPM @ 2450 Psi / ECD 12.00 10/09/2009 Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 15,350' - 16,820' MD - Completed 275 Bbl Whole Mud Dilutions at 15,500' and 16,400' MD Page 16 of 26 • Time Logs Date From To Dur? S. Depth E. Depth Phase ; Code Subcode T Comment 00:00 12:00 12.00 15,350 16,154 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 15350' - 16154' MD - Completed 275 BbI Whole Mud Dilution at 15,500' MD - Added 776 to Maintain System Lubrication @ 2% P/U 230, S/0 138, Rot 185 Torque On /Off 16,000/14,000 @ 120 RPM 220 GPM @ 2480 Psi / ECD 12.04 12:00 14:30 2.50 16,154 16,336 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 16154' - 16336' MD P/U 247, S/O 138, Rot 185 Torque On /Off 15,500/12,000 @ 120 RPM 200 GPM @ 2510 Psi / ECD 12.11 14:30 15:30 1.00 16,336 16,336 PROD2 DRILL CIRC T High Line Power Down - Circulate @ 200 GPM w/ 2140 Psi While Rotating and Reciprocating Pipe 15:30 16:15 0.75 16,336 16,336 PROD2 DRILL CIRC P Highline Power Restored - Continue Complete Circulation Prior to Drilling 16:15 00:00 7.75 16,336 16,820 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 16336' - 16820' MD - Completed 275 Bbl Whole Mud Dilution at 16,400' MD - Added Lube 776 to System to Increase Concentration to 2.25% for High Torque P/U 253, S/O 135, Rot 175 Torque On /Off 16,000/19,000 @ 120 RPM 220 GPM @ 2530 Psi / ECD 12.10 10/10/2009 Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 16,820' - 18,127' MD - Completed 2 - 275 Bbl Whole Mud Dilutions at 17,100' and 17,800' MD Lost 326 Bbls of Mud to the Formation in the Previous 24 Hours - Hourly Losses Average 10 -15 BPH Total Mud Lost to Hole 359 Bbls 00:00 06:00 6.00 16,820 17,203 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 16820' - 17203' MD - Completed 275 BbI Whole Mud Dilution at 17,100' MD, Added Lube 776 to System to Maintain 2 - 2.25% Concentration P/U 245, S/0 132, Rot 182 Torque On /Off 16,500/14,000 @ 120 RPM 220 GPM @ 2590 Psi / ECD 12.20 06:00 12:00 6.00 17,203 17,540 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 17203' - 17540' MD P/U 254, S/0 135, Rot 187 Torque On /Off 16,500/14,000 @ 140 RPM 220 GPM @ 2640 Psi / ECD 12.27 Page 17 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 17,540 17,830 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 17540' - 17830' MD - Completed 275 Bbl Whole Mud Dilution @ 17,800' MD; Added Lube 776 to System to Maintain 2% Concentration P/U 245, S/0 135, Rot 187 Torque On /Off 17,000/14,000 © 140 RPM 212 GPM @ 2520 Psi / ECD 12.12 18:00 00:00 6.00 17,830 18,127 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 17830' - 18127' MD P/U 250, S/O 133, Rot 187 Torque On /Off 16,500/14,500 @ 120 RPM _220 GPM @ 2670 Psi / ECD 12.38 10/11/2009 Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 18,127' - 18,350' MD - Circ & Condition to Clean Hole and Lower ECD's - ECD 12.46 Prior to Circulation and 12.22 Immediately After - Continued to Drill Lateral f/ 18,350' - 19,221' MD Completed 275 Bbl Whole Mud Dilutions @ 18,200' & 18,750' MD - Adding Lube 776 to System to Maintain 1 1/2 - 2% Concentration Lost 414 Bbls of Mud to the Formation in the Previous 24 Hours - Hourly Losses Average 15 - 20 BPH Total Mud Lost to Hole 773 Bbls 00:00 04:30 4.50 18,127 18,350 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 18127' - 18350' MD P/U 245, S/O 135, Rot 190 Torque On /Off 16,000/14,000 @ 120 RPM 210 GPM @ 2590 Psi / ECD 12.46 04:30 06:00 1.50 18,350 18,350 PROD2 DRILL CIRC P Circulate and Condition Mud - Pump 275 Bbl Whole Mud Dilution @ 06:00 12:00 6.00 18,350 18,633 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 18350' - 18633' MD P/U 240, S/O 135, Rot 181 Torque On /Off 17,000/14,000 @ 120 RPM 220 GPM @ 2750 Psi / ECD 12.43 12:00 18:00 6.00 18,633 18,950 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 18633' - 18950' MD P/U 240, 5/0 135, Rot 181 Torque On /Off 18,000/14,000 @ 120 RPM 220 GPM @ 2720 Psi / ECD 12.33 18:00 00:00 6.00 18,950 19,221 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 18950' - 19221' MD P/U 240, S/0 135, Rot 181 Torque On /Off 18,000/14,000 @ 120 RPM 220 GPM @ 2720 Psi / ECD 12.33 Page 18 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/12/2009 24 hr Summary Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 19,221' - 19,678' MD - Drilled Fault at 19,327' MD - Loss Rate Initially Increased to 120 BPH Accompanied by a 300 Psi Drop in Stand Pipe Pressure - Lowered Pump Rate and Loss Rate Decreased to 76 BPH - Added LCM to System at 2 PPB Concentration and Pumped a 40 Bbl, 20 PPB LCM Pill - Loss Rate Decreased to 25 - 30 BPH - Pumped Two More 40 Bbl, 20 PPB LCM Pills @ 19,390' and 19,650' MD Due to Loss Rate Increases to 56 BPH and 40 BPH Respectively Completed 275 Bbl Whole Mud Dilution @ 19,303 MD - Adding Lube 776 to System stem to Maintain 1 1/2 - 2% Y Concentration Lost 735 Bbls of Mud to the Formation in the Previous 24 Hours - Hourly Losses Average 22 -35 BPH Total Mud Lost to Hole 1,508 Bbls Page 19 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 19,221 19,355 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19221' - 19355' MD - Completed 275 Bbl Whole Mud Dilution @ 19,303' MD Crossed a Fault at 19327' MD; Observed Flow Decrease f/ 19 to 3% (Verified Visually), Pump Pressure Dropped 300 Psi - Reduced Pump Rate to 180 GPM and Flow Increased to Previous Levels - Pulled Off Bottom & Shut Pumps Down - OWFF; Initially Observed Flow and Registered 14% on Mud Watch, Flow Decreased and Fluid Level was 2" Below Flow Line in 15 Minutes - Attempted to Continue Drilling at 210 GPM - Initial Loss Rate was 120 BPH - Lowered Rate to 190 GPM and Initial Loss Rate was 76 BPH - Treated Losses by Adding Dyna Red Medium at 2 PPB Concentration and Pumped Two 40 Bbl, 20 PPB LCM Pills - Loss Rate Decreased to 25 - 30 BPH Before the 1st Pill Left the Drill String - Losses Stabilized at 25 -30 BPH for 1.5 Hours - Staged Rate Up f/ 190 to 210 GPM - Loss Rate Increased to 60 BPH @ 210 GPM - Reduced Pump Rate to 200 GPM and Loss Rate Stabilized at 25 - 35 BPH - Continued Drilling Ahead Throughout Operations Estimate Initial Loss at 60 -80 Bbls to Fault - Initial Losses Occurred as a 275 Dump /Dilution was in Progress Preventing Accurate Volume Accounting Until all Dumping and Additions were Shut Down. Parameters Prior to Fault: P/U 255, S/O 124, Rot 186 Torque On /Off 18,000/15,000 @ 120 RPM 210 GPM @ 2650 Psi / ECD 12.33 Initial Parameters After Crossing Fault: P/U 245, S/O 124, Rot 186 Torque On /Off 17,000/15,000 @ 120 RPM 210 GPM @ 2430 Psi / ECD 11.83 Parameters @ 0600 Hrs: P/U 245, S/0 125, Rot 185 Torque On /Off 17,500/14,500 @ 120 RPM Page 20 of 26 . • Time Logs Date From To Dur S. Depth E. Depth Phase :, Code Subcode T Comment 200 GPM @ 2460 Psi / ECD 11.88 06:00 12:00 6.00 19,355 19,455 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19355' - 19455' MD - Loss Rate Increased to 56 BPH @ 19,390' MD - Pumped 40 Bbl, 20 PPB LCM Pill and Losses Decreased to 25 -30 BPH P/U 245, S/O 125, Rot 185 Torque On /Off 17,500/14,500 @ 120 RPM 200 GPM @ 2460 Psi / ECD 11.89 12:00 18:00 6.00 19,455 19,585 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19455' - 19585' MD P/U 245, 5/0 125, Rot 185 Torque On /Off 18,500/14,500 @ 120 RPM 200 GPM @ 2520 Psi / ECD 12.08 18:00 00:00 6.00 19,585 19,678 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19585' - 19678' MD - Loss Rate Increased @ 19650' MD - Pumped 40 bbl, 20 PPB LCM Pill - Losses Decreased to 15 - 25 BPH - Continued to Add LCM to System @ 2 PPB Concentration P/U 245, S/O 122, Rot 184 Torque On /Off 16,500/14,500 @ 120 RPM 200 GPM @ 2590 Psi / ECD 12.19 10/13/2009 Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 19,678' - 20,510' MD - Completed 2 - 275 Bbl Whole Mud Dilutions @ 19,738' and 19,970' MD - Loss Rate Gradually Increased f/ 16 - 40 BPH Over 23 Hour Period - Appeared to Drill a Fault @ 20,500' MD, Loss Rate Initially Increased to 90 BPH and Declined to 60 BPH - Pumped 20 PPB LCM Pill and Continued to Add LCM to Active System at 2 PPB Concentration Lost 520 Bbls of Mud to the Formation in the Previous 24 Hours - Hourly Losses Average 16 - 34 BPH Total Mud Lost to Hole 2,028 Bbls 00:00 06:00 6.00 19,678 19,770 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19678' - 19770' MD - Continue to Add Dyna Red Medium @ 2 PPB Concentration - Loss Rate 16 -20 BPH P/U 245, S/0 122, Rot 184 Torque On /Off 16,500/14,500 @ 120 RPM 200 GPM @ 2590 Psi / ECD 12.19 Page 21 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 19,770 19,933 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19770' - 19933' MD - Continue to Add Dyna Red Medium @ 2 PPB Concentration - Completed 275 Bbl Whole Mud Dilution @ 19738' MD - Added Lube 776 to System to Maintain 1 1/2 - 2% Concentration - Loss Rate 24 -32 BPH P/U 258, S/O 120, Rot 185 Torque On /Off 17,500/14,500 @ 120 RPM 200 GPM @ 2460 Psi / ECD 12.24 12:00 18:00 6.00 19,933 20,235 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 19933' - 20235' MD - Completed 275 Bbl Whole Mud Dilution @ 19,970' MD - Added Lube 776 to System to Maintain 1 1/2 - 2% Concentration - Added Dyna Red Medium to System @ 2 PPB Concentration - Loss Rate 20 - 30 BPH P/U 258, S/O 116, Rot 180 Torque On /Off 18,000/15,500 @ 120 RPM 200 GPM @ 2430 Psi / ECD 12.24 Page 22 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 20,235 20,510 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 20235' - 20510' MD - Added Dyna Red Medium to System @ 2 PPB Concentration - Loss Rate Gradually Increased Over Tour f/ 20 to 40 BPH Appeared to Cross Faulted /Fractured , Zone at 20,500' MD - Loss Rate Increased f/ 40 BPH to 90 BPH - Initially Lost 100 Psi of Pump Pressure and 2% of Flow - Hole Took 90 Bbls then Rate Decreased to 60 BPH - Pumped 35 Bbl 20 PPB LCM Pill & Continued Adding LCM to System at the 2 PPB Concentration - The Fault/Fracture did Not Show Up on MWD Logs P/U 250, S/O 118, Rot 175 Torque On /Off 18,500/15,000 @ 120 RPM 200 GPM @ 2500 Psi / ECD 12.30 Note: Observed Well for Flow During Connection @ 20541' MD: Mud Watch Measured Flow at 15% and Decreased to 3% in 20 Minutes - Visually Verified Flow Decrease Over 20 Minute Period at the Flow Line - Initial SPP was 330 Psi During Event and Decreased Slowly Throughout - Registered a 30 bbl Gain in Pits on PVT 10/14/2009 Drilled 6 1/8" Lateral w/ Geo -Pilot f/ 20,510' - 21,001' MD - Completed 275 Bbl Whole Mud Dilution 20,900' MD - Pumped 35 Bbl 20 PPB LCM Sweep at 20, 535' & 20,635' MD Lost 302 Bbls of Mud to the Formation in the Previous 24 Hours - Drilling Loss Rate Averaged 20 - 40 BPH - Ak Losses While Back Reaming = 61 Bbls - Total Mud Lost to Hole 2,330 Bbls 00:00 08:45 8.75 20,510 21,001 PROD2 DRILL DDRL P Drill 6 1/8" Hole w/ Geo -Pilot f/ 20510' to 21,001' MD / 7453' TVD - Added Dyna Red Medium to System @ 2 PPB Concentration - Loss Rate ave. 20 to 40 BPH P/U 255, S/O NA, Rot 176 Torque On /Off 19,000/15,500 @ 120 RPM 200 GPM @ 2480 Psi / ECD 12.18 ADT= 7.08 hrs. 08:45 13:15 4.50 21,001 20,446 PROD2 DRILL CIRC P CBU X 3 200 gpm / 2380 psi / 120 rpm Stood back one stand / 30 min. to 20,446' ECD= 11.93 13:15 00:00 10.75 20,446 14,725 PROD2 DRILL REAM P BROOH f/ 20,445' - 14,725' MD - 200 GPM @ 2200 Psi, 120 RPM Loss During Reaming 61 Bbls Page 23 of 26 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/15/2009 24 hr Summary BROOH f/ 14,725' - 14,626' MD - Pull Out of Hole w/ Pumps t/ 14,128' MD - Observe Well and Monitor Flow Back, Initilally Flowed at 15 BPH and Decreased to 0.17 BPH Over 6 Hours - Weight Up to 10.6 PPG - Pull Out of Hole w/ Pumps t/ 5,945' MD - OWFF (Static), POOH on TT t/ 414' MD - Begin UD BHA #9 00:00 01:45 1.75 14,725 14,148 PROD2 DRILL TRIP P BROOH f/ 14,725' - 14,626' MD - POOH w/ pump to 14,148' - No problems pulling bha through window 200 GPM @ 1900 Psi Losses 7 Bbls to hole 01:45 07:45 6.00 14,148 14,148 PROD2 DRILL OWFF P Monitor well breathing - Line up returns to trip tank and track return rate / time - Initial Rate 15 bph - Final Rate 0.17 bph - 10.5 bbls total gain Slipped and cut Drilling line - Service top drive and drawworks - Rigged down and remove Geo -Span skid from rig floor 07:45 10:15 2.50 14,148 14,148 PROD2 DRILL CIRC P Circulate and condition mud - 4 bpm / 1500 psi / 30 rpm - Increased mud wt. from 10.3 ppg to 10.6 ppg - obtain SPR 3 bpm / 920 psi - Shut down pumps - flow indicator dropped from 14% to 0% in 4.5 minutes - Lost 5 bbls to hole while circulating • 10:15 19:30 9.25 14,148 5,945 PROD2 DRILL TRIP P POOH while Pumping 2 BPM f/ 14,148' - 5,945' MD 19:30 20:00 0.50 5,945 5,945 PROD2 DRILL OWFF P Pull Air Slips and Stripping Rubber - OWFF (Static) - Moved Pipe Up and Down No Swabbing - Install Stripping Rubber and Air Slips - Line Up on TT 20:00 23:00 3.00 5,945 414 PROD2 DRILL TRIP P POOH on TT f/ 5,945' - 414' MD - Displacement for this Interval 14 Bbls Long 23:00 00:00 1.00 414 219 PROD2 DRILL PULD P UD BHA #9 as Follows: 4 Jts HWDP, 4 3/4" Bumper Sub, 1 Jt HWDP, 4 3/4" Jars 10/16/2009 Remove Nuclear Sources and Reading MWD Data - UD Remainder of BHA #9 - R/U and Run 4 1/2" Upper Completion per Detail and Land Same @ 13,257' MD - Set TWC - Test Hanger - N/D BOPE and N/U Tree 00:00 03:45 3.75 219 0 PROD2 DRILL PULD P PJSM - Remove Nuclear Sources & Read MWD Data - Continue to UD BHA #9 03:45 04:15 0.50 0 0 COMPZ RPCOM PULD P Pull Drilling Wear Ring & Install Tubing Running Wear Ring in Well Head 04:15 04:45 0.50 0 0 COMPZ RPCOM RURD P R/U to Run 4 1/2" IBTM Upper Completion 04:45 18:00 13.25 0 13,220 COMPZ RPCOM RCST P Run 4 1/2" IBTM Upper Completion as Follows: Mule Shoe, 10' Pup Jt, 1 Jt Tubing, XN Nipple, 1 Jt Tubing, Baker "Premier" Packer w/ Top & Bottom XO's, 5 Jts Tubing, Baker "Premier" Packer w/ Top and Bottom XO's, 2 Jts Tubing, KBG -2 GLM w/ DCK -2 SOV and Pups, 244 Jts Tubing, DB Nipple & 52 Jts Tubing Page 24 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:45 0.75 13,220 13,257 COMPZ RPCOM THGR P Pull Wear Ring - P/U and Land Tubing Hanger w/ Tubing Tail @ 13,257' MD - Run In Lock Down Screws 18:45 20:15 1.50 13,257 0 COMPZ RPCOM THGR P Set TWC and Test Tubing Hanger t/ 250/5000 Psi f/ 5 Minutes - Clear Rig Floor of Equipment 20:15 00:00 3.75 0 0 COMPZ WHDBO NUND P N/D Riser, Hole Fill, Drain Lines & BOPE - Nipple Up Tree - Rig Up Hole Fill to IA to Keep Hole Full Static Loss Rate 1 BPH 10/17/2009 Test Tree to 250/5000 Psi f/ 15 Minutes - Pull TWC w/ FMC Lubricator - R/U Squeeze Manifold and Surface Lines then Test Same to 2500 psi - Displace 106 PPG Flo -Pro by Pumping 218 Bbls of 6% KCL, 56 Bbls of Inhibited KCL, 163 Bbls of 6% KCL and 85 Bbls of Diesel - Initial SITP 700 Psi, Initial SICP 50 Psi - Allowed Diesel to U -Tube to Annulus Through the Squeeze Manifold - Final SITP /SICP 500 Psi - Drop Ball and Rod - P/T Surface Lines t/ 5000 Psi - Set Packer w/ 4,500 Psi - Bled Tubing Pressure t/ 2000 Psi Through Squeeze Manifold to the Annulus - Test IA and Top Packer t/ 3500 Psi f/ 30 Minutes - Bled Pressures and Set BPV - R/U and L/D 4" DP f/ the Derrick Note - Final SITP 1000 Psi 00:00 00:45 0.75 0 0 COMPZ WHDBO SEQP P RU and test tree 250/5000 psi - Test hanger void 5000 psi for 15 minutes 00:45 01:30 0.75 0 0 COMPZ WHDBO OTHR P RU and test FMC lubricator to 1000 psi - Pull TWC - RD FMC lubricator 01:30 02:00 0.50 0 0 COMPZ RPCOM RURD P RU hardlines and manifold to tree connections tubing / annulus 02:00 02:15 0.25 0 0 COMPZ RPCOM SFTY P Held Prejob Safety and Opts meeting for displacing well to brine 02:15 06:45 4.50 0 0 COMPZ RPCOM CIRC P Well Displacement - Rig pumped 35 bbls of viscosified mud - Lined up to Dowell - Tested lines to 2500 psi - Dowell pumped down tubing - 218 bbls of 10.0 ppg kcl /nacl brine - 56 bbls of 10.0 ppg corrosion inhibited kcl /nacl brine - 163 bbls of 10.0 ppg kcl /nacl brine and 85 bbls of diesel all fluids pumped at 3 bpm / 376 psi - 858 psi - Initial shut in pressures Tubing 700 psi annulus 50 psi - open across manifold and allow diesel to U -tube down annulus - tbg. press. =500 psi annulus press. = 500 psi 06:45 07:30 0.75 0 0 COMPZ RPCOM PACK P RU Doyon lubticator and drop setting ball /rod Page 25 of 26 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 10:15 2.75 0 0 COMPZ RPCOM DHEQ P Line up to Dowell - PT lines to 5000 psi - Set packers with 4600 psi - test tubing for 30 minutes bled to 4475 psi - bled down tubing to 2200 psi - pressure up annulus to 3500 psi - monitored pressure 15 minutes - had slight communication tbg /annulus - troubleshoot surface equipment - attempted second test with additional isolation valves closed same results - isolated PT to annulus - tested annulus to 3400 psi bled 20 psi in 30 minutes - Bled down tubing to 500 psi - pressured up on annulus and sheared DCK -2 valve open - bled system pressure to 1000 psi and shut in tubing and annulus valves on tree. 10:15 11:15 1.00 0 0 COMPZ RPCOM RURD P Flush and blow down lines - RD hardlines and manifold 11:15 12:45 1.50 0 0 COMPZ WHDBO OTHR P RU and test FMC lubricator to 2000 psi - Install BPV - RD FMC lubricator - secure wellhead - address housekeeping in cellar 12:45 00:00 11.25 0 0 COMPZ MOVE PULD P Lubricate Rig and UD 4" DP via the Mouse Hole 10/18/2009 Lay down 4" drill pipe for rig move - Released rig at 0800 hours 00:00 08:00 8.00 0 0 COMPZ MOVE PULD P Lay down 4" drill pipe in mousehole Release rig @ 0800 hours Page 26 of 26 10 WELL LOG TRANSMITTAL To: State of Alaska October 28, 2009 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD2 -60A AK -MW- 0006820996 CD2 -60A 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50 -103- 20511 -01 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50- 103 - 20511 -01 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50- 103 - 20511 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. a09 — /(3 7 5 55 f Anchorage, Alaska 99518 Office: 907 - 273 -3536 Fax: 907 - 273 -3535 Bryan.Burinda @halliburton.com Aran NOV 0 5 7009 Date: �� � 0 , Signed: Alaska i 'as , • ., anchorage Page 1 of 1 Schwartz, Guy L (DOA) From: Anderson, Nina M [ Nina .Anderson @conocophillips.com] Sent: Monday, October 05, 2009 1:04 PM To: Schwartz, Guy L (DOA) pr 1•� 201 115 Subject: CD2 -60A Injector AOR V Guy, As a follow up to the recently submitted CD2 -60A permit to drill application, a list of wells that fall under the AOR Injection guidelines have been listed. There are three wells within a % mile radius of the planned CD2 -60A Alpine injector. These wells include CD4- 16, CD3 -319, and Nanuq 3. CD4 -16 is an Alpine A producer well that has a cemented intermediate casing shoe. CD3 -319 is a Kuparuk well that also has a cemented intermediate casing shoe, and is geologically isolated from the Alpine reservoir. Nanuq 3 is an exploration well that was plugged and abandoned in 2007. This well was never completed although it does have intermediate casing and all hydrocarbon zones cemented. Please let me know if you have any questions. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)- 265 -6403 Cell: (907) 575 -3256 10/5/2009 CD2 -60A Page 1 of 2 Schwartz, Guy L (DOA) From: Robertson, Ryan G [ Ryan .G.Robertson @conocophillips.com] Sent: Friday, October 02, 2009 9:36 AM en) CI — //5 To: Schwartz, Guy L (DOA) Cc: Galiunas, Elizabeth C; Chambers, Mark A; Anderson, Nina M Subject: RE: CD2 -60A Guy, Thank you for your response. Unfortunately we were unable to test the integrity of the casing and cement retainer below 13,109' MD yesterday night as planned. After the crews had established that there was a hole in the 7" casing between 12,950' MD and 13,109' MD using a Baker Retrieve -o -matic test packer, they attempted to run back to 13,109' MD to test the integrity of the casing and retainer below that depth. To do this, the test packer had to be unseated at 12,950' MD, which required the driller to apply left hand torque to it. It is felt that at this point a drill pipe connection loosened. This caused the pressure test below 13,109' MD to fail once the crews got the test packer reset at that depth. At this point it was a priority to trip the packer and drill string from the hole and re- torque the drillpipe connections to avoid worsening the problem and prevent a possible fishing job. Two loose connections were found during the trip out, one at 60' below the table, and one roughly 5 stands below that. It should be noted that the pressure decline profile of the failed test below 13,109' MD did not match the previous failed tests performed when the suspected hole area was responsible for the loss in pressure. The pressure decline on this last test was more pronounced and linear. It is strongly felt that the test failed due to the backed off drillpipe, and the integrity of the casing and retainer below 13,109' MD has not been compromised. It is also understood that it is not a State requirement to have a full integrity test on the cement retainer. Please do not hesitate to call if you have any questions or concerns, Ryan From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, October 02, 2009 8:31 AM To: Robertson, Ryan G Cc: Galiunas, Elizabeth C; Anderson, Nina M; Chambers, Mark A Subject: RE: CD2 -60A Ryan, Thank you for the update. Your plan forward is reasonable and you have verbal approval to move ahead as outlined below. Nina, Still need the AOR review statement. I can't tell if there are any Alpine penetrations with % mile of the new well with the data supplied. Thanks, Guy Schwartz Senior Petroleum Engineer 10/2/2009 CD2 -60A • Page 2 of 2 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Robertson, Ryan G [mailto: Ryan. G.Robertson @conocophillips.com] Sent: Thursday, October 01, 2009 4:36 PM To: Schwartz, Guy L (DOA) Cc: Galiunas, Elizabeth C; Anderson, Nina M; Chambers, Mark A Subject: CD2 -60A Guy, It has been determined on that there is a hole in the 7" casing on the CD2 -60A wellbore. The hole, located between a depth of 13,109' MD and 12,950' MD, was found today through a series of pressure tests using a 7" test packer. Due to hole problems that included wellbore breathing and gas to surface on the originally planned open hole sidetrack, it was decided to isolate the CD2-60 lateral wellbore. This was done by setting a cement retainer at 14,275' MD. Once this retainer was set in place, 30 bbl of cement was pumped below it, and then the running assembly was pulled from the hole. At that point, an attempt was made to pressure test the 7" casing to 3,500 psi. Unfortunately the casing would not hold the test. It was initially speculated that the cement retainer that was ran in the hole and set at a depth of 14,275' MD was responsible for the failed pressure tests. To prove this, a test packer was ran in the hole, as there was also concern that the casing may have been compromised while pulling the packer. The drill crews tested the casing above the testing tool without issue from 5,000', and then from 10,000' MD. After that, it was determined through a pair of tests that the 7" casing was good above 12,950' MD, however at 13,109' MD, the casing leaked in a similar fashion to that of the initial failed tests. The packer was set at 13,033' MD, which falls into this depth window, further supporting the case that removing the packer from the hole is what compromised the integrity of the casing. The plan forward is to test the casing and retainer below 13,109' MD. From that point the test packer will be pulled from the hole, and a clean out assembly will then be ran to ensure the casing is free of any cement prior to running the whipstock. Once the hole is drilled, the window from 12,950' MD to 13,109' MD will be isolated by means of straddle packers. Please let me know if you have any questions or concerns, Ryan Robertson Drilling Engineer I ConocoPhillips Alaska I Direct: (907) 263 -6318 I Mobile: (907) 980 -5107 10/2/2009 • a � �r " g � ` ' � @ g SEAN PARNELL, GOVERNOR I ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION "s ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Colville River Field, Alpine Oil Pool, CD2 -60A ConocoPhillips Alaska, Inc. Permit No: 209 -115 Surface Location: 2162' FNL, 1491' FEL, SEC. 2, T11N, R4E Bottomhole Location: 3663' FNL, 627' FEL, SEC. 23, T11N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to re -drill 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. r Chair n m.l DATED this 2 day of October, 2009 cc: Department of Fish 86 Game, Habitat Section w/o end. Department of Environmental Conservation w/o end. RECEIVED STATE OF ALASKA SEP 2 9 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1 c. Specify if well is proposed for: Drill ❑ Re -drill El Stratigraphic Test ❑ Service El Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone El Shale Gas ❑ 2. Operator Name: 5. Bond: H/ Blanket Li Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 CD2 - 60A 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 21053' TVD: 7467 Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Alpine Oil Pool Surface: 2162FNL, 1491FEL, SEC2, T11N, R4E ADL 380075, 380077 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2943FNL, 3646FEL, SEC14, T11N, R4E ` 380075 9/30/2009 Total Depth: 9. Acres in Property: 14. Distance to 3663FNL, 627FEL, SEC23, T11N, R4E ' 2560 Nearest Property: 1.75 mi to Alpine PA 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 52 feet 15. Distance to Nearest Surface: x - 371743 y - 5974194 Zone 4 KB Elevation above GL: 37 feet Well within Pool: CD4 -319 at 194' 16. Deviated wells: Kickoff depth: 14,257' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89° deg Downhole: 3378.8175 psig Surface: 2632.1175 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 6.125 4.5 12.6# L -80 IBTM 13802 32 32' 13834 7307 Production Tubing 6.125 N/A N/A N/A N/A 21,023' 13834 7307 21053' 7467' Open Hole 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) 18,695 7,376 14,270 7,373' Casing Length Size Cement Volume MD TVD Conductor /Structural 77' 16" Pre Installed 114 114' Surface 3,239' 9 -5/8" 550 sx ASLite, 10.7 ppg, 'G' 3,276' 2,373' Intermediate 14,294' 7" 315 sx, 15.8 ppg, Class 'G' 14,331' 7,379' Open Hole 18,658' 6 -1/8" N/A 18,695 7,376' Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Liz Galiunas - 265.6247 Printed Name G. L. Alvord Title Alaska Drilling Manager Signature :� ,/) / /� _ ,4/ v c o / �.. 4 T " ^' a U / / Commission Use Only Permit to Drill API Number: Permit Approval ///^^^ See cover letter Number: �O9 f,� 50D�,� ./ /a/O I Date: /D / e I for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produe= coalbe m ne, gas hydrates, or gas contained in shales: d ,>L 350D Sc. QO �¢ .S f Samples req'd: Yes /Vo Mud log req'd: Yes ❑ No d Other: p T , 1-12S measures: Yes No Yr Directional svy req'd: Yes [� No ❑ 0 Z$Da /0,54..., s. / n,...(4.. r ICSt „�.:„ 1 /� T C A,� / '' ,AI t + lh 4G . W • /4 1c 18c, 1 On J 4 631.14 631.14 a 1 v`' `� ��� •e APPROVED BY TOE/COMMISSION DATE: - W� / r ALA 1 , C, COMMISSIONER Form 10 -401 (Revised 1/2009) Submit in Duplicate S3" • • CD2- 60ADrilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6 -1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material additions. Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, keep mud weight above 8.8 ppg. Check Pressure for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H drills, detection systems, alarms, standard well control practices, mud scavengers. ORIGINAL • r Rig Procedure 1. After Cement retainer is set at 14,277' MD and 30 bbls of cement pumped to plug the productive interval on CD2- 60, a Whipstock is run in hole to 14257' MD. Orient the whipstock 45° right and set whipstock. 2. Mill window out of the 7" casing starting at —14,257' MD. 3. Drill 20' of hole to get kicked off from the casing. 4. POOH and pickup drilling BHA (DIR/PWD /RES /GAMMA/DENS /NEUTRON) 5. Drill 6 -1/8" horizontal section to well TD of 21,053' MD / 7,467' TVD. 6. Circulate hole clean and pull out of hole. 7. Run 4 -1/2 ", 12.6 ppf, L -80 tubing with 4 -1/2" Camco DB Nipple (to land Camco Al injection valve), 4 -1/2" KBG -2 gas lift mandrel, 4 -1/2" x 7" Baker Premier packer, XN nipple and 4 -1/2" tubing tail extension (± 1,500' MD) . 8. Land Hanger. 9. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 10. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. 11. Remove 2 way check. 12. Displace well to corrosion inhibitor and freeze protect. 13. Record tubing pressure. 14. Rig up lubricator. Drop RHC ball and rod. 15. Set Premier packer with 4,000 psi plus recorded tubing pressure (Approx. 4,800 psi). 16. Test tubing and tubing- casing annulus separately to 3500 psi / 30 mins. 17. Bleed off tubing pressure. 18. Install BPV and secure well. 19. Move rig off. OR\ GIN Al • • WELL PROXIMITY RISKS Directional drilling and collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4 -319 is the nearest existing well to the CD2 -60A plan with 194' well to well separation at 21,040' MD. DRILLING AREA RISKS There are no high risk events. A fault with a throw of roughly 10 to 20' is expected roughly 4,500' from the heel section of the well. Normal to high pressure is expected on the north side of this fault once it is crossed. To reduce the chances of encountering high pressure, the nearby CD2 -55 injection well will be shut in prior to spud. Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. DRILLING FLUID PROGRAM 6 -1/8" Production Hole Section Density 10.3 ppg PV 10 —15 YP 25 -30 Funnel Viscosity Initial Gels 10 —15 10 minute gels 12 - 20 API Filtrate HPHT Fluid Loss at 160 12 - 14 cc /30 min PH 9.0 -9.5 KCL 6 % Production Hole Section: The horizontal production interval will be drilled with an MI Flo Pro drill -in fluid. The base fluid will consist of 6% KCI, with ± 30 ppb calcium carbonate bridging material to minimize formation damage. Flo -Vis Polymer and Dual -Flo starch will be used for viscosity and fluid loss control respectively. ORG1NAL • CD2 -6OA Sidetrack Schematic / CD2 -60 Top of Whipstock: 14257' MD 14' Bottom of Whipstock / Top of Anchor: 14271' MD C D2 -60A Cement Retainer: 14277' (1.5' Length) Space: : 8.4' St 1 Il in 1 F u joint: J : 14287 3 ` D / 7379' TVD 7" Casing: 14330' M CD2 -60 Original Lateral: 18695' MD / 7376' TVD 0gi61 0 • CD2 -60A PROPOSED COMPLETION Alpine CD2 -60A Injection Well Completion ' C • Updated — 09/30/09 : : „., 'iiiim 16” Conductor to 114' TI 4 -1/2" Camco DB Nipple (3.812" profile) iMi! "` "'' at 2,300' MD = 1,901' TVD 4 9 -5/8" 36 ppf J -55 BTC Surface Casing at 3,276' MD / 2,373' TVD Cemented to surface Upper Completion MD TVD 1) FMC Tubing Hanger 32' 32' 4 -'/ ", 12.6#/ft, IBT -Mod Tubing 4 -1/2" 12.6 ppf 2) 4 -'/ ", Camco 3.812" DB Profile Nipple 2,300' 1,901' L -80 IBT -Mod (f/ Future A -1 Injection Valve installation) 4-W, 12.6 # /ft, IBT -Mod Tubing 3) 4 -Y2" Camco KBG2 -GLM (3.909" ID) w/ DCK -2 12,900' 6,979' shear (set at 2,500 psi annulus to tubing) 4-Y2", 12.6#/ft, IBT -Mod Tubing (2 jts) 4) Baker 4 -'/2" x 7" Premier Packer 13,000' 7,021' 4- 12.6 # /ft, IBT -Mod Tubing (2 jts) 5) 4 -' /z', "XN" (3.813 ") - 66.5° inc 13,100' 7,063' 4- 12.6 # /ft, IBT -Mod Tubing 6) 4 -' /z', 12.6 #/ft IBT -Mod WLEG w/ Muleshoe 13,834' 7,307' ® 4 -'/2° x 1" Camco KBG -2 GLM w/ DCK -2 0 O SOV at 12 MD / 6,979' TVD TOC +/ - 12,422 MD Top of Alpine C at 14,215' MD / 7,337' TVD / 6,7622 ' TVD Top of Alpine A at 15,033' MD 17,412' TVD <.:0 CD2 -60A 6.125" Wellbore Whipstock top set at 14257' MD TD = 21,053' MD / 7,46T TVD Cement retainer set at 14277' MD CD2 -60 Originial Wellbore 7" 26 ppf L -80 BTC -M Production Casing at 14,331' MD / 7,379' TVD @ +/- 85.4° ,. 0 P ! ri 1 l'q ,A. I • • I Id 4 4 i 1 r o : ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2 -60 Plan: CD2 -60A 1 1 Plan: CD2- 60Awp02 4 ill Standard Proposal Report [N A D 2 71 , 1 I - p p 29 September, 2009 N I HALLIBURTON ' rnali t imiemilimm.......................... 1 : Sperry Drilling Services ORIGINAL a 0 Nor HALLIBURTON o.' W CD2 Apiine Pad CD2- 60Awp02 ConocoPhillips CD2 -60 Sperry Drilling Plan: CD2 -60A CD2- 60Awp02 D D I : 7.139 SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 84.00 617.00 CD2 -60 gyro (CD2- 60PB1) CB- GYRO -SS 744.18 11756.04 CD2 -60PB1 (CD2- 60PB1) MWD +IFR -AK- CAZ -SC 11756.04 14255.03 CD2 -60 (CD2 -60) MWD +IFR -AK- CAZ -SC -10000 - -- 14255.03 21053.15 CD2- 60Awp02 (Plan: CD2 -60A) MWD +IFR -AK- CAZ -SC I Pg i CD2 -6 0 \� S O N -12500 CD2- 60L1wp01 Heel 5 6 - 15000 -- — ,,, G O D 6OWI L G� - 17500 — CD2- 60L1wp01 Toe I I I I I I I -7500 -5000 -2500 0 2500 5000 7500 West( -) /East( -) (2500 ft /in) CASING DETAILS TVD MD Name Size 2373.00 3276.00 9 -5/8" x 12 -1/4" 9 -5/8 7372.18 14257.00 7" x 8 -1/2" 7 7467.30 21053.29 4 -1/2" x 6 -1/8" 4 -1/2 CO 7360 — a) o lit a 3 U ■ o N CD > 7440 CD 2- 60L1wp01 Heel L ti CD2- 60L1wp01 Toe C.).° 1 I I 7520 - I I I 7500 9000 10500 12000 13500 15000 Vertical Section at 150 (10° ORIGINAL • i 41, ConocoPhillips HALLIBURTON Standard Proposal Report Dataiiase I EDM v16 Prod Locsl Oo- ordinate Re erence Well CD2 -60 Comp 'hy _ � ConocoPhillips(Alaska) Inc. TVD Reference 90' ; � of CD2 -60: t 52.37ft (CD2-60:) 60:) � ' t)ect ' Western North Slope ''''MD Reference: m"��CD2 -60: © 52.37ft (CD2-60:) 9o�,, "' 1 CD2 Alpine Pad North'Referetce;, ` True ° Well A . CD2 -60 Survey Calculation Method Minimum Curvature �ilyettbore I Plan CD2 -60A 'C)esign - C D2- 60Awp02 „N111-,, 4 '4 = 1 b' � 5 Project Western North Slope 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 ,I Ili CD2 Alpine Pad - -- u, , Site Position: Northing: 752.77ft Latitude: 53° 45 41.281 N From: Map Easting: - 1,140,503.22ft Longitude: 157° 35'20.797 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -6.11 ° Weil 11'6 CD2 -60 Well Position +N /-S 0.00ft Northing: 5,974,194.47ft Latitude: 70° 20' 15.835 N +E/ -W 0.00 ft Easting: 371,743.77 ft Longitude: 151° 2' 26.471 W Position Uncertainty 0.00ft Wellhead Elevation: if Ground Level: 15.90ft 7llleilbore Plan: CD2 -60A p�Qi 9 6' _�I4, ��Gg m"l n ��� i �i�F °uu1j41 iii P uplilil '�`,N.„4i =. �eldStrenffM499 1lAagnetics �W,i = Mo 1 fu me �I,SA Daf C r3ehnatio n 19iiiN I�i Dip i gle �IIIip,p �� 1 71,177-, - - 7174,7 (,, li '11,11111,17 :( J 7 f 967, °� ` 1 1 ; M� BGGM2007 9/29/2009 16.40 79.62 57,293 DesIj CD2- 60Awp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 14,255.03 Veri ca ectrort l ' X9111 y HIDepth Fro l i(TVD) '1991) ld� +NI -C,,, , +El-W 0 "V Dire tlon l'1, w1 4 iil � i' . 1'1 (ft) 1 (ft) 1 (ft) 1 � ') 14 �I ' 36.47 0.00 0.00 150.00 Plan' etF its o lil PI 911'11 9 ' 111 '„ a611m916a11ii ' , �� 91 ' 19 41,1„ 11', 61141,1 '4, 11e,iil 9i9 1 11iiiJ ∎ 11414 91 7 dja111,1 111110 3 611,Aleasurealg11l 9 ,; Vertical TV�39� �11'1'', 4 , 1111 Dogleg ;�l1 Bur ITur 1 11 1 ; ;" ,, # th � �I�nc , 11, 6 ion i zh i h 111 I Depth,1 'i SYs tI I� P46 911 + l' , i + I W , pi g , 0O- = R Illi , ` �a e tro]1F`ac - -7- ii @r ( tl W r (ay I19�) i' t i ( ) t ( e ) i ( °r iv en } �� 11 l -i d 1 E IUI -- = 1 / � 9i ( ". 1 41ii i i ' it _ - 1, 0, Wi,, "111,,,---=;` _ 14,255.03 83.97 150.35 7,371.97 7,319.60 - 11,308.67 - 2,161.41 0.00 0.00 0.00 0.00 14,257.00 84.03 150.30 7,372.18 7,319.81 - 11,310.37 - 2,160.44 3.96 3.05 -2.54 -39.65 14,271.50 85.45 151.72 7,373.51 7,321.14 - 11,323.00 - 2,153.44 13.80 9.77 9.79 45.00 14,291.50 85.45 151.72 7,375.10 7,322.73 - 11,340.56 - 2,143.99 0.00 0.00 0.00 0.00 14,341.50 85.45 152.72 7,379.07 7,326.70 - 11,384.65 - 2,120.76 2.00 0.00 2.01 90.00 14,631.50 85.50 161.45 7,402.00 7,349.63 - 11,650.68 - 2,008.32 3.00 0.02 3.01 90.00 14,817.36 89.45 165.39 7,410.19 7,357.82 - 11,828.57 - 1,955.36 3.00 2.13 2.12 45.00 15,127.36 89.46 174.69 7,413.15 7,360.78 - 12,133.55 - 1,901.80 3.00 0.00 3.00 90.00 15,943.32 89.51 150.21 7,420.65 7,368.28 - 12,905.59 - 1,657.63 3.00 0.01 -3.00 -90.00 21,052.69 89.45 150.24 7,467.30 7,414.93 - 17,340.28 879.50 0.00 0.00 0.00 151.69 9/29/2009 12:10 :50PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL • ConocoPhillips HALLIBURTON Standard Proposal Report � i Da ase EDM v16 Prod 'Oeai CoLordinat '�Refet nce d! Well CD2 -60 116 COmpanyt . ConocoPhillips(Alaska) Inc. TVD Reference CD2 -60: © 52.37ft (CD2 -60:) Projeatwoq, _ Western North Slope MC Re rence = �„ CD2 -60: @ 52.37ft (CD2 -60:) 1te 'II CD2 Alpine Pad ilU True (I11Ofl_ 1 1 CD2 - 60 " � o �, „;3urvey �alculatlon Me ova: 64 Minimum Curvature We1i1e: ° Plan: CD2 -60A DesIgt th CD2- 60Awp02 Planked urvey li II mill' i'i "101 M1, it� i��11l = 1,1141) ( i6 iii I "� - iI� �j�, ( �i��i' ) iiU i i �� I Iph � (qq y III i III � r , V i IIOo (llli leaser l (i i� 111, m Map �i� '' Ii Depth , Incfinatloti Azimuth I'll1 Depth 'a TVDss( +N/..s, +E1 -W r arthing _ astlih i r DLS Vert ctia 14,255.03 83.97 150.35 7,371.97 7,319.60 - 11,308.67 - 2,161.41 5,962,925.34 369,389.45 3.26 8,712.89 TIP 14,257.00 84.03 150.30 7,372.18 7,319.81 - 11,310.37 - 2,160.44 5,962,923.62 369,390.39 3.96 8,714.85 KOP :',Top of Whipstock DLS 13.80 TFO 45.00 - 7" x 8- 112 14,271.50 85.45 151.72 7,373.51 7,321.14 - 11,323.00 - 2,153.44 5,962,910.88 369,397.17 13.80 8,729.29 Millitfg Assembly: Start 20.00 hold at 14271.50 MD 14,291.50 85.45 151.72 7,375.10 7,322.73 - 11,340.56 - 2,143.99 5,962,893.16 369,406.31 0.00 8,749.21 Start DLS 2.00 TFO 90.00 14,300.00 85.45 151.89 7,375.77 7,323.40 - 11,348.02 - 2,139.99 5,962,885.63 369,410.19 2.00 8,757.68 14,341.50 85.45 152.72 7,379.07 7,326.70 - 11,384.65 - 2,120.76 5,962,848.68 369,428.78 2.00 8,799.02 Start ! DLS 3.00 TFO 90.00 14,400.00 85.45 154.48 7,383.71 7,331.34 - 11,436.89 - 2,094.84 5,962,796.01 369,453.81 3.00 8,857.22 14,500.00 85.46 157.49 7,391.63 7,339.26 - 11,527.93 - 2,054.28 5,962,704.29 369,492.80 3.00 8,956.35 14,600.00 85.49 160.50 7,399.52 7,347.15 - 11,620.99 - 2,018.55 5,962,610.65 369,526.93 3.00 9,054.80 14,631.50 85.50 161.45 7,402.00 7,349.63 - 11,650.68 - 2,008.32 5,962,580.79 369,536.65 3.00 9,085.62 Start DLS 3.00 TFO 45.00 14,700.00 86.95 162.90 7,406.50 7,354.13 - 11,715.74 - 1,987.40 5,962,515.38 369,556.46 3.00 9,152.43 14,800.00 89.08 165.02 7,409.96 7,357.59 - 11,811.78 - 1,959.79 5,962,418.89 369,582.41 3.00 9,249.41 14,817.36 89.45 165.39 7,410.19 7,357.82 - 11,828.57 - 1,955.36 5,962,402.04 369,586.55 3.00 9,266.16 Start DLS 3.00 TFO 90.00 14,900.00 89.45 167.87 7,410.98 7,358.61 - 11,908.96 - 1,936.25 5,962,321.34 369,604.28 3.00 9,345.33 15,000.00 89.45 170.87 7,411.94 7,359.57 - 12,007.23 - 1,917.81 5,962,222.78 369,621.05 3.00 9,439.66 15,100.00 89.46 173.87 7,412.89 7,360.52 - 12,106.32 - 1,904.53 5,962,123.47 369,632.63 3.00 9,532.12 15,127.36 89.46 174.69 7,413.15 7,360.78 - 12,133.55 - 1,901.80 5,962,096.21 369,634.89 3.00 9,557.06 Start! DLS 3.00 TFO - 90.00 15,200.00 89.46 172.51 7,413.84 7,361.47 - 12,205.73 - 1,893.70 5,962,023.91 369,641.75 3.00 9,623.62 15,300.00 89.46 169.51 7,414.78 7,362.41 - 12,304.48 - 1,878.08 5,961,924.91 369,655.68 3.00 9,716.95 15,400.00 89.46 166.51 7,415.72 7,363.35 - 12,402.28 - 1,857.31 5,961,826.77 369,674.77 3.00 9,812.04 15,500.00 89.47 163.51 7,416.66 7,364.29 - 12,498.87 - 1,831.45 5,961,729.77 369,698.97 3.00 9,908.61 15,600.00 89.47 160.51 7,417.58 7,365.21 - 12,593.96 - 1,800.57 5,961,634.17 369,728.22 3.00 10,006.41 15,700.00 89.48 157.51 7,418.49 7,366.12 - 12,687.31 - 1,764.75 5,961,540.23 369,762.43 3.00 10,105.16 15,800.00 89.49 154.51 7,419.39 7,367.02 - 12,778.66 - 1,724.10 5,961,448.20 369,801.51 3.00 10,204.59 15,900.00 89.50 151.51 7,420.27 7,367.90 - 12,867.75 - 1,678.73 5,961,358.35 369,845.35 3.00 10,304.44 15,943.32 89.51 150.21 7,420.65 7,368.28 - 12,905.59 - 1,657.63 5,961,320.17 369,865.79 3.00 10,347.75 Start', DLS 0.00 TFO - 176.86 16,000.00 89.51 150.21 7,421.14 7,368.77 - 12,954.78 - 1,629.47 5,961,270.51 369,893.11 0.00 10,404.43 16,100.00 89.50 150.21 7,422.00 7,369.63 - 13,041.56 - 1,579.79 5,961,182.90 369,941.29 0.00 10,504.42 16,200.00 89.50 150.21 7,422.87 7,370.50 - 13,128.34 - 1,530.12 5,961,095.28 369,989.47 0.00 10,604.42 16,300.00 89.50 150.21 7,423.73 7,371.36 - 13,215.13 - 1,480.44 5,961,007.67 370,037.66 0.00 10,704.42 16,400.00 89.50 150.21 7,424.60 7,372.23 - 13,301.91 - 1,430.76 5,960,920.06 370,085.84 0.00 10,804.41 16,500.00 89.50 150.21 7,425.48 7,373.11 - 13,388.70 - 1,381.09 5,960,832.44 370,134.02 0.00 10,904.41 16,600.00 89.50 150.21 7,426.35 7,373.98 - 13,475.48 - 1,331.41 5,960,744.83 370,182.20 0.00 11,004.40 16,700.00 89.50 150.21 7,427.23 7,374.86 - 13,562.27 - 1,281.74 5,960,657.21 370,230.37 0.00 11,104.40 16,800.00 89.50 150.22 7,428.11 7,375.74 - 13,649.05 - 1,232.06 5,960,569.60 370,278.55 0.00 11,204.39 16,900.00 89.50 150.22 7,428.99 7,376.62 - 13,735.84 - 1,182.39 5,960,481.98 370,326.73 0.00 11,304.39 9/29/2009 12:10:50PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL. 0 0 ConocoPhillips HALLIBUR TON Standard Proposal Report iy4lhl Fx ■, - ; ru i ,� ��GIII I 1 , � �� 6� i , lii igli '! uu O EDM v16 Prod Loca -orci ate Ref rence We CD2 60 op�parr}}`1I ConocoPhillips(Alaska) Inc. . '1'VD Reference �'��wy Il' " CD2 -60: © 52.37ft (CD2 -60:) ' J Je ' 111 Western North Slope MD Reference: CD2 -60: @ 52.37ft (CD2 -60:) Slt'g rth CD2 Alpine Pad No Reference: = True Mat, = CD2 -60 Survey Calculation `M'etho e'U M Curvature Wll re Plan: CD2 -60A '111,1 �u� �' ,,, Deoslgn : 11�il CD2- 60Awp02 ii � I�IVi Planhed Al ��9P ii -•r _ - - _ _ �r (1I� _ 1 _ .ii i Meas 1 I��61Ipi� ml l 'i . , Vertical = _ � a p � �� Map _ = �Ilm _ _ Iliipop irl ��6n, Depth �lnclinatron A north Depth 1 Dss +NT- ` +Ef W ' ° I' 4 6 1 1 I� p � Northing O�illiiiii a s i ' 1 7 377 i� �iee� eetion 100 1 17 150.22 lft1 '). e) ∎- (f#'I 'Ill f � � ) �l �ti�� (ft) � (9ii - ffil � �1� 11 .) Gill �Q ilii n ,000.00 89.49 7,429.87 7,377.50 - 13,822.63 - 1,132.72 5,960,394.36 370,374.90 0.00 11,404.38 17,100.00 89.49 150.22 7,430.75 7,378.38 - 13,909.41 - 1,083.05 5,960,306.74 370,423.08 0.00 11,504.38 17,200.00 89.49 150.22 7,431.64 7,379.27 - 13,996.20 - 1,033.38 5,960,219.13 370,471.25 0.00 11,604.37 17,300.00 89.49 150.22 7,432.53 7,380.16 - 14,082.99 - 983.71 5,960,131.51 370,519.42 0.00 11,704.37 17,400.00 89.49 150.22 7,433.42 7,381.05 - 14,169.78 - 934.05 5,960,043.89 370,567.59 0.00 11,804.37 17,500.00 89.49 150.22 7,434.31 7,381.94 - 14,256.57 - 884.38 5,959,956.27 370,615.76 0.00 11,904.36 17,600.00 89.49 150.22 7,435.20 7,382.83 - 14,343.36 - 834.72 5,959,868.65 370,663.93 0.00 12,004.36 17,700.00 89.49 150.22 7,436.10 7,383.73 - 14,430.15 - 785.05 5,959,781.03 370,712.10 0.00 12,104.35 17,800.00 89.48 150.22 7,437.00 7,384.63 - 14,516.94 - 735.39 5,959,693.41 370,760.27 0.00 12,204.35 17,900.00 89.48 150.22 7,437.90 7,385.53 - 14,603.73 - 685.73 5,959,605.79 370,808.44 0.00 12,304.34 18,000.00 89.48 150.22 7,438.80 7,386.43 - 14,690.53 - 636.06 5,959,518.16 370,856.60 0.00 12,404.34 18,100.00 89.48 150.22 7,439.70 7,387.33 - 14,777.32 - 586.40 5,959,430.54 370,904.77 0.00 12,504.33 18,200.00 89.48 150.22 7,440.61 7,388.24 - 14,864.11 - 536.74 5,959,342.92 370,952.93 0.00 12,604.33 18,300.00 89.48 150.22 7,441.52 7,389.15 - 14,950.91 -487.09 5,959,255.30 371,001.10 0.00 12,704.32 18,400.00 89.48 150.23 7,442.43 7,390.06 - 15,037.70 - 437.43 5,959,167.67 371,049.26 0.00 12,804.32 18,500.00 89.48 150.23 7,443.34 7,390.97 - 15,124.50 - 387.77 5,959,080.05 371,097.42 0.00 12,904.31 18,600.00 89.48 150.23 7,444.25 7,391.88 - 15,211.29 - 338.12 5,958,992.42 371,145.58 0.00 13,004.31 18,700.00 89.47 150.23 7,445.17 7,392.80 - 15,298.09 - 288.46 5,958,904.80 371,193.74 0.00 13,104.30 18,800.00 89.47 150.23 7,446.09 7,393.72 - 15,384.88 - 238.81 5,958,817.17 371,241.90 0.00 13,204.30 18,900.00 89.47 150.23 7,447.01 7,394.64 - 15,471.68 - 189.15 5,958,729.54 371,290.05 0.00 13,304.29 19,000.00 89.47 150.23 7,447.93 7,395.56 - 15,558.48 - 139.50 5,958,641.92 371,338.21 0.00 13,404.29 19,100.00 89.47 150.23 7,448.86 7,396.49 - 15,645.28 -89.85 5,958,554.29 371,386.36 0.00 13,504.28 19,200.00 89.47 150.23 7,449.78 7,397.41 - 15,732.08 -40.20 5,958,466.66 371,434.52 0.00 13,604.28 19,300.00 89.47 150.23 7,450.71 7,398.34 - 15,818.87 9.45 5,958,379.03 371,482.67 0.00 13,704.27 19,400.00 89.47 150.23 7,451.64 7,399.27 - 15,905.67 59.10 5,958,291.40 371,530.83 0.00 13,804.27 19,500.00 89.47 150.23 7,452.57 7,400.20 - 15,992.47 108.75 5,958,203.77 371,578.98 0.00 13,904.26 19,600.00 89.46 150.23 7,453.51 7,401.14 - 16,079.28 158.39 5,958,116.14 371,627.13 0.00 14,004.26 19,700.00 89.46 150.23 7,454.44 7,402.07 - 16,166.08 208.04 5,958,028.51 371,675.28 0.00 14,104.25 19,800.00 89.46 150.23 7,455.38 7,403.01 - 16,252.88 257.68 5,957,940.88 371,723.43 0.00 14,204.25 19,900.00 89.46 150.23 7,456.32 7,403.95 - 16,339.68 307.33 5,957,853.25 371,771.57 0.00 14,304.24 20,000.00 89.46 150.23 7,457.26 7,404.89 - 16,426.48 356.97 5,957,765.62 371,819.72 0.00 14,404.24 20,100.00 89.46 150.24 7,458.21 7,405.84 - 16,513.29 406.61 5,957,677.99 371,867.87 0.00 14,504.23 20,200.00 89.46 150.24 7,459.15 7,406.78 - 16,600.09 456.25 5,957,590.35 371,916.01 0.00 14,604.23 20,300.00 89.46 150.24 7,460.10 7,407.73 - 16,686.89 505.89 5,957,502.72 371,964.16 0.00 14,704.22 20,400.00 89.46 150.24 7,461.05 7,408.68 - 16,773.70 555.53 5,957,415.09 372,012.30 0.00 14,804.21 20,500.00 89.45 150.24 7,462.00 7,409.63 - 16,860.50 605.17 5,957,327.45 372,060.44 0.00 14,904.21 20,600.00 89.45 150.24 7,462.96 7,410.59 - 16,947.31 654.80 5,957,239.82 372,108.58 0.00 15,004.20 20,700.00 89.45 150.24 7,463.91 7,411.54 - 17,034.12 704.44 5,957,152.18 372,156.72 0.00 15,104.20 20,800.00 89.45 150.24 7,464.87 7,412.50 - 17,120.92 754.08 5,957,064.55 372,204.86 0.00 15,204.19 20,900.00 89.45 150.24 7,465.83 7,413.46 - 17,207.73 803.71 5,956,976.91 372,253.00 0.00 15,304.19 21,000.00 89.45 150.24 7,466.79 7,414.42 - 17,294.54 853.34 5,956,889.27 372,301.14 0.00 15,404.18 21,052.69 89.45 150.24 7,467.30 7,414.93 - 17,340.28 879.50 5,956,843.09 372,326.50 0.00 15,456.87 CD2- 60L1wp01 Toe (copy) (copy) 9/29/2009 12.10:50PM Page 4 COMPASS 2003.16 Build 69 ORtGNAL 0 0 ConocoPhillips Standard Proposal Report ld � afar'w EDM v16 Prod Local' Co- ordinate Reference Well CD2 - 60 � �� ,,._ • y y � �� Company: ConocoPhillips(Alaska) Inc. TVD References = CD2 - 60: © 52.37ft (CD2 - 60:) PthO:f e is Western North Slope ;M Reference = ,, _ CD2 -60: © 52.37ft (CD2 -60:) Site l CD2 Alpine Pad Nolfth Reference = 'Al 61 True Welk :,00 ,,, CD2-60 Survo / Catculation Metltbd: Minimum Curvature Plan: CD2 -60A 4 " � 'Illy 1,t„ D 1N�IIbo g ,,� CD 11 ,, Ime =� n �i�� 2 60Awp02 _� � _ m, r�goi � i _ =4 t',4 - , ii °�,i z� = DWI Ta bts 4 i II. lr Target N a m e , q1! ..:111„,1,1::7?.--- " � �bi y, , p �iP( p l �i E � lp l�'I11011 ''11 li rim pi °i TVD Bill +N/ a '14,El W 4 1111 iii Nor Eastlt � �I l h� - hltf�YllSStriiQet i ���pii�,, DiiSAnBi� � Dif}CTlr+ �i // i�i -Sha ' ' i�(o)l , (�) ipi i k li — i (ft) ""quIbgii, ( Wp 9,1, "11�(ft) I i ' ,r ) 11.k. „ , f, CD2- 60L1wp01 Heel (copy) (copy) 0.00 0.00 7,412.30 - 12,119.88 - 2,100.21 5,962,113.27 369,436.76 77 - plan misses target center by 196.03ft at 15087. 44 ft MD (7412.77 TVD, - 12093.84 N, - 1905.91 E) - Point CD2- 60L1wp01 Toe (copy) (copy) 0.00 0.00 7,467.30 - 17,340.28 879.50 5,956,843.09 372,326.50 - plan hits target center - Point asi rg P t g gw Meagti ed Vertic f Casrng a' P = l Hole l � l lpp , � Dep Dept �I� ” D ia seter Diaetex� �, p��I l1, ,1,1p1u6 eft) (ft) = N ( � ' - 1 = 41 3,276.00 2,373.00 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 14,257.00 7,372.18 7" x 8 -1/2" 7 8 -1/2 21,053.29 4 -1/2" x 6 -1/8" 4 -1/2 6 -1/8 - Plan Annotation ∎ _ i s Milli i; ii `i * (�;! 0� d r i 1r, 1 -' ; Vii; i''''0,,„ P',1 , wt'' ( Measured Vertical L oca l Coo i r na d)tes i i , ll ' 1 ( � e �,,; „p� ���p Depth 'li r Depth N/- ' +E/W �, ” . 9 j " � � ��� Tir , . tf t) 1� i1' c (ft ( � � t) (�) Comment 1 i9 iy a � �.. (fir 14,255.03 7,371.97 - 11,308.67 - 2,161.41 TIP 14,257.00 7,372.18 - 11,310.37 - 2,160.44 KOP: Top of Whipstock DLS 13.80 TFO 45.00 14,271.50 7,373.51 - 11,323.00 - 2,153.44 Milling Assembly: Start 20.00 hold at 14271.50 MD 14,291.50 7,375.10 - 11,340.56 - 2,143.99 Start DLS 2.00 TFO 90.00 14,341.50 7,379.07 - 11,384.65 - 2,120.76 Start DLS 3.00 TFO 90.00 14,631.50 7,402.00 - 11,650.68 - 2,008.32 Start DLS 3.00 TFO 45.00 14,817.36 7,410.19 ' - 11,828.57 - 1,955.36 Start DLS 3.00 TFO 90.00 15,127.36 7,413.15 - 12,133.55 - 1,901.80 Start DLS 3.00 TFO -90.00 15,943.32 7,420.65 - 12,905.59 - 1,657.63 Start DLS 0.00 TFO - 176.86 21,053.29 TD at 21053.29 9/29/2009 12:10:50PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL Ea ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad ' CD2 -60 Plan: CD2 -60A CD2- 60Awp02 • A Sperry Drilling Services Clearance Summary - A nt icollision Report p 29 September, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) g Reference Design: CD2 Alpine Pad - CD2 -60 - Plan: CD2 -60A - CD2- 60Awp02 Well Coordinates: 5,973,941.18 N, 1,511,776.53 E (70° 20' 14.65" N, 151° 02' 37.79" W) y Datum Height: CD2 -60: @ 52.37ft (CD2 -60:) ✓�l P Scan Range: 14,257.00 to 21,053.29 ft. Measured Depth. Scan Radius is 2,301.74 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited G 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 r"" , HALLIBURTON ill 1 Sperry Drilling Services GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference 11:44, September 29 2009 9 C132- 60Awp02 Ellipsoid Color 14257.00 To 21053.29 0 250 1750 - " " "" 2000 5000 "' 6000 14000 1600C 250 500 2000 ° 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 -- 1000 3000 3500 8000 9000 20000 _ ------- 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - 30/ 330 30 1500 " "" 1750 4500 5000 12000 14000 201 • -60 / 300 60 0 / 360 ,50 30 • II D2 -6C -60 / 60 90 / 270 _��� 90 CD2 -60 - 90 / 270 Ailik 90 VIP / -120 / 240 120 -120 / 240 120 III 200 1j' -150 /210 150 - 150/21# 150 50 Q 300 -180 / 180 :IC) -180 / 180 GI Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] r ConocoPhillips(Alaska) Inc. -WNS H LLlBURT. -. Western North Slope Anticollision Report for CD2 -60 - CD2- 60Awp02 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - CD2 -60 - Plan: CD2 -60A - CD2- 60Awp02 Scan Range: 14,257.00 to 21,053.29 ft. Measured Depth. Scan Radius is 2,301.74 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 CD2 Alpine Pad • CD2 -37 - CD2 -37 - CD2 -37 14,529.58 2,194.36 14,529.58 1,938.81 13,775.00 8.587 Centre Distance Pass - Major Risk CD2 -37 - CD2 -37 - CD2 -37 14,541.18 2,194.98 14,541.18 1,938.40 13,800.00 8.555 Clearance Factor Pass - Major Risk CD2 -60 - CD2 -60 - CD2 -60 14,274.99 0.38 14,274.99 -0.16 14,275.00 0.699 Clearance Factor FAIL - Minor 1/10 an O -11M =11111111111111■ MINIM • MI - CD4 Nanuq Pad CD4 -16 - CD4 -16 - CD4 -16 20,266.01 1,124.03 20,266.01 927.11 9,675.00 5.708 Centre Distance Pass - Major Risk CD4 -16 - CD4 -16 - CD4 -16 20,240.30 1,126.60 20,240.30 923.14 9,750.00 5.537 Clearance Factor Pass - Major Risk CD4 -17 - CD4 -17 - CD4 -17 20,758.52 2,013.02 20,758.52 1,827.90 9,325.00 10.875 Centre Distance Pass - Major Risk CD4 -17 - CD4 -17 - CD4 -17 20,727.91 2,015.91 20,727.91 1,825.50 9,425.00 10.587 Clearance Factor Pass - Major Risk CD4 -213 - CD4 -213 - CD4- 213wp05 21,046.62 2,103.41 21,046.62 1,874.51 11,275.00 9.189 Clearance Factor Pass - Major Risk CD4 -304 - CD4 -304 - CD4 -304 18,652.47 2,001.10 18,652.47 1,827.13 10,475.00 11.502 Centre Distance Pass - Major Risk CD4 -304 - CD4 -304 - CD4 -304 18,575.86 2,005.27 18,575.86 1,823.71 10,625.00 11.045 Clearance Factor Pass - Major Risk CD4 -304 - CD4- 304PB1 - CD4- 304PB1 18,652.47 2,001.10 18,652.47 1,827.13 10,475.00 11.502 Centre Distance Pass - Major Risk CD4 -304 - CD4- 304PB1 - CD4- 304PB1 18,575.86 2,005.27 18,575.86 1,823.71 10,625.00 11.045 Clearance Factor Pass - Major Risk CD4 -306 - CD4 -306 - CD4 -306 17,529.65 1,600.89 17,529.65 1,352.89 10,346.00 6.455 Clearance Factor Pass - Major Risk • CD4 -319 - CD4 -319 - CD4 -319 21,039.55 374.06 21,039.55 193.35 17,175.00 2.070 Clearance Factor Pass - Major Risk Nanuq 3 - Nanuq 3 - Nanuq 3 20,945.36 913.67 20,945.36 623.49 9,112.00 3.149 Clearance Factor Pass - Major Risk Plan: CD4 -23 - Plan: CD4 -23 - CD4- 23wp08 19,562.17 756.77 19,562.17 563.12 9,850.00 3.908 Centre Distance Pass - Major Risk Plan: CD4 -23 - Plan: CD4 -23 - CD4- 23wp08 19,556.65 763.53 19,556.65 554.92 9,950.00 3.660 Clearance Factor Pass - Major Risk C) IO G) 29 September, 2009 - 11:42 Page 2 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALL Western North Slope Anticollision Report for CD2 -60 - CD2- 60Awp02 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 84.00 617.00 CB- GYRO -SS 744.18 11,756.04 MWD +IFR- AK- CAZ -SC 11,756.04 14,255.03 MWD +IFR- AK- CAZ -SC 14,255.03 21,053.15 CD2- 60Awp02 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. 22 >�* 29 September, 2009 - 11:42 Page 3 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for CD2 -60 - CD2- 60Awp02 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to CD2 -60: @ 52.37ft (CD2 -60:). Northing and Easting are relative to CD2 -60. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 °, Grid Convergence at Surface is: -0.98 °. CD2.42,CO2- 42PB1.0O2 -42PB1 V0 Ladder ,` CD2.43,CO2- 43,CD2 -43V15 PlotPlot 43, CD2- 43PB1,CD2 -43P81 V12 _ . CD2- 43, Prelim: CD2- 43A,CD2- 43Amp02V1 • ' t1' � : ` . h " �. ti `„ --f CD2- 44,CO2- 44,CD2- 44V15 _ i.1 i Fi 1 �� t • - r CD2- 45,CD2- 45,CO2 -45 V5 _ r. , ? 1950 r CD2.46,CO2- 46,CD2 -46 V2 O r -- CO2- 464,CD2- 464,CO2 -464W t I A -=5 CD2- 467,CD2- 467,CD2 -467 D CO , "-■-- i -.6- -.6- CD2.467,CO2- 467PB1,CO2- 467PB1 W = O i 1 . -0- CD2.47,CO2- 47,CD2 -47 V2 CO i i i i i - E,?. CO2- 48,CO2- 48.0O2.48V1 ( ' CO 1 : 1 CD2- 49,CO2- 49,CD2.49V1 CL i 0) 1 1 1 1 I f CD2.50,CO2- 50,CD2.50 V2 i � !.. 1 -5, CO2- 50,CO2- 50P81,CD2.50PB1 V2 � � � 1 1 CD2- 51, CD2- 51,CD2 -51V12 i i i i i ' Q) 1 1 .i i }t CD2- 52,CD2- 52,CO2 -52 V8 (, 1 1 ._\ • 650— 1 1 —a— CO2- 53,CD2.53,CO2 -53 V11 O i % � -A CO2- 54,CD2- 54,CO2 -54 V3 C i i 1 �. 1 CD2- 54,CD2- 54L1,CO2 -54L1 V4 1 • - ` ' 1 C i - i - - i i - .47 CD2- 55 ,CD2- 55,CD2 -55 V9 (, 1 i -- CD2- 55,CO2.56,CD2 -56 VB ,; ` � i $ CD2- SB,CD2- 56L1,CD2 -56 L1 V10 '•• -9- CD2- 57,CD2.57,CD2 -57 V2 0 4000 8000 12000 1 6000 2000 —&- CD2- 58,CO2.58,CD2 -58V12 C....? Measured Depth (4000 ftJin) 4- CO2- 58,CD2- 58L1,CD2 -58L1 V7 70 -7 CD2.59,CD2- 59,CD2.59V12 ...re rm -Fry P.11?-5QPR1 rm -5apRi \BS 29 September, 2009 - 11:42 Page 4 of 5 COMPASS 1 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for CD2 -60 - CD2- 60Awp02 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor CO2- 42,CD2 -42PB 1,C 02-42P B1 VD CO2 -43, CD2 -43, CD2 -43 V15 4 _ " b CD2- 43,CD2- 43PB1,CO2 -43PB1 V12 �` . CD2 -43, Prelim: CD2 -43A, CO2 -43A.0 p02 V1 ; 2 -4, C D2 -44. C - V " ___ u • -___._ °T - C D2 -45 CD2 -45, CD2 D2 -45 44 V5 15 - �� CD2 -4 ®,CD2 -40, CD2 -48 V2 S. - C132-464,C 02-464, CO2 -484V0 2 _ �. � - k -+- CD2- 467,CO2 -487, CD2.487 V0 0 _ '. ' ' ` -a C132.457, CO2 -487PB 1, CD2 -457P 81 VD 6. - i , -$ -- CD2 -47, C132-47, CD2 -47 V2 off] - _. ^.. ...__----- _ - _._. ...�...._.�:�._____ - __.__ - -- --- -- -- ._. _.__.__.4� o - 1 -Q- CO2- 48,CO2- 48,CO2 -48 V1 cu _ f ` -e}- CD2- 49,CO2- 49,CO2 -49 V1 u._ - Or -0- CD2 -50, CD2 -50, CD2 -50 V2 0 r ► CD2- SD,CD2- 50P81,CD2- 5DPBIVZ c - + - C132- 51,CD2- 51,CD2 -51V12 m s: 5 - co - CD2 -52, CD2.53, CD2 -52 V8 _ -8- CO2 -53, CO2.53, CD2 -53 V11 ,",, - CO2 -54, CD2 -54, CO2 -54V0 .13D- W_ _ _. }+ CD2 -54, CD2 -54L1 , C D2 54L1 V4 --- { #- - CO2 .55, CO2 -55 C D2 -55 V9 (! + C132-56, C132-56, CD2 -58 V8 III i t j - ._ - .- -- -- ! u_ i ' -$- CD2.58.0O2- 56L1,CD2.56L1V10 , : 1 ('� 3" � j ! i C D2.57, CO2 -57, C132.57 V2 P c i G t s t r t r C D2.58, CD2 -58, CO2.58 V12 7 0 a I" 7/... sro �■= 7110 a: :o IC€€0 1= 11000 157750 I7e30 192o13 2100 - C D2.58.C132 - 58L1.0O2.58L1 V7 ...- -� Measured Depth (3500ftAn) $ C132 CD2 - 59, CD2 - 59 V12 -SI- CD2- 59,CD2- 59P81.C - 59P B1 V5 GI 29 September, 2009 - 11:42 Page 5 of 5 COMPASS GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:45, September 29 2009 9 CD2- 6OAwpO2 Ellipsoid Color 14257.00 To 14500.00 0 250 1750 "' "" " " " "' 2000 5000 "` " " "° 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 - - - -- 1000 3000 3500 8000 9000 20000 " - - -- 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 -30/ 330 30 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 50 -30 / 330 30 -60 / 300 60 -90 / 270 90 illk -90 / 270 90 EEC -120 /240 120 • -120 / 240 lir 120 200 -150 /210 150 -150 / 21 . 150 50 -180 / 180 0 300 -180 / 180 X) G) Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:46, September 29 2009 9 CD2- 60Awp02 Ellipsoid Color 14500.00 To 15000.00 0 250 1750 " 2000 5000 ° 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 " ' 1000 3000 3500 8000 9000 20000 `i 25000 300 1000 1250 3500 " 4000 9000 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 ill 201 • -60 / 300 60 0/360 50 -30 / 330 30 -60 / 300 60 -90 / 270 h 90 -90 / 270 90 CD2 -60 -120 /240 120 • -120 /240 120 200 -150 / 210 150 -150 /210 150 50 -180 / 180 300 P - 180 / 180 N C ) Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] 1 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:46, September 29 2009 9 CD2- 6OAwpO2 Ellipsoid Color 15000.00 To 16000.00 0 250 1750 " "` " " " " " "" 2000 5000 6000 14000 1600C 250 500 2000 — 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 --- 8000 18000 2000C 0 / 360 750 "" --- 1000 3000 3500 8000 9000 20000 - - -- 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 201 • -60 / 300 60 0 / 360 50 AI ilh -30 / 330 30 -60 / 300 60 -90 / 270 90 D2 -6C all I -90 / 270 90 10i -120 / 240 120 • -120 / 240 120 200 - 150/210 150 -150 / 211 150 50 CD 300 -180 / 180 °° "'j -180 / 180 r� G) �'° Travelling Cylinder Azimuth (TFO+AZI) [O] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:47, September 29 2009 9 CD2- 60Awp02 Ellipsoid Color 16000.00 To 20500.00 0 250 1750 ° __`" ° 2000 5000 -- 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 -- 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 201 • -60 / 300 60 0 / 360 50 -30 / 330 30 -60 / 300 60 -90 / 270 90 /Ilk -90 / 270 90 ' 101 -120 / 240 120 - 120 /240 120 • 200 -150 / 210 150 -150 / 211 150 50 -180 / 180 0 1 300 -180 / 180 71 3 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:48, September 29 2009 9 CD2- 6OAwpO2 Ellipsoid Color 20500.00 To 21053.29 0 250 1750 2000 5000 - "' "" 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 — 1000 3000 3500 8000 9000 20000 ' 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 201 • -60 / 300 60 0/360 50 Al -30 / 330 30 101 -60 / 300 60 -90 / 270 90 /7 ilk -90 / 270 90 glij / / igir -120 /240 / 120 / -120 /240 120 • 200 150 /210 150 - 150/211 150 50 300 - 180 / 180 - 180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [O] vs Centre to Centre Separation [25 ft/in] Conoco Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 September 29, 2009 c `, Alaska Oil and Gas Conservation Commission ECEI V ED 333 West 7 Avenue, Suite 100 SEP 2 9 2009 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Re: Application for Permit to Re -Drill CD2 -60A Anchorage Dear Sir or Madam: ConocoPhillips Alaska Inc. hereby applies for a permit to re -drill the CD2 -60 injector well (PTD 205 -068) from the CD2 drilling pad. This well, originally drilled in June of 2005, has been unable to sufficiently provide water injection support to nearby producing wells due to poor rock quality and subsequent low injectivity rates. Due to issues while decompleting the well, the decision was made to plug the existing lateral and sidetrack out of the intermediate casing. This new CD2 -60A well (API: 50- 103 - 20511 -01) will be sidetracked at approximately 14,257 ft MD from the Intermediate casing into the Alpine C sand. The plan is to then parallel the original CD2 -60 wellbore roughly 300 ft to the west, reaching a planned TD of 21,053 ft MD. The TD of the well is planned for 21,053' MD, same as approved in CD2 -60L1, PTD# 209 -0920. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. Proposed Fluids Program 4. Kick off Schematic diagram. 5. A proposed completion diagram. 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Liz Galiunas at 265 - 6247 or Chip Alvord at 265 -6120. ,, // ' Sincerely, 4, V/ - r / Liz Galiunas Drilling Engineer • Attachments: cc: CD2 -60L1 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Nina Anderson ATO 1706 Ryan Robertson ATO 1702 Tim Schnieder ATO 1768 Lanston Chin Kuukpik Corporation CD2-60L1 Shut In • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, September 28, 2009 4:58 PM nv hh Z ° 1 _ 11' To: 'Robertson, Ryan G' Subject: RE: CD2 -60L1 Shut In Ryan, Thank you for the update. I discussed your plan forward concerning setting a CIBP and sidetracking from the 7" casing with the commissioners. You have verbal approval to execute the steps as outlined below. Please contact me Tuesday morning and we can discuss the permitting requirements needed to reflect the changes planned. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Robertson, Ryan G [mailto :Ryan.G .Robertson @conocophillips.com] Sent: Monday, September 28, 2009 4:51 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Cc: Anderson, Nina M; Galiunas, Elizabeth C Subject: CD2 -60L1 Shut In Doyon 19 functioned the annular preventer this morning to perform a series of exhale tests on the CD2 -60L1 sidetrack well. Over the weekend, the Baker Premier Packer was retrieved from a depth of 13,033' MD / 7,035' TVD. Unfortunately several of the slips on the packer were seen to be missing once it was brought to surface. The decision was made to run a cleanout assembly to the 7" casing shoe in order to remove any debris remaining in the well. The assembly had reached a depth of 14,316' MD this morning at which point the well was circulated. As bottoms up was nearing surface, gas was seen to be breaking out of the 10.6 ppg brine in the hole. This prompted the rig crew to shut in the annular preventer and perform an exhale test. The well was bled down and then shut in to monitor. The flow rate began to decrease and the pressure was taking longer to build up once shut in thus indicating welibore breathing. It should be mentioned that breathing had been an issue on this well since kill weight fluid was initially pumped. After performing the exhale test, the well was opened and a bottoms up was circulated. As bottoms up was approaching, gas was once again noted at surface. Circulation was maintained on the well this time, and the gas seen at surface decreased to the point where the return flow was clean. It should be noted that none of the gas detection monitors were alarmed. The well was further circulated for over two bottoms up to ensure there was no gas entering the welibore. Circulation was then stopped, and the well shut in with the annular preventer. This was done to conduct another exhale test to further prove that no gas was present in the hole. Once completed, bottoms up was circulated 9/30/2009 CD2-60L1 Shut In Page 2 of 2 again. The plan forward is to POOH with the clean out assembly once the well is determined to be dead and free of gas. At this point the annular preventer and BOPE will be tested. We are currently working towards putting together a plan to sidetrack the existing wellbore in the upper Alpine C sand which is approximately +/- 100' MD up from the intermediate casing shoe. A cement retainer will be set to isolate the original wellbore CD2 -60. A whipstock will be placed above the cement plug to sidetrack the well at approximately +/- 14,257' MD. The sidetracked wellbore will be called CD2 -60A. ConocoPhillips will submit a 10-401 change of approved program and a sundry to isolate the original perforations in CD2 -60. Please let me know if you have any questions, Ryan Robertson Alpine Drilling Engineer ConocoPhillips Alaska Office: 265.6318 CeII: 980.5107 9/30/2009 Alaska Department of Naturalources Land Administration System Page 1 of$ 7 Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 380077 Printable Case File Summary See Township, Range, Section and Acreage? New search 0 Yes 0 No LAS Menu 1 Case Abstract 1 Case Detail I Land Abstract File: ADL 380077 Search for Status Plat es U dat p As of 09/30/2009 Customer: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 01/29/1993 Total Acres: 2148.810 Date Initiated: 10/27/1992 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 05/06/2009 Case Subtype: NSAS NS ARCTIC SLOPE R C Last Transaction: CHNGTEXT CHANGE LEGAL TEXT Meridian: U Township: 011N Range: 004E Section: 22 Section Acres: 229 Search Plats Meridian: U Township: O11N Range: 004E Section: 23 Section Acres: 640 Meridian: U Township: 011N Range: 004E Section: 24 Section Acres: 640 Meridian: U Township: 011N Range: 004E Section: 26 Section Acres: 615 Meridian: U Township: 011N Range: 004E Section: 27 Section Acres: 25 Legal Description 08 -25 -1992 * *SALE NOTICE LEGAL DESCRIPTION ** TRACT 75 -077 T. 10N., R. 4E., UMIAT MERIDIAN, ALASKA, TRACT A STATE % ASRC % SECTION 1, UNSURVEYED, ALL, EXCLUDING THE "NATIONAL PETROLEUM RESERVE ALASKA ", 584 ACRES; 55.07 44.93 SECTION 2, UNSURVEYED, ALL, EXCLUDING THE "NATIONAL PETROLEUM RESERVE ALASKA ", 80 ACRES; 7.86 92.14 SECTION 12, UNSURVEYED, ALL, EXCLUDING THE "NATIONAL PETROLEUM RESERVE ALASKA ", 173 ACRES; 20.95 79.05 http: / /dnr.alaska.gov /proj ects /1as /Case_Summary. cfm ?FileType= ADL &FileNumber =3 800... 9/30/2009 Alaska Department of NaturalOsources Land Administration System Page 1 o1.2( 7 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources 1 Alaska DNR Case Summary File Type: ADL File Number: 380075 Printable Case File Summary See Township, Range, Section and Acreage? New Search 0 Yes Q No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 380075 _ MaP Search for Status Plat Updates As of 09/30/2009 Customer: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 01/29/1993 Total Acres: 4396.590 Date Initiated: 10/27/1992 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 05/04/2009 Case Subtype: NSAS NS ARCTIC SLOPE R C Last Transaction: CHNGTEXT CHANGE LEGAL TEXT Meridian: U Township: 011N Range: 004E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 004E Section: 02 Section Acres: 640 Meridian: U Township: O11N Range: 004E Section: 03 Section Acres: 51 Meridian: U Township: O11N Range: 004E Section: 10 Section Acres: 6 Meridian: U Township: 011N Range: 004E Section: 11 Section Acres: 594 Meridian: U Township: 011N Range: 004E Section: 12 Section Acres: 640 Meridian: U Township: 011N Range: 004E Section: 13 Section Acres: 640 Meridian: U Township: 011N Range: 004E Section: 14 Section Acres: 640 Meridian: U Township: O11N Range: 004E Section: 15 Section Acres: 536 Meridian: U Township: O11N Range: 004E Section: 16 Section Acres: 10 Legal Description 08 -25 -1992 * *SALE NOTICE LEGAL DESCRIPTION ** TRACT 75 -075 T. 11N., R. 4E., UMIAT MERIDIAN, ALASKA, TRACT A STATE % ASRC % SECTION 1, UNSURVEYED, ALL, 640 ACRES; 53.51 46.49 SECTION 2, UNSURVEYED, ALL, 640 ACRES; 57.25 42.75 http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber =3 800... 9/30/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME C - 6o,4 PTD# v?09./AS0 Development V Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: eaZ POOL: 4744 /4/E O/L 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 Field & Pool COLVILLE RIVER, ALPINE OIL - 120100 Well Name: COLVILLE RIV UNIT CD2 -60A Program SER Well bore seg [I PTD #:2091150 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 50360 On /Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes Alpine Oil Pool 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 59 -52 -180. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 9/30/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 018.000 • 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(1.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in CD2 -60 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in CD2 -60 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented to GL 21 CMT vol adequate to tie -in long string to surf csg NA 7" intermediate casing cemented .. OH completion 22 CMT will cover all known productive horizons No OH completion 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re -drill, has a 10 -403 for abandonment been approved Yes 309 -343 Plug perforations 26 Adequate wellbore separation proposed Yes Proximity analysis performed. WB is 300' parallel to original completion. 27 If diverter required, does it meet regulations NA Wellhead in place Appr Date 28 Drilling fluid program schematic & equip list adequate Yes KWF = 8.7 ppg Will drill with 10.3 ppg mud GLS 9/30/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2631 psi Will test BOP's to 3500 psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S in CRU. Rig has sensors and alarms in the event H2S is encountered. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR performed, Replacement wellbore 300' away and parallel to CD2 -60. 35 Permit can be issued w/o hydrogen sulfide measures Yes Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/30/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date to / -p,
