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Home My WebLink About205-017MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-17A COLVILLE RIV UNIT CD2-17A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 CD2-17A 50-103-20406-01-00 205-017-0 W SPT 6938 2050170 1734 2247 2247 2253 2256 750 755 750 750 4YRTST P Matt Herrera 6/27/2022 MIT-IA Performed to 3000 PSI Per Operations 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 CD2-17A Inspection Date: Tubing OA Packer Depth 390 2980 2880 2880IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629143424 BBL Pumped:2.1 BBL Returned:2.1 Thursday, July 21, 2022 Page 1 of 1         MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: Jim Regg P.I.Supervisor Ne* (i sl 7 j SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-17A FROM: Brian Bixby COLVILLE RIV UNIT CD2-17A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-17A API Well Number 50-103-20406-01-00 Inspector Name: Brian Bixby Permit Number: 205-017-0 Inspection Date: 6/5/2018 Insp Num: mitBDB180610163746 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-17A ';Type Inj W -TVD 6938 Tubing 1915 - 1915 - 1915 1915 PTD 2050170 Type Test SPT Test psi 1734 ' IA 550 2800 2730- 2730 BBL Pumped: '' 1.8 - BBL Returned: 1.9 - OA 610 - 825 825 - 825 Interval ' 4YRTST P/F P ✓ Notes: SCANNED JUN 21 tu» Pae1of1 Monday,June 11,2018 g • • Image Project Well History Fite 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. ~~ - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III II~IIIII III IIIII ^ Rescan Needed III II~IIIIIII IIIII RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria '' Date: ~~ ~ ~ /s/ i Project Proofing , III II III II III II III BY: ~ Maria Date: ~ ~ ~ (~' ~ ~ ~ /s/ (I Scanning Preparation _~ x 30 = t~~ + ~ =TOTAL PAGES ~~ ount oes not include cover shdet BY: Maria Date: 1 ~ ~~ ~ I ~ ~ (C d /s/ ) Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: //~(~' ~ ~ /s/ / ~~ 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. II I II')11 I II II I (III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III II'I III 10/6/2005 Well History File Cover Page.doc • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED April 01, 2011 N to 4 x'11 Atoka ail & fins Cons. Commission Commissioner Dan Seamount Anctorag@ Alaska Oil & Gas Commission u 8 2011 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 aos- 1 7A Commissioner Dan Seamount: 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 Ci, CO2 -17A _ 50103204060100 ..2.05' 4" n/a 14" n/a 3.6 3/14/2011 t�1A` CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 l CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 �u�`� `� 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 CD2 -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 MEMORANDUM Toy Jim Regg P.I. Supervisor ~ ~~~ ~(Z>~~l v FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-] 7A COLVILLE RIV UNIT CD2-17A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Jg~ Comm Well Name: COLVILLE RIV UNIT CD2-17A API Well Number: 50-103-20406-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ100719121645 Permit Number: 205-017-0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-17A ;Type Inj. `~' TVD 6938 IA ~ 470 2300 2220 2210 ' ~ ~ P.T.D zosol7o TypeTest SPT 1735 Test psi QA 350 400 420 420 InterVal4YRTST P~F P ~ Tllblllg 1430 1430 1430 1430 Notes: 1.7 BBLS diesel pumped. 1 well inspected; no exceptions noted. ' Monday, July 26, 2010 Page I of 1 • ~. -• ~ a~~o~~2oos DO NOT PLACE ~' .~~"" F ~ ;' " ;,~„w° __ - ~- ANY NEW MATERIAL UNDER THIS PAGE F:1l~aserFicl~iCvrPgs_InsertstAiticrofilm Mazkei:~c ~~ ~.._J Memorandum To: Colville River Unit Well History File #202-015 Re: Administrative Abandonment Action Colville River Unit CD2-17 Permit #202-015 January 3, 2006 This memo will remain at the front of the subject well file. Colville River Unit ("CRU") well CD2-17A (permit #205-017, API # 50-103-20406-01) replaces CD2- 17 (permit #202-015, API # 50-103-20406-00) effective October 18, 2005, which is the date drilling operations began for CRU CD2-17A. CRU CD2-17A incorporates an extension to a new bottom hole location from the existing CRU CD2-17 well bore. This extension, along with the original well bore, will be used for production of hydrocarbons. A review of both well .history files indicates administrative abandonment of the originating well bore is appropriate according to current Commission procedures for wells when an additional permitted extension is drilled from an existing well bore. 20 AAC 25.005(a) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, Commission databases require each conductor has only one permit number and API number. Administrative abandonment of the original well bore only eliminates duplication in databases. Information for the original well and its replacement will be maintained in their respective files. The operator has been notified of this action, All future correspondence with the Commission should reflect the new well name, permit number, API number and well data. ~~,~ Statistical Technician Reservoir Engineer r _~ ~T',ti // a ~~~ Petroleum Geologist Commissioner /~ .~,~ • State of Alaska Oil and Gas Conservation Commission cc: Well History File #205-017 ~1 lU"o v ~.0~? DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050170 Well Name/No. COLVILLE RIV UNIT CD2-17A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20406-01-00 MD 11819 TVD 7142 Completion Date 10/21/2005 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Log s Run: GR/Res/Dens/Neutron (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED , D Asc Directional Survey 8581 11819 Open 11/17/2005 Definitive C Pdf 13789 Induction/Resistivity 8756 11819 Open 3/9/2006 ROP DGR EWR (Graphics .emf & .pdf) !QED D Lis 13792 Induction/Resistivity 8500 11758 Open 3/9/2006 GR EWR4 ABI ROP PWD C .Laa~,i ~ 14419 T Induction/Resistivity 8500 11819 Open 1/29/2007 LIS Veri, GR, ROP, FET I - - --.-. ------_ _ _ w/Graphics _~ Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? ~' Y nplJ Chips Received? -'H-~" Analysis Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ~~ N Date: ~ ~~'1 Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 1 1, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~bs~ ~ i7 Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace; 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ,~~ ,~ /~~ ~`'~'l M.. Loveland ConoeoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na Z.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16'' na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/172007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CDZ-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4!16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2!18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3!8/2007 ~ .. onocoPhill~p~ Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. Asper 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment r.. • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31.2007 Well Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2118/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17!2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 _ 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007. CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3!8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165- 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16!2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068. 6" na 6" na 1 3/8/2007 • :. WELL LOG TRANSMITTAL To: State of Alaska November` 16, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: CD2-10_PB1, CD2-11, CD2-17A, CD2-27, CD2-28 PB1, CD2-30. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd. , Anchorage, AK 99518 cD2-1o PB1: X03 -79~ ~" ~~1~11~ Digital Log Images: 1 CD Rom 50-103-20473-00,70 v zc CD2-11: aU~ - t3a ~ l~~/~ ~ Digital Log Images: 1 CD Rom 50-103-20515-00 CD2-17A: U ~ 2US- U i'} '~ l ~~~1(°, Digital Log Images: 1 CD Rom 50-103-20406-01 cD2-27: ~.1TC- X03 - ~~~- t ~-!~! ~~ Digital Log Images: 1 CD Rom 50-103-20471-00 cDZ-zs PBI: ~~~ -2-.~ '~ ~~-~L/i5 Digital Log Images: I CD Rom 50-103-20435-00, 70 CDZ-30: v ?' C X03 - - 3S ~ f ~'~lI~.I Digital Log Images: 1 CD Rom 50-103-20465-00 MEMORANDUM TO: Jim Regg ,~ ~.,,jh,- P.I. Supervisor j ~~~ ~ ~ ~ ~'1 L~' FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-17A COLVII.LE RIV UbIIT CD2-17A Src: Inspector NON-CONFIDENTIAL a~s.o-~ Reviewed By: P.I. Suprv ~-~ ~~" Comm Well Name• COLVILLE RIV UNIT CD2-17A Insp Num• . mitCS060827193850 Rel Insp Num API Well Number 50-103-20406-01-00 Permit Number 205-017-0 Inspector Name• Chuck Scheve Inspection Date• 8/27/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-17A TYPe Inj. G TVD 6938 IA 1440 2500 2490 2490 P.T. 2oso17o TypeTest SPT Test psi 173as OA 7zo 9so 9so 9so Interval 4YRTST Pni P ;~ Tubing 26s0 26s0 2650 2650 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. Wednesday, August 30, 2006 Page 1 of 1 MEMORANDUM TO: Jim Regg K~ c7 3l l ~ J ~ P.I. Supervisor ~f FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, March 02, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-17A COLVILLE RIV 1JNIT CD2-17A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,-) ~- Comm Well Name: COLVILLE RIV UNIT CD2-17A Insp Num: mirJCr060209082741 Rel Insp Num API Well Number 50-103-20406-01-00 Permit Number: 205-017-0 Inspector Name: John Crisp Inspection Date: 2/4/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 'CD2-17A (Type InJ. ~ W TVD ~ , 7496 ' IA i 400 ~ 2005 1940 i 1950 ~ ' P.T. 2050170 ;TypeTest ~ SPT Test psi ~ 1874 ~ OA ~ 400 600 ~ 550 550 ~ Interval INITAL p~ P Tubing ~ 1521 ~ 1521 1521 ~ 1521 Notes IA pressures monitored & stable prior to test. No tubing to IA problems reported by Operator. .9 bbl pumped for test. Thursday, March 02, 2006 Page I of 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-17A, March 08, 2006 AK-MW-3985790 CD2-17A: Digital Log Images: 50-103-20406-01 1 CD Rom 0 3~8~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 .,, ,~ Date: ~ 4 Signed: dos-~or~ h'l~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-17A, February 27, 2006 AK-MW-3985790 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~ ?`~~ 1 LDWG formatted Disc with verification listing. API#: 5 0-103 -20406-0 l . gW~.Zro~ G~~ ~v~=®d7 ~'~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Alpine CRU CD2 02/04/06 Dusty Beller -AES John Crisp Packer De th Pretest Initial 15 Min. 30 Min. Well CD2-17A T e In'. W TVD 7,496' Tubin 1521 1521 1521 1521 Interval P.T.D. 2050170 T e test P Test si 1874 Casing 400 2005 1940 1950 P/F P Notes: Initial MIT OA 400 600 550 550 Well CD2-59 T e Inj. W TVD 6,899' Tubin 1826 1826 1826 1826 Interval I P.T.D. 2042480 Type test P Test si 1725 Casing 550 2012 2000 2000 P/F P Notes: Initial MIT OA 700 800 800 810 Well CD2-02 T e In'. W TVD 7,105' Tubing 1637 1637 1637 1637 Interval I P.T.D. 2051090 T e test P Test si 1776 Casing 550 2420 2400 2390 P/F P Notes: Initial MIT OA 500 650 650 650 Well CD2-60 T e In'. W TVD 7,035' Tubing 1967 1967 1967 1967 Interval I P.T.D. 2050680 T e test P Test psi 1759 Casing 250 2040 2020 2010 P!F P Notes: Initial MIT OA 420 620 620 620 Well T pe In~. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9!1/05 MIT CRU CD2 02-04-06-1.xls C ~~ ~ ~~ ~ ~~° ~~ ~ ~~~ ~ j ~ Ij ALASSiA OIL AHD GAS C011T5ERQATIOI~T COl-II-II5SI011T January 9, 2006 Mr. Chip Alvord Alpine Drilling Team Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Administrative Abandonment Action Colville River Unit CD2-17 Permit # 202-0 l 5 Dear Mr. Alvord, • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Colville River Unit ("CRU") well CD2-17A (permit #205-017, API # 50-103-20406-01) replaced well CRU CD2-17 (permit #202-015, API # 50-103-20406-00) effective October 18, 2005, which is the date drilling operations began for CRU CD2-17A. CRU CD2-17A incorporates an extension to a new bottom hole location from the existing CRU CD2-17 well bore. This extension, along with the original well bore, will be used for production of hydrocarbons. A review of both well history files indicates administrative abandonment of the originating well bore is appropriate according to current Commission procedures for wells when an additional permitted extension is drilled from an existing well bore. 20 AAC 25.005(a) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, Commission databases require one permit number and API number for each conductor. Administrative abandonment of the original well bore only eliminates duplication in databases. Information for the original well bore and its replacement will be maintained in their respective files. Please notify other affected personnel in your organization so that the well will be correctly identified on subsequent reports and applications submitted to the Commission. Sincerely, ~%~~ Robert Flecken Statistical Technician cc. Commission Well History File #205-017 Commission Well History File #202-015 cD2-1~a X205-01~~ • ~~# ~~i>o dos of l Subject; CDZ-17~~ (205-017) From: Thomas h`tauncler <torn_maunder@adrnin.state.ak.trs> Datc: Thu, ~y Dec ?OOH ~1ti:~~: l i -~19~)li To: Vcrn.fohilsc~r~ -.Vcrn..lohn~or~<<i.c~~nocophillips.c~~m- CC: Chip _~I~ or~i ~~('hip.,~~1~ ord~c~con~~cophillips.coi~~= Vern and Chip, I was just looking at the completion report for CD2-17A. In the operations summary, it is noted on October 15 that it was necessary to use the BOP to prevent flow from the well. I have looked in my records and I don't find any notice regarding this event. I found others. From the summary, it appears that you all were alternately battling lost circulation and flow which is not unusual given the well history and operations. Needing to use the BOP would likely be expected. Would you please check your records on this?? Thanks, Tom Maunder, PE AOGCC 1 of 1 12/29/2005 2:11 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ~ Exploratory I^I Service ^~ Stratigraphic Testa 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ oraband.: October 21, 2005 12. Permit to Drill Number: 205-017 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ ~ October , 2005 r• 3`dr" 13. API Number: 50-103-20406-01 4a. Location of Well (Governmental Section): Surface: 1736' FNL, 1543' FEL, Sec. 2, T11 N, R4E, UM ~ 7. Date TD Reached: October 20, 2005 14. Well Name and Number: CD2-17A At Top Productive Horizon: 108' FSL, 55' FEL, Sec. 35, T12N, R4E, UM 8. KB Elevation (ft): 33' RKB / 52' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 1767' FNL, 1801' FEL, Sec. 35, T12N, R4E, UM 9. Plug Back Depth (MD + ND): 11819' MD / 7142' TVD Alpine Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371698 ~ y- 5974622 ! Zone- 4 10. Total Depth (MD + ND): ~ 11819' MD / 7142' .Property Designation: 380075, 25530 TPI: x- 373216 y- 5976440 Zone- 4 Total Depth: x- 371526 ' - 5979874 ' Zone- 4 11. Depth where SSSV set: ~]E'~' Landing Nipple @ 1998' c,,. ~ 17. Land s rmit: ~QQ ~ ALK ASRCNPRA 18. Directional Survey: Yes ^~ No 19. Water Depth, if Offish- - ~ p!1 ~ ~~ N/A fe M L 20. Thickness of ~~• GQ 1756' MD 21. Logs Run: ~~ ~JS'7°IYI'~, °7ig/''~-a jf~ GR/Res/Dens/Neutron ~ ~~ ~' ~ ` r'(" 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 33' 114' 33' 114' 42" 306 sx AS I 9.625" 36# J-55 33' 2382' 33' 2378' 12.25" 365 sx AS III Lite, 245 sx Class G 7" 26# L-80 33' 8184' 33' 7177' 8.5" 151 sx Class G 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 7570' 7496' open hole completion from 8164' - 11819' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection December 14, 2005 Method of Operation (Flowing, gas lift, etc.) Injector Date of Test not applicable Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". I~®MS ~~~. ~t1 , y:} '? ?006 NONE ~ ff~-:~'p~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE za. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-17A Seabee Form. 2410' 2407' Nanushak 3918' 3844' Gamma Ray Shale 7276' 6777' Kalubik 7541' 6968' Kuparuk Formation 7614' 7013' Miluveach 7715' 7064' Top Alpine D 7915' 7141' Top Alpine C 7gg8' 7160' Base Alpine C 11724' 7142' N/A TD 11819' 7142' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern JohnSOn @ 265-6081 Printed Name Ivord Title: Alpine Drilling Team Leader Si nature Phone D t I ~ ~~ ~ ~ g ~~ ~~ ~ r~ a e INSTRUCTIONS Prepared by Sharon Allsup-Drake 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. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List ail test information. if none, state "None". Form 10-407 Revised 12/2003 • ConocoPhillips Alaska Operations Sumrnary Report Page 1 of 5 Legal Well Name: CD2-17 Common Well Name: CD2-17 Spud Date: 10/12/2005 Event Name: ROT -DRILLING Start: 10!12/2005 End: 10/21/2005 Contractor Name: Doyon Drilling Inc Rig Release: 10/21/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Code Phase Description of Operations 10/12/2005 14:00 - 14:30 0.50 WELLS KILL DECOMP P/U lubricator and pulled BPV w/ FMC. R/D lubricator. 14:30 - 19:00 4.50 WELLS KILL DECOMP Installed annulus valve. R/U lines to tubing and annulus for kill operations. Took on 9.3 ppg. brine to pits. 19:00 - 21:00 2.00 WELLS KILL DECOMP Held PJSM. Displaced 9.3 ppg brine staging pump from 1 BPM to 3.2 BPM. Returns 1:1 throughout. 21:00 - 21:30 0.50 WELLS KILL DECOMP Blew down and R/D lines and shut in well. Well on vacuum @ completion, filling hole down annulus w/ hole fill (100 bph losses). 21:30 - 00:00 2.50 WELLS NUND DECOMP Held PJSM. Rig up pumpdown sub, BOPS and lubricator for wireline tubing cut. Losses constant @ 100 bph. 10/13/2005 00:00 - 07:30 7.50 WELLS OTHR DECOMP Continue to rig up Halliburton slick line -PJSM - RIH w/dummy run & tag up on XN nipple -POOH -Change tool string - MU chemical cutter - RIH & get on depth -Arm tool -Cut 4 1/2" tbg @ 7536' -POOH w/ wireline tools into lubricator Hole taking fluid @ 100 to 120 bbls / hr 07:30 - 09:00 1.50 WELLS CIRC DECOMP RU & spot LCM pill @ 3 bbls/min @ 300 psi -observed returns @ pits w/ 20 bbsl pumped -blow down lines 109:00 - 12:00 3.00 WELLS NUND DECOMP RD Hallibutron chemical cutter tools - RD Hallibutron lubricator & BOP I Hole taking fluid @ 45 to 55 bbls/hr Lost 1193 bbls 9.3 brine last 12 hrs. 12:00 - 12:30 0.50 WELLS NUND DECOMP Cont'd rig down slickline. 12:30 - 13:30 1.00 WELCT EORP DECOMP Set TWC and tested to 5000 psi. 13:30 - 14:30 1.00 WELCT NUND DECOMP N/D tree. 14:30 - 16:30 2.00 WELCT NUND DECOMP N/U BOP. 16:30 - 00:00 7.50 WELCT BOPE DECOMP Test BOPE - Hydril to 250 & 3500 psi -Pipe rams ,blind rams, choke & kill line valves, choke manifold valves, floor safety & dart valves. Performed accumulator closure test. -Witnessing of test waived by i John Spaulding AOGCC. ~ Brine loss slowed to +/- 7 bbl/hr. Total losses for tour 85 bbls. 10/14/2005 00:00 - 00:30 0.50 WELCT BOPE DECOMP ' Continue w! BOPE test - LD test jt. -Test blind rams TD auto & manual IBOP's to 250 ~ 5000 psi - BOPE test complete - RD test equipment 00:30 - 02:30 2.00 CASE OTHR DECOMP MU landing jt. -Unseat tbg hanger & pulled to rig floor - PU wt. 155 K - LD tbg hanger 02:30 - 10:30 8.00 CASE OTHR DECOMP RU -Pull & LD 4 1/2" tbg - 152 jts. - ' Loss rate increasing to 30 to 45 bbls/hr 10:30 - 11:30 1.00 CASE CIRC ; DECOMP Observed diesel/brine mix in tbg - RU & circulate tgb & annulus volume @ 857' 11:30 - 13:00 1.50 CASE OTHR DECOMP Continue pulling & laying down 4 1!2" tbg - 19 jts. plus GLM & 7.40' cut-off pup jt f/ top of packer - (LD total 171jts. tbg - DB nipple -GLM & 7.40' cut off) Top of fish @ 7538.45' 13:00 - 14:00 ~ 1.00 RIGMNT RSRV DECOMP Service rig -monitor well on TT -Loss rate @ 30 bbls/min. 14:00 - 14:30 0.50 FISH OTHR DECOMP ! Bring fishing tools up to rig floor 14:30 - 15:00 0.50 FISH OTHR DECOMP I Set wear ring. 15:00 - 17:00 2.00 FISH PULD DECOMP M/U milling BHA to 294.15'. 17:00 - 19:45 2.75 FISH TRIP DECOMP RIH from 294' to 7,483' MD. 19:45 - 00:00 4.25: FISH FISH DECOMP Est'd circ. @ 7483'. ! String wt. PU 195 SO 170 Rot 185 ~ Torque on/off btm. - 10/7 k ~ i Tagged packer top w/grapple @ 7541' unable to work down far ~ ; enough to engage mill. Continued attempt. Printed: 11/14/2005 3:58:06 PM • ConocoPhilli'ps-Alaska Page 2 of 5 Operations Summary Report Legal Well Name: CD2-17 Common Well Name: CD2-17 Spud Date: 10/12/2005 Event Name: ROT -DRILLING Start: 1 011 212 0 0 5 End: 10/21/2005 Contractor Name: Doyon Drilling Inc Rig Release: 10/21/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code '' ~ de Phase Description of Operations 10/15/2005 00:00 - 01:00 1.00 FISH MILL DECOMP Attempt to mill on packer -unable to get gripple into top of packer - Spot hi vis LMC pill 3 BPM @ 460 psi Loss rate while attempting to mill 80 BPH 01:00 - 04:30 3.50 FISH TRIP DECOMP Monitor well for 10 mins -well static -POOH on TT w/milling assembly f/ 7538' to 294' -flow check fluid level dropping 04:30 - 07:30 3.00 FISH TRIP DECOMP Change out milling assembly - LD PRT - PU packer mill -RIH to 291' 07:30 - 10:30 3.00 FISH TRIP DECOMP ~ RIH f/ 291' to 7470' -Wash down f/ 7470' to 7538' -tagged top of tbg stub 10:30 - 12:00 1.50 FISH MILL DECOMP Mill on tbg stub f/ 7538' to 7540.6' -Mill on packer f/ 7540.6' to 7541' WOB 6/8k RPM 75 GPM 131 @ 280 psi String wt. PU 195 SO 170 Rot 185 I Torque on/off btm. - 7500/6500 ft. lbs. i Lost 467 bbls brine last 12 hrs. 12:00 - 13:00 1.00 FISH MILL DECOMP , Continue milling over packer f/ 7541' to 7542' WOB - 6/10 k RPM 80 GPM 130 @ 180 psi Observed increase in flow rate -shut down pumps -well flowing -shut -in well - 15 bbl gain 13:00 - 15:30 2.50 WELCT KILL DECOMP Well shut in (SIDP - 10 psi SICP - 140 psi monitor well 5 mins. SIDP 10 psi 180 psi Circulate out kill through choke -shut in well monitor pressure SIDP - 0 SIC - 0 -open well -monitor well fulid level dropping -blow down ckoke line & manifold 15:30 - 17:30 2.00 FISH CIRC DECOMP Pump 40 bbls hi vis sweep w/ 1/4 #/bbl -super sweep - 17:30 - 18:30 1.00 FISH CIRC DECOMP Spotted hi-vis LCM pill. Checked flow, static. 18:30 - 22:00 3.50 FISH TRIP DECOMP POOH on TT from 7,542' to 290'. Checked flow, fluid level dropping. 22:00 - 23:00 1.00 FISH TRIP DECOMP POOH on TT from 290' to surface. VD mill and junk baskets. 1 23:00 - 23:30 0.50, FISH PULD DECOMP M/U spear assembly to 86'. 23:30 - 00:00 0.50 RIGMNT RSRV DECOMP Performed rig service. ~ Total losses for tour = 350bb1s. 10/16/2005 00:00 - 00:30 0.50 FISH ~ PULD DECOMP Finish MU fishinging assembly - spear,BS, Jars, DC's,Acc - to 276' 00:30 - 03:30 3.00 FISH TRIP DECOMP RIH f/ 276' to 7525' 03:30 - 04:30 1.00 FISH FISH DECOMP Establish circ. -wash down & engage fish @ 7565' - (fish move 23' downhole before being engaged) -POOH to 7525' 04:30 - 05:00 ~ 0.50 FISH CIRC DECOMP Spot hi-vis pill @ 3 bbls/min @ 450 psi 05:00 - 09:00 4.00 FISH TRIP DECOMP POOH on TT w/ fish f/ 7525' to 3040' 09:00 - 10:30 1.50 RIGMNT RGRP DECOMP Repair link tilt on top drive 10:30 - 12:45 2.25 FISH I TRIP DECOMP Continue POOH on TT w/ fish f/ 3040' to 276' 12:45 - 13:45 1.00 FISH PULD DECOMP Handle BHA -std back DC's - LD jars - LD spear w/ packer (2.86') mill out extension, pup jt 13:45 - 15:15 1.50 FISH PULL DECOMP LD fish 2 jts 4 1/2" tbg , XN nipple, 6 jts 4 1/2" tbg, WLEG -Recovered all of fish -all connections below packer ' were made up w/ BakerLoc -used Prota-band saw on cut pipe 6" above collars 15:15 - 16:00 0.75 ~ FISH I PULD DECOMP PU spearw/ packer assembly -attempt to disengage spear -unable to I disengage spear -Broke out XO's & bumper sub - LD down packer i assembly w/ spear 16:00 - 16:30 0.50 FISH PULD DECOMP PU tools for scraper run 16:30 - 17:30 1.00 FISH PULD DECOMP M/U BHA to 279'. ; 17:30 - 21:30 4.00 FISH TRIP DECOMP RIH with scraper and junk baskets from 279' to 8,175' Printed: 11/14/2005 3:58:06 PM • ConocoPhillips Alaska Operations Summary-Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To CD2-17 CD2-17 ROT -DRILLING Doyon Drilling Inc Doyon 19 Hours ' Code ,Code Phase Start: 10/12/2005 Rig Release: 10/21/2005 Rig Number: 19 Page 3 of 5 Spud Date: 10/12/2005 End: 10/21/2005 Group: Description of Operations 10/16/2005 17:30 - 21:30 4.00 FISH TRIP DECOMP PUW=200 SOW=170 @ 8,175'. SPR#1=20stk/150psi, 30stk/240psi 21:30 - 23:00 1.50 FISH CIRC DECOMP Circ'd hi-vis sweep containing SuperSweep fiber @ 30 BPM w/ 300psi. 23:00 - 23:15 0.25 WELCT OBSV DECOMP Shut pumps off to break jt. Observed well flowing, shut in well. Observed for approx. 10 min w/ SITP=O SICP=O. Opened well and monitored decreasing returns. Well breathing. Contacted CD-2 pad operator and shut-in adjacent injection wells. 23:15 - 00:00 0.75 FISH CIRC DECOMP Cont'd to circ sweep in order to get fiber OOH (possible plugging issue if well had to be lined up to choke again). Pumped 30 BPM w/350 psi and no indications of gas. Total brine loss for tour = 325 bbls 10/17/2005 00:00 - 00:30 0.50 FISH CIRC DECOMP Finish circulating out Hi-vis sweep w/super sweep 1/4#/bbl -Spot hi-vis pill 00:30 - 07:00 6.50 FISH TRIP DECOMP Ftow check(static) -POOH on TT f/ 8401' to 279' -Flow check(fluid level dropping) 07:00 - 09:00 2.00 FISH PULD DECOMP LD DC's - scraper,boot bskts, bumper sub, jars -clean boot bskts - clean & clear floor of tools 09:00 - 12:00 3.00 DRILL PULD DECOMP MU 6 1/8" drilling assembly - bit,motor,MW - RIH w/ NM flex DC's & 1 std HWDP Shallow pulse test MWD i Static losses 12 bblslhr Lost 255 bbls last 12 hrs. 12:00 - 16:00 4.00 DRILL TRIP PROD RIH w/drilling assembly f/ 370' to 8,095'. PUW=190K SOW=165K ROT=185K TOon/off=7.5K/7K SPR#2=20stk/410psi, 30stk/630psi @8,095'. 16:00 - 17:00 1.00 RIGMNT RSRV PROD Cut and slipped 60' drill line. Monitored well on TT. 17:00 - 17:30 0.50 RIGMNT RSRV PROD Serviced TD, draw works, and iron roughneck. 17:30 - 19:00 1.50 DRILL CIRC PROD Changed over brine to FloPro @ 9.1 ppg. 19:00 - 20:30 1.50 DRILL REAM PROD Washed and reamed from 8,095' to 8,384'. 20:30 - 21:00 0.50 DRILL CIRC PROD Circ'd buttoms up @ 220 gpm and 1400 psi. 21:00 - 21:30 0.50 DRILL REAM PROD Cont'd to wash and ream from 8,384' to 8,500'. 21:30 - 00:00 2.50 DRILL REAM PROD Cont'd to wash and ream from 8,500' to 8,680'. MAD pass from 8,500'. Total brine loss for tour = 160 bbls Total FloPro loss for tour = 360 bbls 10/18/2005 00:00 - 00:30 0.50 DRILL REAM PROD Wash & ream f/ 8680' to 8756' (Mad pass) RPM 50 GPM 220 @ 1320 psi 00:30 - 12:00 I 11.501 DRILL I DRLH I PROD 12:00 - ! I DRILL I DRLH I PROD Drill 6 1/8" horz. hole f/ 8756' to 9461' MD 7172' TVD ADT - 7.47 hrs.=ART - 5.25 hrs. AST - 2.22 hrs. WOB 517 k RPM 75 GPM 220 @ 1840 psi String wt. PU 190 SO 160 Rot 180 Torque on/off btm. - 9000/8000 ft. lbs. ECD - 9.9 to 10.2 ppg Loss rate 30 bbls/hrs. -Observed well breathing on connections Lost 546 bbls FlowPro to hole last 12 hrs. Drill 6 1/8" horz. hole f/ 9461' to 10,261' MD 7154' TVD ADT - 11.35 hrs.=ART - 9.7 hrs. AST -1.65 hrs. WOB 5/8 k RPM 75 GPM 220 @ 1930 psi String wt. PU 195 SO 160 Rot 185 Torque on/off btm. - 9000/8000 ft. lbs. @ 10,261' ECD - 10.2-10.4 ppg .~1 ~----- ~z,t1a AQ ~~~ t' Printed: 11/14/2005 3:58:06 PM • ConocoPhillips Alaska Page 4 of 5 Operations Summary Report Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase 10/18/2005 12:00 - DRILL DRLH PROD 10/19/2005 00:00 - 12:00 , 12.00 DRILL DRLH PROD Spud Date: 10/12/2005 Start: 10/12/2005 End: .10/21/2005 Rig Release: 10/21/2005 Group: Rig Number: 19 Description of Operations Loss rate 30 bbls/hrs. -Observed well breathing on connections Lost 531 bbls FlowPro to hole last 12 hrs. Drill 6 1/8" horiz. hole f/ 10,261' to 10,850' MD - 7143' TVD ADT - 6.01 hrs. =ART 4.36 hrs. AST 1.65 hrs. WOB 5/7 k RPM 75 GPM 220 @ 2140 psi String wt. PU 195 SO 150 Rot 175 Torque on/off btm. - 9500/8000 ft. lbs. ECD - 10.2 to 10.7 ppg Hole still taking fluid @ 30 bbls/ hr & breathing on connections Lost 345 bbls last 12 hrs. 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD Performed exhale test to confirm well breathing Drill 6 1/8" horiz. hole f/ 10,850' to 11,283' MD - 7148' TVD ADT - 8.50hrs. =ART 4.25 hrs. AST 4.25 hrs. WOB 5/10 k RPM 75 GPM 220 @ 2200 psi String wt. PU 200 SO 145 Rot 175 Torque on/off btm. - 9000/8000 ft. lbs. ECD - 10.2 to 10.7 ppg Hole still taking fluid @ 30 bbls/ hr & breathing on connections Lost 283 bbls last 12 hrs. 10/20/2005 ~ 00:00 - 06:00 6.00 DRILL DRLH PROD Drill 6 1/8" horiz. hole f/ 11,283' to 11,819' MD 7142' TVD ADT - 4.2 hrs. WOB - 8/10 k RPM 75 GPM 220 @ 2200 psi String wt. PU 200 SO 145 Rot 175 ii Torque on/off btm - 10,500/9,500 ft. lbs. ECD - 10.4 to 10.7 ppg hole still breathing on connections 06:00 - 07:30 I 1.501 DRILL I CIRC I PROD 07:30 - 12:00 4.50 DRILL TRIP PROD 12:00 - 15:45 3.75 DRILL TRIP PROD 15:45 - 16:15 0.50 DRILL OBSV PROD 16:15 - 17:45 1.50 DRILL CIRC PROD 17:45 - 18:30 0.75 DRILL CIRC PROD 18:30 - 23:15 4.75 DRILL TRIP PROD 23:15 - 00:00 0.75 DRILL PULD PROD 10/21/2005 00:00 - 01:30 1.50 DRILL PULD PROD 01:30 - 02:00 0.50 CMPLTN OTHR CMPLT2 02:00 - 02:30 0.50 CMPLTN OTHR CMPLT2 02:30 - 08:45 6.25 CMPLTN RUNT CMPLT2 Circ hole clean -pumped hi vis sweep - 220 gpm @ 2200 psi w! 75 rpm - lost rate picked up w/ sweep in annulus (80 bbls/hr) Slow pump rate added LCM POOH w/ pump f/ 11,819' to 10,386' - 3 BPM @ 700 psi w/ 50 rpm POOH w/ pump from 10,386' to 8,184' @ 3 BPM, 50 RPM, 630 psi. Observed well by performing exhale test for 10 min. w/ SIDPP=O SICPP=O. Blew down. Displaced remainder of well from FloPro to 9.4 ppg brine. Spotted LCM pill. Performed flow check for 15 min, static. POOH on TT from 8,184' to 370'. Checked flow, losing to hole. Cont'd POOH on TT from 370' to 89'. Flushed BHA w/ H2O and Conqor. Losses for tour = 60 bbls FloPro Losses for tour = 35 bbls brine Stand back NM flec DC's & jars -Down load MWD - LD BHA Pull wear bushing Rig up to run 4 1/2" completion -Held pre job meeting Run 4 1/2" completion as follows: All pipe 4 1/2" 12.6# L-80 IBTM tbg (used) WLEG - pup jt. - XN nipple (seated in RHC plug) 1 jt. tbg (all connections below packer made up w/ BakerLoc) Baker Premier Packer - 2 jts. tbg -Camco GLM assembly - 123 jts. tbg -Camco DB nipple - 45 jts tbg -FMC tbg hanger w/ pup jt. (171 jts. total) Landed w/ Printed: 11/14/2005 3:58:06 PM • ConocoPhillips Alaska Page 5 of 5 Operations Summary Report Legal Well Name: CD2-17 Common Well Name: CD2-17 Spud Date: 10/12/2005 Event Name: ROT -DRILLING Start: 10/12/2005 End: 10/21/2005 Contractor Name: Doyon Drilling Inc Rig Release: 10/21/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code 'Code Phase Description of Operations 10/21!2005 02:30 - 08:45 6.25 CMPLTN RUNT CMPLT2 tbg tail @ 7569.56' - XN nipple @ 7557.14' -packer @ 7495.81' - GLM @ 7383.14' & DB nipple @ 1998.46' String wt. PU 155 SO 140 08:45 - 09:15 0.50 CMPLTN OTHR CMPLT2 Run in lock downs on tbg hanger - LD landing jt.A -set TWC - MU landing jt. B -Test tbg hanger seal to 5000 psi for 10 mins. - LD landing jt. B 09:15 - 12:15 3.00 CMPLTN NUND CMPLT2 ND BOPE - NU tree & test to 5000 psi 12:15 - 13:00 0.75 CMPLTN NUND CMPLT2 RU squeeze manifold & hard lines to wellhead 13:00 - 17:00 4.001 CMPLTN PCKR CMPLT2 PJSM -Test lines to 2500 psi -Pump 104 bbls 9.4 ppg inhibited KCL ~ brine (packer fluid) & 152 bbls diesel (tbg vol plus 2000' TVD into 4 1/2" X 7" annulus for freeze protection) - RU lubricator & drop packer setting rod/ball assembly -Test lines to 5000 psi - Pressure up on tbg to 4749 psi to set packer & test tbg for 30 minutes -final tbg pressure 4319 psi -monitor 4 1/2" x 7" annulus 0 psi -Bleed tbg to 800 psi -Pressure up on 4 1/2" x &7" annulus to 3500 psi & test for 30 mins. - final pressure 3467 psi - Monitor tbg pressure 1300 psi final -Bleed off annulus to 0 psi -bleed tbg to 800 psi -shut in well 17:00 - 18:30 1.50 CMPLTN OTHR CMPLT2 Flush lines w/ water & blow down w/ air - RD hard lines & squeeze manifold - RU FMC lubricator & set BPV -Secure well 18:30 - 21:00 2.50 ~ CMPLTN OTHR CMPLT2 Set mouse hole - LD NM flex DC's -jars - 5 HWDP - 15 jts 4" DP for rig ~ move -move 33 stds 4" DP f/ off driller side to driller side to balance wt. I for move. Pull mouse hole Release rig @ 2100 hrs. -Move to CD2-51 ' Printed: 11/14!2005 3:58:06 PM ~'^~^^^°hillips Alaska, Inc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-17a Job No. AK MW-0003985797, Surveyed: 20 October, 2005 Survey Report 4 November, 2005 Your Ref.• API 501032040601 Surtace Coordinates: 5974622.10 N, 371698.48E (70° 20' 20.0330" N, 151° 02' 28.0077" YIQ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surtace Coorolinates relative to Project H Reference: 974622.10 N, 128301.52 W (Grid) Surtace Coordinates relative to Structure: 178.84 N, 22.07 W (True) Kelty Bushing Elevation: 52.43ft above Mean Sea Level Kelly Bushing Elevation: 52.43ft above Project V Reference Kelly Bushing Elevation: 52.43ft above Structure GR f A Hmfitburt4n CQlriplERy • • Survey Ref: svy524 ConocoPhillips Alaska, lnc. Survey Report forA/pine CD-2 - CD2-17a Your Ref: AP/ 501032040601 , Job No. AK MW-0003985797, Surveyed: 20 October, 2005 A/aska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 8581.93 89.330 332.180 7136.15 7188.58 2372.79 N 1219.97E 5976973.67 N 372958.87E 2309.66 Tie-On Point 8629.93 89.440 332.650 7136.66 7189.09 2415.33 N 1197.75E 5977016.58 N 372937.38E 1.006 2353.25 8723.52 89.150 332.120 7137.81 7190.24 2498.25 N 1154.37E 5977100.24 N 372895.43E 0.645 2438.21 8818.90 88.960 331.120 7139.39 7191.82 2582.16 N 1109.04E 5977184.90 N 372851.54E 1.067 2524.25 8914.60 90.860 331.640 7139.54 7191.97 2666.16 N 1063.20E 5977269.68 N 372807.15E 2.058 2610.42 9010.85 90.430 334.220 7138.45 7190.88 2751.85 N 1019.41E 5977356,11 N 372764.82E 2.717 2698.17 9106.01 92.540 333.150 7135.99 7188.42 2837.12 N 977.24E 5977442.08 N 372724.12E 2.486 2785.41 • 9200.95 92.100 332.220 7132.14 7184.57 2921.40 N 933.71E 5977527.10 N 372682.04E 1.083 2871.74 9296.41 92.860 331.040 7128.01 7180.44 3005.32 N 888.39E 5977611.77 N 372638.17E 1.469 2957.79 9392.18 92.610 336.120 7123.44 7175.87 3090.96 N 845.84E 5977698.13 N 372597.09E 5.305 3045.43 9487.66 91.740 334.430 7119.82 7172.25 3177.62 N 805.94E 5977785.46 N 372558.67E 1.990 3133.95 9583.62 91.050 336.490 7117.48 7169.91 3264.88 N 766.10E 5977873.39 N 372520.33E 2.263 3223.07 9678.42 91.430 333.150 7115.43 7167.86 3350.64 N 725.78E 5977959.83 N 372481.49E 3.545 3310.72 9774.12 90.950 333.020 7113.44 7165.87 3435.95 N 682.47E 5978045.87 N 372439.64E 0.520 3398.07 9869.17 91.050 332.070 7111.78 7164.21 3520.28 N 638.65E 5978130.94 N 372397.28E 1.005 3484.46 9964.83 90.570 329.640 7110.43 7162.86 3603.82 N 592.07E 5978215.26 N 372352.13E 2.589 3570.19 10060.04 92.100 332.640 7108.21 7160.64 3687.17 N 546.14E 5978299.38 N 372307.63E 3.536 3655.71 10156.04 91.790 332.270 7104.95 7157.38 3772.24 N 501.77E 5978385.20 N 372264.72E 0.503. 3742.86 10250.42 91.690 332.380 7102.09 7154.52 3855.78 N 457.95E 5978469.48 N 372222.34E 0.157 3828.47 10346.16 91.060 334.970 7099.79 7152.22 3941.56 N 415.51E 5978555.97 N 372181.37E 2.783 3916.24 10441.86 90.620 333.420 7098.39 7150.82 4027.70 N 373.86E 5978642.82 N 372141.20E 1.683 4004.33 10537.75 89.750 334.470 7098.08 7150.51 4113.85 N 331.74E 5978729.67 N 372100.56E 1.422 4092.45 10633.36 90.940 331.940 7097.50 7149.93 4199.18 N 288.65E 5978815.73 N 372058.94E 2.924 4179.81 10728.09 90.630 331.230 7096.20 7148.63 4282.49 N 243.57E 5978899.80 N 372015.29E 0.818 4265.24 • 10824.00 90.810 333.140 7095.00 7147.43 4367.31 N 198.82E 5978985.37 N 371972.00E 2.000 4352.16 10919.44 90.310 335.230 7094.06 7146.49 4453.21 N 157.27E 5979071.97 N .371931.92E 2.252 4440.02 11015.13 88.540 333.010 7095.02 7147.45 4539.29 N 115.51E 5979158.75 N 371891.64E 2.967 4528.06 11110.39 89.580 333.700 7096.59 7149.02 4624.42 N 72.79E 5979244.60 N 371850.39E 1.310 4615.19 11205.89 90.440 333.480 7096.57 7149.00 4709.96 N 30.32E 5979330.85 N 371809.38E 0.930 4702.72 11301.36 91.420 330.710 7095.02 7147.45 4794.31 N 14.35 W 5979415.95 N 371766.16E 3.077 4789.17 11396.66 91.380 330.610 7092.69 7145.12 4877.36 N 61.04 W 5979499.79 N 371720.91E 0.113 4874.42 11492.20 91.000 332.360 7090.71 7143.14 4961.29 N 106.63 W 5979584.48 N 371676.75E 1.874 4960.50 11587.57 90.310 329.970 7089.62 7142.05 5044.82 N 152.62 W 5979668.79 N 371632.20E 2.608 5046.20 11682.92 90.180 331.810 7089.21 7141.64 5128.12 N 199.01 W 5979752.87 N 371587.25E 1.935 5131.69 11776.43 89.690 332.410 7089.32 7141.75 5210.77 N 242.75 W 5979836.26 N 371544.93E 0.828 5216.40 4 November, 2005 - 10:04 Page 2 of 3 Dri//Quest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report forA/pine CD-2 - CD2.17a Your Ref.• APl 501032040601 Job No. AK ININ-0003985797, Surveyed: 20 October, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11819.00 89.690 332.410 7089.55 7141.98 ~ 5248.50 N 262.46 W 5979874.32 N 371525.86 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 357.170° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11819.OOft., The Bottom Hole Displacement is 5255.06ft., in the Direction of 357.137° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 8581.93 7188.58 2372.79 N 1219.97E Tie-On Point 11819.00 7141.98 5248.50 N 262.46 W Projected Survey North Slope, Alaska Dogleg Vertical Rate Section Comment (°/100ft) 0.000 5255.05 Projected Survey I Survey tool program for CD2-17a From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 11819.00 7141.98 Survey Tool Description MWD Magnetic (CD2-17) • 4 November, 2005 -10:04 Page 3 of 3 DrillQuest 3.03.06.008 • 14-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for We11 CD2-17A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,581.93' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,819.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /y / , , Date ~~ ~e J o~,0 a~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~0~--61? ~ ~~ C, Email to: Winton_Aubert~admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well CD2-17A T e In'. N TVD 6,937' Tubin 700 4,750 4,385 4,321 Interva I P.T,D. 205-017 T e test P Test si 4700 Casin 1,200 P/F Notes: Bleed csg to 0 psi -monitored through ou test 0 psi Well CD2-17A T e In'. N TVD 6,937' Tubin 850 1,250 1,300 1,300 Interva I P.T.D. 205-017 T e test P Test si 3500 Casin 3,538 3,480 3,468 P/F Notes: Well T e In'. TVD Tubing Interva P.T.D. T e tes Test si Casing P/F Notes: Well T e In'. TVD Tubing Interva P.T.D. T e tes Test si Casing P/F Notes: Well T e In'. TVD Tubin Interva P.T.D. T e tes Test si Casin P/F Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ConocoPhillips Alpine / CD17A 10/21 /05 Don Mickey Test Details: TYPE INJ Codes F =Fresh Water Inj G =Gas Inj S =Salt Water Inj N =Not Injecting TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form Revised: 06119!02 CD2-17A MIT Form.xls Re: Doyon 19 10-13-OS Subject: Re:boyon l~ 10-13-05 From: Thomas !~-Maunder <toln_maunder@~dminatate.ak.us> Date: Fri, 14 Oct X005 16:10:3? -0800. To: "J~~hnson, Vern" ~Vern.J~~hns~~n ~r c~~nocophill~}~s.ec~m=', Uc~~~~n 19 C~~mhan~~ elan ~~~d~~yon 1 <<<con~~cophilli~~s.a~m-= C'C: Uuvon (9 l cx~lE~ushcr ~=~lovunl ,'~r'conc~c~r~hiflip~.conz>. Brian noel ~~~~3rian.Nr~cli~rconc~co~hilli}~s.com :: All, I just pulled the file and I understand what you are doing. You are correct that the operation is workover and the well name is CD2-17, however the PTD for CD2-17 is 202-015. Once you recover the "guts and feathers" and begin making new hole, the well name is CD2-17A and the permit number is 205-017. Please remember while you are doing the workover operations, the BOP test interva is 7 days. I don't expect that you all will crowd that time. If your drilling operations start before 7 days have expired, you switch to 14 days. Sorry to be bureaucratic, but if the names and numbers aren't kept straight then Bob F. will be sending you all a message. Keeping the names and numbers straight helps us with the filing as well. Thanks for your attention to these details. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 10/14/2005 4:02 PM: Zane, Don, Vern or Brian, Workover is checked on the form. I knew there was a workover coming up out there, but not on CD2-17. Can someone provide a little information. Thanks, Tom Maunder, PE AOGCC Doyon 19 Toolpusher wrote, On 10/14/2005 3:45 PM: 1 of 1 12/22/2005 10:06 AM STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~ req;,,~;~adrrsi:~.state.ak.us ao~c~ ~`€.Ed~~os c~:~ad:~n.s#ate.ak.us brh ~8ckensten;~acrrsin.state.a:~.ttr Contractor: Doyon Rig No.: 19 DATE: 10/13/2005 ~ Rig Rep.: Welsh/Sena Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey ~~~,~~ l5 i Field/Unit & Well No.: Colville Rv CD2-17 PTD # 1i~0'°f7 ~-i~t ~- ~~5 ~~ t Operation: Drlg: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250!5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drf. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 ~ P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: TimelPressure Test Resu System Pressure 3000 P Pressure After Closure 1600 P 200 psi Attained 33 P Full Pressure Attained 2 min 35 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2225 Number of Failures: 0 Test Time: 10 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ~irn req~ :~adrr:i:~.state.a?c.ur Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Date 10/11/05 Time 11:10 Test start 4:30:00 PM Finish Waived By John Witness SenalKuenzler BOP Test (for rigs) BFL 11/09/04 Doyon1910-13-05 CD2-17A.xls ~~~ ~ ~ ~ ~~~5 ~ ~ ~~~~, ~ ~ ~ ~ ~ ! ~ ~f~' ~ ~ ) ~ ~ ~ '"', ~~ 1 § , .~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~*7~ OIL ~ ~ 333 W. 7"' AVENUE, SUITE 100 CO1~T5ER'QA'1'I011T COMDII5SIOIQ JI ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907j 276-7542 C. Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River CD2-17A ConocoPhilllips Alaska, Inc. Permit No: 205-017 Surface Location: 1736' FNL, 1543' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 1775' FNL, 1797' FEL, SEC. 35, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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 31.45 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. Ple provide at least twenty-four (24) hours notice for a representative of the Commission t wit ss any required test. Contact the Commission's petroleum field inspector at (907) 659- 60~ ger). N DATED thisL~y of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska, I Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 4, 2005 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips Re: Application for Permit to Drill CD2-17A ,c t:.6ow+r1 ~SSt n ~. Q c~C:~<<c ~l ~ ~ c~ ~t v~ `~~ ~C4"~~ J~ ~~ Dear Sir or Madam: c~~OC9,R~©r. ~~ ~ _ ~~ S~~ Q .~~~ p~ ~ S$ rc. ~ U ~t- ConocoPhillips Alaska, Inc. hereby app~ies for a Permit to Drill an onshore injection well from the Alpine CD2 drilling pad. The intended re-entry date for this well is February 20, 2005. It is intended that Doyon Rig 19 drill the well. The tubing and associated completion equipment will be removed and the current openhole section will be lengthened approximately 3050'. ~ Drilling on the original well was stopped due to losses n ower an expected reservoir pressure. The area has since been re-pressured and is now a candidate for wellbore extension operations. '~ CD2-17A will be re-completed as an openhole injector. At the end of the work program the well will be shut in awaiting surface connection. it is also requested that the packer placement requirement be relaxed to place the packer 250 ft TVD above the Alpine formation. This will place the completion at a maximum inclination less than 65 degrees (this also provides for the re-completion packer to be set above the prior packer placement depth), and allows access to the completion with standard wireline tools for future intervention. 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. fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1 ). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 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 setup which replaces diverter f i' f ` ~ ~ ~~, • ~ If you have any questions or require further information, please contact Vern Johnson or Zane Kuenzler at 265-6081 or 265-1308, respectively. Chip Alvord can also be reached by calling 265-6120. Sincerely, Zane ue zler Drilling Engineer Attachments cc: CD2-17A Well File I Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson/Zane Kuenzler ATO 1702/1704 Tim Schneider ATO 1768 Steve Moothart/Jeff Yeaton ATO 1756/1752 Bill Esco Anadarko -Houston Lanston Chin Kuukpik Corporation ORIGINAL ~ • STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL ~9 1 a. Type of Work: Drill ^ Redrill / 1 b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service^/ Development Gas ^ Single Zone ^/ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD2-17A 3. Address 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11809' ~ TVD: 7152' / Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: , Surface: 1736' FNL, 1543' FEL, Sec. 2, T11N, R4E, UM ALK 3800750, 025530 Alpine River Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: '~~ 104' FSL, 50' FEL, Sec. 35, T12N, R4E, UM ASRCNPRA N/A S..Z/a®~0, ' Total Depth: 9. Acres in Property: 14. Distance to 1775' FNL, 1797' FEL, Sec. 35, T12N, R4E, UM ' Wig- T34r ~ o Nearest Property: 50' FEL, Sec. 34 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 371698.48 y- 5974622.1 Zone- 4 (Height above GL): 52 feet well within Pool: Alpine 1A P&A , 213 16. Deviated wells: g'7~i ~ ~ z , ~, p5' 17. Anticipated Pressure (see 20 AAC 25.035) , Kickoff depth: .,290 ft. Maximum Hole Angle: 92° Max. Downhole Pressure: 3236 psig /Max. Surface Pressure: 2530 psig 18. Casing Program Setting Depth Quantity of Cement Size S ecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 12.25" 9.625" 36# J-55 BTC 2345' 37' 37' 2382' 2378' 365 sx AS Lite & 245 sx LiteCrete 8.5" 7" 26# L-80 BTC-M 8147' 37' 37' 8184' 7187' 6.125" 4.5" 12.6# L-80 EUE-M 7880' 32' 32' 7912' 7138' 151 sx, additional 137 sx Class G Uncemented 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Structural Conductor .Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): None None 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. JOhnson2.Kuenzler @ 265-6081/1308 Printed Name C. Alvord Title Alpine Drilling Team Leader Signature ~~~,p Phone ~,~-_~ IZp Date 2~4~p~ Commission Use Only Permit to Drill API Number: Permit Approval See cover letter //~~ f~] Number: ~V~~ ~ / [ 50- f~ "' Zd ~ " d ~ Date: for other requirements Conditions of approval : Samples required ^ Yes ~No Mud log required ^ Yes ~ No o Directional survey required Yes ^ No ^ Yes ~ N ur es Hydro en sulfide meas g \ p~ Cc~- /~ / p~ ^ (~ ~ c ~Q~Y..~l'~ ~Q,7~ Y, T~9~~C[.: ~ at ~t~.rdv a ~~V `Gl) . t 7Ci~ C~®~C~~`~~c„(`2W~C3®~ n~C ~ + ~ ~"~c3~ ~ Other: ~~ rte ~~v~ra ~~ "~`` ~ ~ .`~ { ( } t ^ ~ h ., ' Z ~<iC9AS `t a~ C. CCGc V W l ~- ~. ~] ~ tJ ~ i ~~ J BY ORDER OF Ap ved b : ~~ COMMISSIONER THE COMMISSION Date: (i ~ D Form 10- vis 6/2004 ORIGINAL I Su mit in Duplicate s • CD2-17A Drilling 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) 12-1 /4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots as re uired Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increase mud weight Surface Formations >2000' TVD Lost Circulation Low Reduce pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-1 /2" Hole / 7" Casin Interval Event Risk Level Miti ation Strate Abnormal Pressure in Low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir Low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers i ~ ~ ~ v rd ~. .~~ ~ L O ~ s.-K ~I`- COCQ `C b ~ r ~ ~ ORIGINAL Alpine : CD2-17A Procedure Procedure 1. Pre-rig work will include removal of the injection valve @ 1999' MD, and the dummy valve @ 7426' MD. Tubing above the packer will also be cut prior to moving the rig over the well. 2. Move on Doyon 19 3. NU and test BOP 4. MU landing jt. and pull 4-1/2" tubing (evaluate condition of tubing for re-use}. 5. PU miffing/fishing assembly 6. RI, circulate drilling/milling fluid, mill and spear packer, POOH 7. PU 6-118" drilling assembly, circ and clean hole with drilling assembly 8. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). ~ 9. Circulate the hole clean and pull out of hole, displacing the well to 9.2 ppg brine. 10. Run 4-'/2, 12.6#, L-80 tubing with DB nipple, gas lift mandrels}, and packer. Land hanger. 11. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 12. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 13. Circulate tubing to diesel and install freeze protection in the annulus. 14. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 15. Set BPV and secure well. Move rig off. oRiciNa~ • Well Proximity Risks: • Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-06 will be the closest well to CD2-17A. Well separation is 293.8' @ 11785' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 131.2 @ 11785' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. `~ Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. 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. Annular Pumping Operations: Incidental fluids developed from drilling operations on well C 2-17A will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-17A surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. Upon completion of CD2-17A form 10-403, Application for Sundry Operations,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 - 1081 = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppg Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL • CD2-17A DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12 '/4" Intermediate hole to 7" casing point - 8 %2" Production Hole Section - 6 1/8" Density 9.0-9.6 ppg PV 10 -15 YP 25 -30 Funnel Viscosity Initial Gels 10-15 10 minute gels Previously drilled Previously drilled and 12-20 API Filtrate and cemented cemented NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 9.0-9.5 KCL 6% Oil /water ratio Surface Hole: Previously drilled and cemented. Intermediate Hole Section: Previously drilled and cemented. The horizontal production interval will be drilled with an M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PP6 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. OR161NAL • • Colville River Field CD2-17A Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812" ID) Al Injection Valve (2.125"ID) - to <;' j at 2000' TVD = 1996' MD be installed later l 9-5/8" 36 ppf J-55 BTC ~! Surface Casing @ 2382' MD / 2378' TVD cemented to surface Packer Fluid mix: 9.6 ppa KCI Brine with 2000' TVD diesel cap Tubina Suoended with 4-1/2" 12.6 ppf L-80 IBT Mod. tubing run with Jet lube pipe dope diesel Com len lion ~ ~ Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 2000' 1996' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7426' 6880' 4-1l2" tubing joint (2) R3 S3 Packer (c/w handling pups) 7541' 6978' 4-1/2" tubing joint (2) R3 HES "XN" (3.725" ID) - 58.5° 7651' 7022' 4-1/2" 10' pup joint WEG - 72.5° 7912' 7138' Camco KBG-2 GLM (3.909" ID) & 1"dummy valve ETOC @ +/- 7743 MD S3 Packer at +/- 7541' MD (6978 rvD) j Current TD at 8757' MD / 7191' TVD Top Alpine Cat 7987' MD 17159' TVD 7" 26 ppf L-80 BTC Mod ~~ Production Casing @ 8184' MD / 7187' TVD @ 88° ~'~~~~ S PQ~`~~ Well TD at 11809' MD / 7152' TVD ! ~' ORIGINAL i ~ CD2-17A PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD ft Fracture Gradient (Ibs. / al Pore pressure (psi) ASP Drilling (psi) 16 N/A N/A N/A N/A 9 5/8 N/A N/A N/A N/A 7" 8184 / 7178 16.0 3248 2530 N/A 11809 / 7152 16.0 3236 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1}D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psilft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3248 - (0.1 x 7178') = 2530 psi ~ 2. Drilling to TD = 3236 - (0.1 x 7152') = 2521 psi ORIGINAL • ~ 9 5/8" Surface Casing run to 2382' MD / 2378' TVD, 9-5/8" casing was cemented with 51 bbls/245 sacks of Class G and 289 bbls/365 sacks of ASLite. The job was completed with full returns and 87 bbls of cement returned to surface. 7" Intermediate Casin run to 8184' MD / 7178' TVD t Q) 7" casing was cemented with 31 bbls/151 sacks of 15.6 ppg class G, with minimal returns. CD2-17~was subsequently squeezed with an additional 28 bbls/137 sacks of 15.8 ppg class G and TOC was estimated @ 7743' MD. A CBL was run on CD2-17; results of the log found the well suitable for injection. ORIGINAL • • ConocoPhif lips ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-17 Plan: CD2-17 A Plan: CD2-17 A (wp01) Standard Planning Report 03 February, 2005 ORIGINAL "1VAIAi'11~ ~ r. sa~f~a~s ~roi"~-r~ac7 uT~~"~l~It..IC~~S ~KZd 1~~tlLL-Za3 96£'96ZS 40~ZZ OL'0 £00'6SZ- 666'6£ZS 000'ZS6L Ol£'£££ LZL'Z6 LZL'BOBIL Z 06£'89tiZ 00'0 00'0 4LZ'8£lL Sl9'LZSZ 4Z9'O6LL. 08L'ZE£ OE£'68 000'LSLB a ~aFuel SSA eoe~L 6a'10 Mf3~ SIN+ OAl !rf~W aNi ~S SlM13O N011~3S 1_ ti ~u!~ 008) ~+)lsa3/~-)~saM OOZE 0082 OObZ OOOZ 009E OOZE 008 004 OOtr- 008- OOZE- 009L- 000Z- . ' ~ ~ . , - . .~ ~..,..mN ,...... . ,gym . .~~........ ~,. ... ~...... . ~ ,. , .~, .,, ... . „ I I n 3 i " OOtr j f O7 t ~ 008 ~ s ( m S ~ 3 ~ .. m OOZL a € E I ° i _ _ _ i _..___ p 009E ( _ ----- - ~ ~ rn - --- - x OOOZ I , p cO _ c O OObZ [ a~oH ua d0..8/L 9 T ~ ' ' ~ z r o c ' „ yo ..~ 008Z~ ' ~ m QAJ. ~34Z9'086L`Q1N 7d000'LSLB ~S"IQ 00'0 6uuaaLso~~ ur6a 8 x ,i m ~ OOZE ~ m .~ < ~ ~ ~ .. .-. ~ o ~ ~ f z 009E ~ A _- . . m .. ~ OOOb € ! OObb ._ ~ Uetib j ~ ~ Lip ~,a ae1 0084 ~y.,, 34~°NZLL°S£'~aS'"133~3L6L1°7N-i~SLLt~Q1lLi~Q6'Z>!L`C7L3OZL`8#18LL°d'1"~}t~1 ~ } • - - ,h,a - ~ -_ - ooze _ a~oH uad0 8/L 9-~ (aol) VLL- Z0~ ,~ 4~oN ~apu!~(~ 'ne~l :poy~aW Bwu.aeM t ~ pase8 sa~n21 :aoe}anS aa~3 l®'" - ' 'ik ! ' 1= ' ~ o o eo - !u ~ l !~ !III :poy~aW ueoS ~60~) td L6-Z{]3 :uetd :uel tfSM~SI :uaa}s~tg ~oa~~ '~16~Z®~,ue1d :aaagE3a,~ta aan~eiun~ wnua!wW .poylaW uo!~elno~e~ ~~~~ ~~~~~~~ ll"-ZfI~ :ueld allaM Id . auid Zt3~ sdyy :a~18 II r. Project: Colv(lte `ver Unit ,. ~rr Site; spine G1~2 Welt: Ptan: CC12-17 ~~~~ ~ ~ 1 ~ Alpine _ Error System: Minimum Curvature ~, Wel(bore; Ptan: CD2-'t? A Plan: Plan: CL32-17 A (wp0~} Calculation Method: ISCWSA Scan Method: Trav. Cylinder North a LpT~~'i Error Surface: Elliptical Conic ~,l;~'~ G,,I~~ SECTION DETAILS Sec MD Inc Azi TVD +N/S +EI-W DLeg TFace VSec Target 1 8757.000 89.330 332.180 7190.624 2527.815 1138.274 0.00 0.00 2468.340 2 11808.727 92.121 333.310 7152.000 5239.999 •259.003: 0.10 22.04 5246.396 CD2-17A (Tce) I , 750 ., i I i '. _ _ ~ _ _ _ ~ _ _ _. _ _._... _~ _ _ _.__.. ._~ _ - sperry-sun '..,' I ORiL_LIN G... SERVICES '.. •r/ 1500 ...... ._.. _.... _.. _ _ _ ..... _ _ 1 N '+er 2250 '~ _ , ~ V J i '~"" ~ 3000 i _ ',. ', _ t -. t ' a t i p~•~+~1r f ~ 3750 t 1 _ , m v i I } N ~ 4500 ,t -«-- ~ _ ~ _ , . ~ ,, 7" Csg Pt . Begin 6 1/8" hole. 8184.000ft MD. 7177 586ft TVD -- 4992 ft FNL & 131 ft FEL Sec35 T12N R4E H - - -- - - -- - - - - - - - ~ '' 5250 , - _ _ _ _ _ _ ._ 'y _ _ , ' _ _ i F _ ' ` ~ t ,~ `t v _ _ - ' ~~,, ~~ CD2-17A (Toe) i ' ~, ~~ 6000 _ ,, _ 1 i ~ ~ ~i ~ 6 1/8 Open Hole ~ > i : i ~ ~ ~ - I c A ~i ,' ~ i { I' ~ 6750 _ _ _ ~, ,_ _ i .~ ,- ' ' ~ ~ i ~ ! , A ~~ ~~ _ 3 I '- 7500 i 3 ~ 6 118" Open Hole I _ -1 ~Y - I Begin Geosteering cz OAO aLS: 8757.p00ft MD,7190.624ft 7VD _ ' -4500 -3750 -3000 -2250 -1500 -750 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 awn' • SPERRY SUN HES ~~"'~(~~(~~~~~~~ Planning Report Database: EDM 2003.1.1 Single User Db Local Co-ordinate Reference: Compan}: ConocoPhillips Alaska Inc. (Alpine) TVD Reference: Project: Colville River Unit MD Reference: Site: Alpine CD2 North Reference: Well: Plan:. CD2-17 Survey Calculation Method: Wellbore: Plan: CD2-17 A Design: Plan: CD2-17 A (wp01) Well Plan. CD2-17 CD2-17 @ 52.430ft (CD2-17:) CD2-17: @ 52.430ft (CD2-17:) True Minimum Curvature Project Colville RFver Unit, iJoiih Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site - - -Alpine CD2 - - - - - - - - _ i Site Position: Northing: 5,974,641.660ft Latitude: 70° 20' 20.225" N From: Map Easting: 371,696.240ft Longitude: 151° 02' 28.083" W Position Uncertainty: 0.000 ft Slot Radius: 0" Grid Convergence: -0 98 ' I Well Plan: CD2-17, 501032040600 ~ t i Well Position +N/-S 0.000 ft Northing: 5,974,622.100 ft ° Latitude: 70° 20' 20.033" N +E/-W 0.000 ft Easting: 371,698.480 ft ° Longitude: 151° 02' 28.008" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 0.000 ft Wellbore i Plan: CD2-17 A i Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) i l BGGM2004 12/6/2004 23.76 80.60 57,515 Design Plan: CD2-17 A (wp01) Audit Notes: Version: Phase: PLAN Tie On Depth: 8,757.000 Vertical Section : De pth From (TVD) +N/-S +E/-W Direction Ift) (ft) (ft) (°) L 36.530 0.000 0.000 357.'170 i Plan Sections _- __-. - - i I Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft; (°) (°) (ft) (ft) (ft) (°1100ft) (°I100ft) (°It00ft) (°) Target 8,757.000 89.330 332.180 7,190.624 2,527.615 1,138.274 0.00 0.00 0.00 0.00 11,808.727 92.121 333.310 7,152.000 5,239.999 -259.003 0.10 0.09 0.04 22.04 CD2-17A(Toe) 2/3/2005 9:44:44AM Page 2 of 5 COMPASS 2003.11 Bur/d 50 SPERRY SUN HES ~~~~(~~~''~~~~~ _ Planning Report Database: EDM 2003.11 Si ngle User Db Local Co-ordinate Reference: Well Plan : CD2-17 Company: ConocpPhillips Alaska Inc. (Alp ine) TVD Reference: CD2-17: @ 52.430ft (C D2-1'7:) Project: Colville River Un it MD Reference: CG2-17: @ 52 430ft (CD2-17:) Site: Alpine CD2' North Reference: True Well: Plan; CD2-17 Survey Calculatio n Method: Minimum' Curvature Wellbore: Plan: CD2-17 A Design: Plan CD2-1TA (wp01) Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (~) (^) (ft) (1t) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) 100.000 0.000 0.000 100.000 0.000 0.000 0.000 0.00 0.00 0.00 200.000 0.395 43.100 199.999 0.216 0.203 0.206 0.40 0.40 0.00 300.000 0.591 51.702 299.995 0.820 0.858 0.776 0.21 0.20 8.60 i 400.000 0.871 90.432 399.988 1.153 2.011 1.052 0.55 0.28 38.73 500.000 1.255 101.907 499.969 0.827 3.876 0.635 0.44 0.38 11.47 600.000 1.371 84.349 599.944 0.798 6.105 0.495 0.42 0.12 -17.56 700.000 1.547 86.181 699.910 1.034 8.707 0.603 0.18 0.18 1.83 800.000 2.325 80.388 799.864 1.270 11.689 0.692 0.80 0.78 -5.79 900.000 4.797 76.406 899.679 2.601 17.483 1.735 2.48 2.47 -3.98 1,000.000 6.473 79.370 999.151 4.831 27.473 3.468 1.70 1.68 2.96 1,100.000 6.784 81.317 1,098.462 6.724 39.033 4.789 0.38 0.31 1.95 1,200.000 6.562 81.901 1,197.778 8.419 50.583 5.912 0.23 -0.22 0.58 i 1,300.000 5.694 68.734 1,297.199 10.805 61.020 7.780 1.65 -0.87 -13.17 1,400.000 4.253 40.387 1,396.821 15.466 68.197 12.081 2.81 -1.44 -28.35 1,500.000 1.793 30.452 1,496.666 19.885 71.314 16.341 2.51 -2.46 -9.93 1,600.000 0.633 28.549 1,596.644 21.671 72.317 18.075 1.16 -1.16 -1.90 1,700.000 0.668 19.846 1,696.637 22.708 72.775 19.087 0.10 0.03 -8.70 1,800.000 0.626 19.445 1,796.631 23.770 73.157 20.129 0.04 -0.04 -0.40 1,900.000 0.618 17.110 1,896.625 24.778 73.482 21.120 0.03 -0.01 -2.34 2,000.000 0.631 26.125 1,996.618 25.923 73.881 22.244 0.10 0.01 9.02 2,100.000 0.343 117.991 2,096.615 26.223 74.441 22.516 0.73 -0.29 91.87 ~ 2,200.000 0.446 167.386 2,196.612 25.577 74.781 21.854 0.34 0.10 49.40 2,300.000 0.201 169.863 2,296.611 25.015 74.836 21.290 0.25 -0.25 2.48 2,400.000 i 0.266 143.675 2,396.610 24.752 75.012 21.019 0.12 0.07 -26.19 2,500.000 0.250 161.389 2,496.609 24.301 75.280 20.555 0.08 -0.02 17.71 2,600.000 1.402 77.055 2,596.602 24.234 76.115 20.446 1.40 1.15 -84.33 2,700.000 4.377 73.810 2,696.473 25.541 80.771 21.523 2.98 2.97 -3.24 2,800.000 7.322 74.874 2,795.934 28.326 90.653 23.816 2.95 2.95 1.06 2,900.000 9.085 70.425 2,894.881 32.541 104.466 27.344 1.87 1.76 -4.45 3,000.000 10.386 66.299 2,993.434 38.828 120.189 32.848 1.48 1.30 -4.13 3,100.000 12.350 67.455 3,091.480 46.603 138.233 39.722 1.98 1.96 1.16 3,200.000 14.685 68.540 3,188.706 55.334 159.896 47.373 2.35 2.34 1.09 3,300.000 17.564 68.916 3,284.764 65.390 185.775 56.139 2.88 2.88 0.38 3,400.000 20.479 68.456 3,379.296 77.268 216.113 66.505 2.92 2.92 -0.46 3,500.000 23.564 69.035 3,471.997 90.789 251.062 78.284 3.09 3.08 0.58 3,600.000 26.544 68.154 3,562.481 106.316 290.672 91.837 3.00 2.98 -0.88 3,700.000 i 27.636 67.154 3,651.426 123.715 332.929 107.129 1.18 1.09 -1.00 3,800.000 27.764 67.072 3,739.995 141.959 375.622 123.242 0.13 0.13 -0.08 3,900.000 28.044 68.400 3,828.318 159.541 419.092 138.657 0.68 0.28 1.33 4,000.000 i 27.903 67.866 3,916.642 176.970 462.625 153.915 0.29 -0.14 -0.53 4,100.000 27.830 67.193 4,005.049 194.870 505.796 169.663 0.32 -0.07 -0.67 4,200.000 27.956 65.815 4,093.473 213.277 548.717 185.928 0.66 0.13 -1.38 4,300.000 27.969 63.068 4,181.715 233.565 591.159 204.097 1.29 0.01 -2.75 4,400.000 28.314 59.290 4,270.046 255.998 632.311 224.470 1.81 0.34 -3.78 4,500.000 29.144 54.449 4,357.681 282.278 672.659 248.726 2.47 0.83 -4.84 4,600.000 29.115 49.887 4,444.918 312.309 711.215 276.817 2.22 -0.03 -4.56 4,700.000 28.948 47.550 4,532.391 344.494 747.440 307.175 1.15 -0.17 -2.34 4,800.000 29.101 47.475 4,619.855 377.351 783.083 338.232 0.16 0.15 -0.08 4,900.000 29.261 47.388 4,707.156 410.300 819.040 369.366 0.17 0.16 -0.09 5,000.000 29.265 47.503 4,794.383 443.399 855.040 400.647 0.06 0.00 0.11 5,100.000 29.320 46.874 4,881.602 476.596 890.966 432.030 0.31 0.05 -0.63 5,200.000 29.548 46.479 4,968.703 510.320 926.690 463.949 0.30 0.23 -0.40 I 5,300.000 29.580 45.838 5,055.676 544.497 962.294 496.327 0.32 0.03 -0.64 5,400.000 29.400 45.370 5,142.717 578.943 997.469 528.995 0.29 -0.18 -0.47 2/3/2005 9:44:44AM Page 3 of 5 COMPASS 2003.11 Buifd 50 L Database: EDM 2003.11 Single UserDb Company: ConocoPhillips Alaska lnc. (Alpine) Project: Colville River Unit Site: Alpine CD2 Well: Plan; CD2-17 Wellbore: Plan: CD2-17 A Design: Plan: CD2-17 A (wp01) Planned Survey Well Plan: CD2-17 CD2-17; @ 52.430ft (CD2-17:) CD2-177: @ 52s430ft (CD2-17:) True Minimum Curvature Vertical Section (ft) 562.018 595.185 627.300 658.612 689.898 721.328 753.123 785.234 817.465 850.028 882.808 915.389 947.971 979.957 1, 012.407 1, 049.700 1, 095.894 1,148.617 1,208.882 1,275.010 1, 345.331 1,421.979 1, 506.261 1, 595.484 1, 686.704 1, 779.903 1,874.057 1, 951.379 1,965.946 2, 056.219 2,145.922 2,235.706 2,326.048 2,416.680 2,468.340 2,507.314 2, 597.973 2,688.660 2,779.375 2, 870.119 2,960.890 3, 051.689 3,142.515 3,233.368 3,324.248 3, 415.155 3, 506.087 3,597.046 3,688.030 3,779.039 3,870.074 Dogleg Build Turn Rate Rate Rate 0.41 0.03 -0.84 0.40 -0.40 -0.07 0.88 -0.60 1.34 0.14 -0.07 0.27 0.18 0.18 0.10 0.21 -0.04 -0.42 0.26 0.07 -0.53 0.26 -0.10 -0.50 023 -0.08 -0.45 0.28 0.00 -0.58 0.24 -0.20 -0.27 0.38 -0.30 -0.50 0.60 -0.58 -0.37 0.38 -0.37 -0.22 0.86 0.38 -1.69 6.36 3.74 -10.58 3.69 2.73 -4.63 6.01 3.04 -8.98 6.68 3.17 -9.48 6.01. 3.08 -7.80 6.53 4.13 -7.14 6.81 6.81 -0.17 8.03 7.79 -2.28 4.79 4.46 -1.96 6.97 5.53 -4.54 7.69 7.30 -2.50 7.93 6.97 -3.81 5.27 2.71 -4.53 2.62 1.62 -2.07 1.73 -0.34 -1.69 0.14 0.04 0.13 0.22 -0.02 0.22 1.39 1.05 0.91 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0.04 0.10 0.09 0:04 0.10 0.09 0.04 0.10 0.09 0.04 2/3/2005 9:44:44AM SPERRY_SUN HES Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Depth Inclination Azimuth Depth +N/-S +EI-W (ft) (°) (°) (ft! (ft) (ftl 5,500. 000 29. 433 44. 529 5,229. 816 613. 722 1,032 .168 5,600. 000 29. 033 44. 456 5,317. 068 648. 620 1,066 .362 5,700. 000 28. 429 45. 799 5,404. 784 682. 457 1,100 .432 5,800. 000 28. 362 46. 068 5,492. 780 715. 495 1,134 .567 5,900. 000 28. 538 46. 164 5,580. 677 748. 519 1,168 .968 6,000. 000 28. 501 45 .740 5,668. 560 781. 683 1,203 .273 6,100. 000 28. 573 45 .207 5,756. 398 815. 202 1,237 .346 6,200. 000 28. 469 44 .706 5,844. 240 849 .021 1,271 .110 6,300. 000 28. 384 44. 253 5,932. 224 882. 937 1,304 .405 6,400. 000 28. 384 43. 670 6,020. 166 917. 174 1,337 .479 6,500. 000 28. 185 43 .400 6,108. 224 951 .604 1,370 .041 6,600. 000 27. 884 42 .897 6,196. 474 985 .820 1,402 .311 6,700. 000 27. 306 42 .524 6,285. 064 1,019 .992 1,433 .679 6,800. 000 26. 938 42. 304 6,374. 119 1,053. 535 1,464 .402 6,900. 000 27. 320 40 .616 6,463. 182 1,087. 519 1,494 .613 7,000. 000 31. 058 30 .039 6,550. 807 1,126 .261 1,523 .030 7,100. 000 33. 787 25 .404 6,635. 199 1,173 .743 1,547 .949 7,200. 000 36. 830 16 .426 6,716. 782 1,227 .566 1,568 .882 7,300. 000 40. 002 6 .944 6,795. 051 1,288 .507 1,581 .076 7,400. 000 43. 079 359. 145 6,569. 656 1,354 .909 1,585 .003 7,500. 000 47. 211 352 .006 6,940. 629 1,425 .016 1,578 .936 7,600. 000 54. 017 351 .837 7,004. 296 1,501 .186 1,567 .374 7,700. 000 61. 809 349 .559 7,057. 131 1,584 .900 1,553 .786 7,800. 000 66. 265 347. 602 7,100. 247 1,673 .360 1,536 .156 7,900. 000 71. 795 343 .064 7,136. 247 1,763 .519 1,512 .437 8,000. 000 79. 098 340 .560 7,161. 563 1,855 .338 1,482 .195 8,100. 000 86. 070 336 .754 7,173. 933 1,947 .844 1,446 .523 8,184. 000 88. 346 332 .949 7,177. 586 2,023 .464 1,410 .187 7..: 8,200. 000 88. 605 332 .619 7,178. 012 2,037 .687 1,402 .872 8, 300. 000 88. 262 330 .925 7,180. 742 2,125 .731 1, 355 .543 8,400. 000 88. 300 331 .056 7,183. 722 2,213 .148 1,307 .073 8,500. 000 88. 276 331 .272 7,186. 865 2,300 .653 1,258 .773 8,600. 000 89. 330 332 .180 7,188 .788 2,388 .771 1,211 .540 8,700. 000 89. 330 332 .180 7,189. 958 2,477 .207 1,164 .874 8, 757. 000 89. 330 332 .180 7,190. 624 2,527 .615 1,138 .274 Begin Geosteering @ 0.00 DLS: 8757 ,OOOft MD,7190. 624ft TVp - 6 1 J8" Open Hole 8,800. 000 89. 369 332 .196 7,191 .112 2,565 .646 1,118 .212 8,900. 000 89. 461 332 .233 7,192 .133 2,654 .111 1,071 .599 9,000. 000 89. 552 332 .270 7,192 .994 2,742 .608 1,025 .041 9,100. 000 89. 644 332 .307 7,193. 696 2, 831 .135 978 .540 9,200. 000 89. 735 332 .344 7,194 .238 2,919 .694 932 .096 9,300. 000 89. 826 332 .381 7,194 .621 3,008 .284 885 .709 9,400. 000 89. 918 332 .418 7,194 .844 3,096 .903 839 .379 9,500. 000 90. 009 332 .455 7,194 .907 3,185 .553 793 .106 9,600. 000 90. 101 332 .492 7,194 .811 3,274 .233 746 .890 9,700. 000 90. 192 332 .529 7,194 .555 3,362 .942 700 .732 9,800. 000 90. 284 332 .566 7,194 .140 3,451 .681 654 .631 9,900. 000 90. 375 332 .603 7,193 .565 3,540 .449 608 .588 10,000 .000 90. 467 332 .640 7,192 .830 3,629 .245 562 .603 10,100. 000 90. 558 332 .677 7,191 .936 3,718 .070 516 .676 10,200. 000 90. 649 332 .714 7,190 .883 3,806 .924 470 .807 10,300 .000 90 .741 332 .751 7,189 .669 3,895 .805 424 .996 Page 4 of 5 ORIGINAL COMPASS 2003.19 Build 50 • SPERRY SUN HES ~~~~"'~~~~~~ _ Planning R eport Database: EDM 2003. T9 Single User Db Loc al Co-ordinate R eference: Well Plan: CD2-17 Company: ConocoPhillips Alaska Inc. (Alpine) TVD Reference: CD2-17: @ 52`430ft (CD2-17:) Project: Colville River Unit MD Reference: CD2-17: @ 52.430ft (CD2-1 T) Site: Alpine CD2 No rth Reference: True Well: Plan: CD2-17 Su rvey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-17A Design: Plan: CD2-17 A (wp01) Planned Survey i Measured Vertical Vertical Dogleg Build Turn i Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate ~ (ft) (') (°) (ft) (ft) (ft) (ft) (°/100ft) (°l100ft) (°/100ft) i 10,400.000 90.832 332.788 7,188.296 3,984.714 379.244 3,961.133 0.10 0.09 0.04 10,500.000 90.924 332.825 7,186.764 4,073.651 333.550 4,052.217 0.10 0.09 0.04 10,600.000 91.015 332.862 7,185.072 4,162.615 287.915 4,143.325 0.10 0.09 0.04 10,700.000 91.107 332.899 7,183.220 4,251.605 242.338 4,234.458 0.10 0.09 0.04 10,800.000 91.198 332.936 7,181.209 4,340.623 196.821 4,325.614 0.10 0.09 0.04 10,900.000 91.290 332.973 7,179.038 4,429.667 151.362 4,416.793 0.10 0.09 0.04 11,000.000 91.381 333.010 7,176.708 4,518.737 105.963 4,507.996 0.10 0.09 0.04 11,100.000 91.472 333.047 7,174.218 4,607.833 60.623 4,599.222 0.10 0.09 0.04 11,200.000 91.564 333.084 7,171.569 4,696.954 15.342 4,690.470 0.10 0.09 0.04 .11,300.000 91.655 333.121 7,168.760 4,786.101 -29.879 4,781.740 0.10 0.09 0.04 11,400.000 91.747 333.159 7,165.791 4,875.273 -75.040 4,873.033 0.10 0.09 0.04 11,500.000 91.838 333.196 7,162.663 4,964.470 -120.141 4,964.348 0.10 0.09 0.04 11,600.000 91.930 333.233 7,159.376 5,053.691 -165.183 5,055.684 0.10 0.09 0.04 11,700.000 92.021 333.270 7,155.929 5,142.937 -210.164 5,147.042 0.10 0.09 0.04 .11,800.000 92.113 333.307 7,152.322 5,232.207 -255.085 5,238.420 0.10 0.09 0.04 11,808.727 92.121 333.310 7,152.000 5,239.999 -259.003 5,246.396 0.10 0.09 0.04 TD (BHL)-1 1808.720 ft MD, 7152.000 ft TVD; 1775ft FNL & 1797ft FEL, Sec35-T12N-R4E - 6 118" Open Hofe - GD2-17A (Toe) ' Targets - _- - _ __ I Target Name I - hitJmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) ft ft (ft) (ft) Latitude Longitude CD2-17A (Toe) 0.00 0.00 7, 152.000 5,240.000 -259.000 5,979,865. 338 371,529.194 70° 21' 11.568" N 151° 02' 35.578" W - Point I Casing Points _ - - _ _ _ _ Measured Vertical Casing Hole Depth Depth Name Diameter Diameter i (ftl (ft) f") (") 8,184.000 %,177.586 7" 7 8-1/2 8,756.900 7,190.623 6 1/8" Open Hole 6-1/8 6-1/8 11,808.700 7,152.001 6 1/8" Open Hole 6-1/8 6-1/S Plan Annotations Measured Vertical Local Coordi nates ~ Depth Depth +N/-S +E/-W Comment ~ i (ft) (ft) (ft) (ft) 8, 757.000 7,190.624 2,527.615 1,138.274 Begin Geosteering @ 0.00 DLS: 8757.OOOft MD,7190.624ft TVD 11,808.720 7,152.000 5,239.992 -259.000 TD (BHL)-1 1808.720 ft MD, 7152.000 ft TVD; 1775ft FN L & 1797ft FEL, Sec35- 2/3J2005 9:44:44AM Page 5 of 5 COMPASS 2003.11 Budd 50 ~~~ • • Con~oPhillips ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine CD2 Plan: CD2-17 Plan: CD2-17 A Plan: CD2-17 A (wp01) Travelling Cylinder Report 03 February, 2005 ORIGINAL Cor~ocoP~rl1~ Company: ConocoPhillips Alaska Inc..{Alpine) Project: Colville River Unif Reference Site: Alpine CD2 Site Error: O.000ft Reference Well: Plarr. CD2-17 Well Error: O.000ft Reference Wellbore Plan: CD2-17 A Reference Design: Plan: CD2-17 A (wp01) SPERRY_SUN HES Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • Well Plan: CD2-17 CD2-17: @ 52.430ft (CD2-17:) CD2;-17: @ 52:430ft (CD2-17:) True Minimum Curvature 1.OO sigma EDM 2003:11'Single User Db Offset Datum Reference Plan: CD2-17 A (wp01 j Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 100.OOOft Error Model: ISCWSA Depth Range: 8,757.000 to 11,808.727ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,377,219ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 2/312005 ~ From To (ft) (ft) Survey (Wellbore) Tool Name Description 114.000 8,757.000 CD2-17 (CD2-17) MW D MW D -Standard 8,757.000 11,808.727 Plan: CD2-17 A (wp01) (Plan: CD2-17 A) MW D MW D -Standard CC -Min centre to center distance or covergent point. SF -min separation factor, ES -min ellipse separation 213/2005 9:43:34AM Page 2 of 7 COMPASS 2003.11 Build 50 ORIGINAL Company: ConocoPhillips Alaska Inc. (Alpine Project: Colville River Unit Reference Site: Alpine CD2 Site Error: O.000ft Reference Well: Plan: CD2-17 Well Error: O.000ft Reference Wellbore Plan: CD2-17A Reference Design: Plan: CD2-17 A (wp01) • SPERRY_SUN HES Anticoilision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Summary Site Name Offset Well -Wellbore -Design Alpine CD2 CD2-01 -Plan: CD2-01 -Plan: CD2-01 (wp01) CD2-05 -Plan: CD2-05 -CD2-05 (Rig Surveys) CD2-O6 -CD2-06 -CD2-06 CD2-07 -CD2-07 -CD2-07 CD2-07 -CD2-07P61 -CD2-07PB1 CD2-07 -CD2-07P62 -CD2-07PB2 CD2-08 -CD2-O8 -CD2-08 CD2-09 -Plan: CD2-09 -CD2-09 (Rig Surveys} CD2-10 -CD2-10 -CD2-10 CD2-10 -CD2-10P61 -CD2-10P61 CD2-12 -CD2-12 -CD2-12 CD2-13 -CD2-13 -CD2-13 CD2-13 -CD2-13PB1 -CD2-13PB1 CD2-13 -CD2-13PB2 -CD2-13P62 CD2-14 -CD2-14 -CD2-14 CD2-15 -CD2-15 -CD2-15 CD2-15 -CD2-15P61 -CD2-15PB1 CD2-15 -CD2-15P62 -CD2-15P62 CD2-16 -CD2-16 -CD2-16 CD2-16 -CD2-16 (Sag) -CD2-16 (Sag) CD2-18 -CD2-18 -CD2-18 CD2-20 -CD2-20 -CD2-20 CD2-22 -CD2-22 -CD2-22 CD2-23 -CD2-23 -CD2-23 CD2-23 -CD2-23P61 -CD2-23PB1 CD2-24 -CD2-24 -CD2-24 CD2-24 -CD2-24PB1 -CD2-24P61 CD2-25 -CD2-25 -CD2-25 CD2-28 -CD2-28 -CD2-28 CD2-30 -CD2-30 -CD2-30 CD2-31 -CD2-31 -CD2-31 CD2-31 -CD2-31 PB1 -CD2-31 P61 CD2-32 -CD2-32 -CD2-32 CD2-33 -CD2-33 -CD2-33 CD2-33 -CD2-33B -CD2-336 Plan: CD2-03 -Plan: CD2-03 -Plan: CD2-03 (wp02 Plan: CD2-04 -Plan: CD2-04 -Plan: CD2-04 (wp02 Plan: CD2-11 -Plan: CD2-11 -Plan: CD2-11 (wp06 Plan: CD2-17 -CD2-17 -CD2-17 Plan: CD2-21 -CD2-21 (Rig Surveys) -CD2-21 (Rig Plan: CD2-21 -CD2-21 PB1 (Rig Surveys) -CD2-21 Plan: CD2-21 -Plan CD2-21 PB1 -Plan CD2-21 PB Plan: CD2-21 -Plan CD2-21 PB1 -Plan: CD2-21 PB Plan: CD2-21 -Plan: CD2-21 -Plan: CD2-21 (wp06 PIan:CD2-02 -Plan: CD2-02 -Plan: CD2-02 (wp01) Alpine Outlands. Alpine 1 -Alpine 1A -Alpine 1A Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 11,785.069 8,700.000 293.833 8,757.000 8,757.000 0.000 `JVell Plan: GD2-17 CD2-17: @ 52.430ft (CD2-17:) CD2-17: @ 52.430ft,(CD2-17;) True Dflinimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) Out of range Out of range 288.84 131.248 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 67.69 -22.568 FAIL -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range 8,913.255 9,700.000 250.814 28.38 250.302 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/3/2005 9:43:34AM Page 3 of 7 COMPASS 2003.11 Build 50 ORIGINAL ~~1C.~CC~P ~~~~~ Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: ConocoPhillips Alaska inc. (Alpine) Colville River Unit Alpine CD2 O.000ft Plan: CD2-17 0-000ft Plan: CD2-17 A Plan: CD2-17 A (wp01) SPERRY_SUN HES Anticallision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan: CD2-17 CD2-17: @ 52.430ft{CD2-17:) CD2-1 T. @,52.430ft (CD2-17:) True Minimum Curvature 1.00 sigma' EDM 2003:11 Single UserDb Offset. Datum Offset Design Alpine CD2 - CD2-06 -CD2-O6 -CD2-06 onset srte error: aooo a Survey Progra m: 84-CB-GYRO-SS, 303-MWDHFR-AK-CAZ-SC Rule Assigned: Major Risk Offset We{{Error: 0.000 it Reference Offse[ Semi Major Axis reasured Vertical Measured Vertical Reference Offset Toolface + Offse[ Wellbore Cen[re Casing - Cen[re to No Go Allowable Warning Depth DepOr DepUr Depth Azimuth +NI-S *E!-W Hole Size Cen[re Distance Deviation (ft) (ft) (ft) (ft) (ftl fftl ~~) (fti (ft) (f[j (ft) (ft) (fti 11,004.277 7,176.606 7,400.000 5,931.349 69.093 16.437 -46.70 4,293.160 -280.054 0.609 1,323.431 24542 1203.588 Pass-Mapr Risk 11,056.901 7,175.311 7,500.000 6,012.73fi 59.797 16.656 -47.01 4,351.063 -284.850 0.609 1238.193 248.26 1,116.347 Pass-Major Risk 11,110414 7,173.950 7,600.000 6,093.109 60.516 16.881 -47.30 4,410.418 -288.941 0.609 1,153.447 251.17 1,029.611 Pass-Mapr Risk 11,164.976 7,172.515 7,700.000 6,172.477 61.254 17.115 -47.58 4,471.121 -292.875 0.609 1,069.351 254.15 943.480 Pass-Mapr Risk 11,218.214 7,171.069 7,800.000 6,252.940 fi1.979 17.348 -47.99 4,530.342 -297.181 0.609 984.620 257.07 856.341 Pass-Major Risk 11,271.886 7,169.565 7,900.000 6,332.736 62.714 17.581 -48.40 4,590494 -300.832 0.609 900.157 260.02 769400 Pass-Major Risk 11,327.809 7,167.950 8,000.000 6,410.384 63.484 17.827 -48.75 4,653.422 -304.067 0.609 817.044 263.10 683.916 Pass-Major Risk 11,384.543 7,166.260 8,100.000 6,487.12fi 64.269 18.080 -49.11 4,717465 -307.092 0.609 734.485 266.25 598.889 Pass-Major Risk 11,441.920 7,164.499 8,200.000 6,563.433 65.068 18.341 -49.59 4,781.983 -310.833 0.510 652.471 269.35 514.089 Pass-Major Risk 11,501.159 7,162.626 8,300.000 6,638.376 65.897 18.613 -50.22 4,847.993 -315.903 0.510 571.881 272.66 430.085 Pass-Major Risk 11,563.089 7,160.608 8,400.000 6,711.043 66.769 18.904 -50.97 4,916.374 -322.328 0.510 493.397 276.15 347661 Pass-Major Risk 11,629.586 7,158.373 8,500.000 6,779.952 67J10 19.225 -51.99 4,988.148 -332.125 0.510 418.882 279.92 268.147 Pass-Major Risk 11,703.852. 7,155.793 8,600.000 6,840.840 68.766 19.592 -53.13 5,065.987 -346.752 0.510 352.156 284.17 195.706 Pass-Major Risk 11,785.069 7,152.871 8,700.000 6,892.920 69.928 19.998 -54.30 5,149.192 -365.716 0.510 293.833 288.84 131.248 Pass -Major Risk, CC, ES, SF CC -Min centre to center distance or covergent point. SF -min separation factor, ES -min ellipse separation 2/3/2005 9:43:34AM Page 4 of 7 COMPASS 2003.11 Burld 50 ORIGINFlL • Company: ConocoPhillips Alaska Inc. (Alpine) Project: Colville River Unit Reference Site: Alpine CD2 Site Error: O.000ft Reference WeIL• Plan; CD2-17 Well Error: O.000ft Reference Wellbore Plan: CD2-1TA Reference Design: Plant CD2-17 A (wp01) SPERRY_SUN HES Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • Well Plan: CD2-17 CD2-17: @ 52:430ft (CD2-17:) CD2-17: @ 52.430ft (CD2-17:) True Minimum Curvature 1.00 sigma EDM 2003.11`Single User Db Offset Datum Offset Design Alpine CD2 - Plan: CD2-17 -CD2-17 -CD2-17 otfset site error o 00o o I Survey Program: " 1 4 UVJD Rule Assigned: Major Risk Offset Well Error: 0.000 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toollace+ Offset Wellbore Cen[re Casing - Centre [o No Go Allowable Warning Depth Deptli i Dep[h Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ftl (ft) (ft) (ft) f~) (ft) (ft) (ft) (ft) (ft) (ft) fftl Iftl 5,757.006 7,190.624 8,757.000 7,190.624 0.000 35.981 -27.82 2,527-615 1,138274 0.510 0.001] 67.69 -22.Sti6 FAIL-Mapr Posk,CQ ES, SF CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/3/2005 9:43:34AM Page 5 of 7 COMPASS 2003.11 Burld 50 • Company: ConocoPhillips Alaska Inc. (Alpine) Project: Colville River Unit Reference Site: Alpine CD2 Site Error: O.000ft Reference Well: Plan: CD2-17 Well Error: O:000ft Reference Wellbore Plan: CD2-17 A Reference Design: Plan: CD2-17 A (Wp01) SPERRY_SUN HES Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey CalculatiolT Method: Output errors are at Database: Offset TVD Reference: • Well Plan: CD2-17 CD2-17 @ 52.430ft (CD2-17:) CD2-17: @ 52.430ft (CD2-17:) True Minimum Curvature 1.00 sigma' EDM 2003:11 Single User Db Offset Datum Offset Design Alpine Outlands - Alpine 1 -Alpine 1A - Alpine 1A offset sice Error, o 00o tr Survey Program: 14 1-MWD Rule Assigned: Major Risk Ottset Well Error: 0.000 fl Reference Offset Semi Major Axi s Measured Vertical Measured Vertical Reference Offset T oolface+ Oftset Wellbore Centre Casiny- Centre to No Go Allowable Warning I Depth Depth Depth Depth Azimuth +NI-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ftl (ft) (~) (ft) (ft) (R) (ft) (f[) (ft) (ftl Ittl 8,76}.606 i,19G.678 9,500.000 7,050.895 36.040 80.966 -90.34 2,420.488 922.254 0.510 271.697 29.31 271.186 Pass-Mapr Risk 8,837.691 7,191.516 9,600.000 7,116.391 36.633 82.093 -103.95 2,484.658 882.350 0.510 253.779 28.79 253.268 Pass-Major Risk 8,913.255 7,192.256 9,700.000 7,182.379 37.137 83.212 -118.80 2,548.992 843.538 0.510 250.814 28.38 250.302 Pass -Major Risk, CC, ES, SF 8,988.212 7,192.901 9,800.000 7,248.991 37.659 84.323 -133.32 2,614.001 806.980 0.510 262.509 28.30 261.997 Pass-Major Risk 9,023.159 7,193.171 9.846.970 7,280.498 37.910 84.844 -139.54 2,644.192 789.602 0.510 273.805 28.26 273.294 Pass-Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, E5 -min ellipse separation 2/3/2005 9:43:34AM Page 6 of 7 COMPASS 2003.11 Burtd 50 SPERRY SUN HES ~~~"~~~~~ Anticollision Report Company: ConocoPhillipSAlaska Inc. (Alpine) Local Co-ordinate Reference: Project: Colville River Unit TVD Reference: Reference Site: Alpine CD2 MD Reference: Site Error: O.000ft North Reference: Reference Well: Plan: CD2-17 Survey Calculation Method: Well Error: O:000ft Output errors are at Reference Wellbore Plan; CD2-17 A Database: Reference Design: Plan: CD2-17A (wp01') Offset TVD Reference: • Well Plan: CD2-17 CD2-17: @ 52.430ft (CD2-17:) CD2-17: @ 52.430ft (CD2-17:) True Minimum'Curvature 1.OO sigma EDM 2003.1.1 Single User Db Offset batum 2eference Depths are relative to CD2-17: @ 52.430ft (CD2-17:) Coordinates are relative to: Plan: CD2-17 offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 ventral Meridian is -150.00000000 ° Grid Convergence at Surface is: -0.98° Ladder Plot 14 00 - C 1050- 0 ~i ] C O .~ co Q v ~ 7d0- a7 4=1 U 0 m v 350- I Un i CD2-01 (wp t 05 (Rig Suru 2 0 U PB1 5~ 4 2 B9 (Rig Surueys]LQ P B 1 \+'8 PB1 V10 PB2 V4 ® 2 ~3,`C Cb3-24,C I CD2-24,C Z-23'P°B !.-C°C12°-2 2-24,Cd2-24UU 4 2-24PB1I,CD2.24 t ^c~1`2_I _ _ _ - I t B1 V1 I - - - - - - - °, i ~- 1 I CD2'=38 .ICD2~3°$ CD2-39,ICD2.39, 4 CD2.39,ICD2.39 53 CD B1, ), CD -39 V C02- -: 9 CD2-?3,C 2-25,CD2-23 V1 -CD2-40, CD2-40,CD2-40 2000 CD2-26,36,CD2.26'S~001) $00$ ~~2-4B,CD2-a[~~~.CD2- d cD2-2a,cD2-2 ~b~~s~llj~d~p(@t~1~000ftfin} cD2-41,cD2-a1,cD2-a1 CD2-26,CD2.28PB2,CD2.26PB2 V3 CD3-42, CD2.42,C0?-42 CD2-27,CD2-27,CD2-275./8 -~-CD2-42,CD2-42PB1,CD2- 2 CD2-28,CD2-28,CD2-285,33 CD2-43,CD2-43,CD2-43 V 5 • CD2-28,CD2.28PB1,CD2-28PB1 \313 =CD2-43,C02.43PB1,CD2- 3 - CD2-29,CD2-29,CD?-29 V1 -~ CD2-44, CD2-44,CD2-44 V 5 =~~- CD2-30,CD2.30,CD2-3p V31 CD2-48.CD2-48,CD2.48 CD2-31.CD2-31,CD2-31117 ^^ CD2-48,CD2-48,CD?-48 V CD2-31 ,CD2-31 PB1 ,CD2-31 PB1 V4 ~$- CD2-5D, CD2.5d,CD2-50 CD2.32.C02.32,CD2-32VI] -CD2-50,CD2-50PB1, CD2- 0 CD2-32,CD2-32PB1,CD2-32PB15.+B Plan:GD2-03,PIan:CD2-03 P CD2-33,CD2-33,CD2-33 V2 -e.- Plan: CD2-04,PIan:CD2-04 P - Ems--3 3 . ~a4t&3 i><-C Ff3 X3-3-ftsdi , P CC -Min centre to center distance or covergent point. SF -min separation factor, ES -min ellipse separation 2/3/2005 9:43:34AM Page 7 of 7 COMPASS 2003.11 Buitd 50 I I i I I I I I ! l 1 I i i I i i I 4 E i I I I E I I I t I I I I i i I t t k 1 P'. i`:. 1'i,. I'' 1`.'. _ I A I I I i I i I ( s i 3 I I I I t t I I t 7 E I I t I E 4 1 I I I i I I I t 1 I''..r 3 1 I 1 '. I I I ! 3 i I 1 I I I I I I I I I I 7 I i t i I i f ( t I f [ [ I I ! S 1 t 3 I I i 1 1 I t i i I t I ! ~ I a I iLEG E i N D i E i I 1 1 -----I`-- I 1 ~ i ~ I I I 1 J 1}LU I I }'s) ~ 1 • • ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-17 Plan: CD2-17 A Plan: CD2-17 A (wp01) s ~7 ~ 1'1''1- sl.,71"1 GEO Report 03 February, 2005 Local Coordinate Origin: Centered on Well Plan: CD2-17 Viewing Datum: CD2-17: @ 52.430ft (CD2-17:) TVDs to System: N North Reference: True Unit System: API - US Survey Feet e ORIGINAL ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Plan Report for Pian: CD2-17 -Plan: CD2-17 A -Plan: CD2-17 A (wpO1) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) ~°) ~°) eft) eft) eft) eft) eft) eft) (°/100ft) eft) 100.000 0.000 0.000 47.570 100.000 0.000 0.000 5,974,622.100 371,698.480 0.00 0.000 200.000 0.395 43.100 147.569 199.999 0.216 0.203 5,974,622.313 371,698.686 0.40 0.206 300.000 0.591 51.702 247.565 299.995 0.820 0.858 5,974,622.905 371,699.351 0.21 0.776 400.000 0.871 90.432 347.558 399.988 1.153 2.011 5,974,623.218 371,700.511 0.55 1.052 500.000 1.255 101.907 447.539 499.969 0.827 3.876 5,974,622.861 371,702.369 0.44 0.635 600.000 1.371 84.349 547.514 599.944 0.798 6.105 5,974,622.793 371,704.597 0.42 0.495 700.000 1.547 86.181 647.480 699.910 1.034 8.707 5,974,622.985 371,707.202 0.18 0.603 800.000 2.325 80.388 747.434 799.864 1.270 11.689 5,974,623.170 371,710.189 0.80 0.692 900.000 4.797 76.406 847.249 899.679 2.601 17.483 5,974,624.402 371,716.004 2.48 1.735 1,000.000 6.473 79.370 946.721 999.151 4.831 27.473 5,974,626.459 371,726.030 1.70 3.468 1,100.000 6.784 81.317 1,046.032 1,098.462 6.724 39.033 5,974,628.155 371,737.620 0.38 4.789 1,200.000 6.562 81.901 1,145.348 1,197.778 8.419 50.583 5,974,629.652 371,749.195 0.23 5.912 1,300.000 5.694 68.734 1,244.769 1,297.199 10.805 61.020 5,974,631.859 371,759.671 1.65 7.780 1,400.000 4.253 40.387 1,344.391 1,396.821 15.466 68.197 5,974,636.396 371,766.926 2.81 12.081 1,500.000 1.793 30.452 1,444.236 1,496.666 19.885 71.314 5,974,640.761 371,770.118 2.51 16.341 1,600.000 0.633 28.549 1,544.214 1,596.644 21.671 72.317 5,974,642.529 371,771.151 1.16 18.075 1,700.000 0.668 19.846 1,644.207 1,696.637 22.708 72.775 5,974,643.557 371,771.627 0.10 19.087 1,800.000 0.626 19.445 1,744.201 1,796.631 23.770 73.157 5,974,644.613 371,772.027 0.04 20.129 1,900.000 0.618 17.110 1,844.195 1,896.625 24.778 73.482 5,974,645.615 371,772.369 0.03 21.120 2,000.000 0.631 26.125 1,944.188 1,996.618 25.923 73.881 5,974,646.753 371,772.788 0.10 22.244 2,100.000 0.343 117.991 2,044.185 2,096.615 26.223 74.441 5,974,647.043 371,773.352 0.73 22.516 2,200.000 0.446 167.386 2,144.182 2,196.612 25.577 74.781 5,974,646.392 371;773.681 0.34 21.854 2,300.000 0.201 169.863 2,244.181 2,296.611 25.015 74.836 5,974,645.828 371,773.727 0.25 21.290 2,400.000 0.266 143.675 2,344.180 2,396.610 24.752 75.012 5,974,645.563 371,773.898 0.12 21.019 2,500.000 0.250 161.389 2,444.179 2,496.609 24.301 75.280 5,974,645.108 371,774.159 0.08 20.555 2,600.000 1.402 77.055 2,544.172 2,596.602 24.234 76.115 5,974,645.026 371,774.993 1.40 20.446 2,700.000 4.377 73.810 2,644.043 2,696.473 25.541 80.771 5,974,646.254 371,779.670 2.98 21.523 2,800.000 7.322 74.874 2,743.504 2,795.934 28.326 90.653 5,974,648.869 371,789.597 2.95 23.816 2,900.000 9.085 70.425 2,842.451 2,894.881 32.541 104.466 5,974,652.847 371,803.479 1.87 .27.344 3,000.000 10.386 66.299 2,941.004 2,993.434 38.828 120.189 5,974,658.863 371,819.306 1.48 32.848 3,100.000 12.350 67.455 3,039.050 3,091.480 46.603 138.233 5,974,666.327 371,837.478 1.98 39.722 3,200.000 14.685 68.540 3,136.276 3,188.706 55.334 159.896 5,974,674.685 371,859.286 2.35 47.373 3,300.000 17.564 68.916 3,232.334 3,284.764 65.390 185.775 5,974,684.296 371,885.332 2.88 56.139 3,400.000 20.479 68.456 3,326.866 3,379.296 77.268 216.113 5,974,695.652 371,915.866 2.92 66.505 3,500.000 23.564 69.035 3,419.567 3,471.997 90.789 251.062 5,974,708.572 371,951.038 3.09 78.284 3,600.000 26.544 68.154 3,510.051 3,562.481 106.316 290.672 5,974,723.419 371,990.905 3.00 91.837 3,700.000 27.636 67.154 3,598.996 3,651.426 123.715 332.929 5,974,740.091 372,033.450 1.18 107.129 3,800.000 27.764 67.072 3,687.565 3,739.995 141.959 375.622 5,974,757.599 372,076.445 0.13 123.242 3,900.000 28.044 68.400 3,775.888 3,828.318 159.541 419.092 5,974,774.434 372,120.206 0.68 138.657 4,000.000 27.903 67.866 3,864.212 3,916.642 176.970 462.625 5,974,791.114 372,164.027 0.29 153.915 4,100.000 27.830 67.193 3,952.619 4,005.049 194.870 505.796 5,974,808.272 372,207.495 0.32 169.663 4,200.000 27.956 65.815 4,041.043 4,093.473 213.277 548.717 5,974,825.940 372,250.721 0.66 185.928 4,300.000 27.969 63.068 4,129.285 4,181.715 233.565 591.159 5,974,845.498 372,293.501 1.29 204.097 4,400.000 28.314 59.290 4,217.616 4,270.046 255.998 632.311 5,974,867.221 372,335.028 1.81 224.470 4,500.000 29.144 54.449 4,305.251 4,357.681 282.278 672.659 5,974,892.805 372,375.816 2.47 248.726 4,600.000 29.115 49.887 4,392.488 4,444.918 312.309 711.215 5,974,922.169 372,414.877 2.22 276.817 4,700.000 28.948 47.550 4,479.961 4,532.391 344.494 747.440 5,974,953.727 372,451.644 1.15 307.175 4,800.000 29.101 47.475 4,567.425 4,619.855 377.351 783.083 5,974,985.967 372,487.841 0.16 338.232 4,900.000 29.261 47.388 4,654.726 4,707.156 410.300 819.040 5,975,018.293 372,524.354 0.17 369.366 5,000.000 29.265 47.503 4,741.953 4,794.383 443.399 855.040 5,975,050.769 372,560.912 0.06 400.647 5,100.000 29.320 46.874 4,829.172 4,881.602 476.596 890.966 5,975,083.344 372,597.398 0.31 432.030 5,200.000 29.548 46.479 4,916.273 4,968.703 510.320 926.690 5,975,116.448 372,633.690 0.30 463.949 5,300.000 29.580 45.838 5,003.246 5,055.676 544.497 962.294 5,975,150.009 372,669.871 0.32 496.327 5,400.000 29.400 45.370 5,090.287 5,142.717 578.943 997.469 5,975,183.845 372,705.627 0.29 528.995 5,500.000 29.433 44.529 5,177.386 5,229.816 613.722 1,032.168 5,975,218.022 372,740.914 0.41 562.018 5,600.000 29.033 44.456 5,264.638 5,317.068 648.620 1,066.362 5,975,252.327 372,775.697 0.40 595.185 5,700.000 28.429 45.799 5,352.354 5,404.784 682.457 1,100.432 5,975,285.574 372,810.338 0.88 627.300 5,800.000 28.362 46.068 5,440.350 5,492.780 715.495 1,134.567 5,975,318.020 372,845.031 0.14 658.612 5,900.000 28.538 46.164 5,528.247 5,580.677 748.519 1,168.968 5,975,350.448 372,879.989 0.18 689.898 03 February, 2005 - 9:45 Page 2 of 5 COMPASS ORIGINAL ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Plan Report for Plan: CD2-17 -Plan: CD2-17 A -Plan: CD2-17 A (wpO1) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) (°) (°) lft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 6,000.000 28.501 45.740 5,616.130 5,668.560 781.683 1,203.273 5,975,383.018 372,914.853 0.21 721.328 6,100.000 28.573 45.207 5,703.968 5,756.398 815.202 1,237.346 5,975,415.945 372,949.492 0.26 753.123 6,200.000 28.469 44.706 5,791.810 5,844.240 849.021 1,271.110 5,975,449.179 372,983.827 0.26 785.234 6,300.000 28.384 44.253 5,879.794 5,932.224 882.937 1,304.405 5,975,482.517 373,017.695 0.23 817.465 6,400.000 28.384 43.670 5,967.736 6,020.166 917.174 1,337.479 5,975,516.181 373,051.347 0.28 850.028 6,500.000 28.185 43.400 6,055.794 6,108.224 951.604 1,370.041 5,975,550.046 373,084.491 0.24 882.808 6,600.000 27.884 42.897 6,144.044 6,196.474 985.820 1,402.311 5,975,583.702 373,117.339 0.38 915.389 6,700.000 27.306 42.524 6,232.634 6,285.064 1,019.992 1,433.679 5,975,617.330 373,149.284 0.60 947.971 6,800.000 26.938 42.304 6,321.689 6,374.119 1,053.535 1,464.402 5,975,650.340 373,180.574 0.38 979.957 6,900.000 27.320 40.616 6,410.752 6,463.182 1,087.519 1,494.613 5,975,683.799 373,211.360 0.86 1,012.407 7,000.000 31.058 30.039 6,498.377 6,550.807 1,126.261 1,523.030 5,975,722.046 373,240.434 6.36 1,049.700 7,100.000 33.787 25.404 6,582.769 6,635.199 1,173.743 1,547.949 5,975,769.091 373,266.159 3.69 1,095.894 7,200:000 36.830 16.426 6,664.352 6,716.782 1,227.566 1,568.882 5,975,822.543 373,288.008 6.01 1,148.617 7,300.000 40.002 6.944 6,742.621 6,795.051 1,288.507 1,581.076 5,975,883.262 373,301.242 6.68 1,208.882 7,400.000 43.079 359.145 6,817.226 6,869.656 1,354.909 1,585.003 5,975,949.582 373,306.304 6.01 1,275.010 7,500.000 47.211 352.006 6,888.199 6,940.629 1,425.016 1,578.936 5,976,019.777 373,301.438 6.53 1,345.331 7,600.000 54.017 351.837 6,951.866 7,004.296 1,501.186 1,567.374 5,976,096.127 373,291.182 6.81 1,421.979 7,700.000 61.809 349.559 7,004.701 7,057.131 1,584.900 1,553.786 5,976,180.054 373,279.029 8.03 1,506.261 7,800.000 66.265 347.602 7,047.817 7,100.247 1,673.360 1,536.156 5,976,268.796 373,262.917 4.79 1,595.484 7,900.000 71.795 343.064 7,083.817 7,136.247 1,763.519 1,512.437 5,976,359.340 373,240.746 6.97 1,686.704 8,000.000 79.098 340.560 7,109.133 7,161.563 1,855.338 1,482.195 5,976,451.655 373,212.082 7.69 1,779.903 8,100.000 86.070 336,754 7,121.503 7,173.933 1,947.844 1,446.523 5,976,544.751 373,178.001 7.93 1,874.057 8,184.000 88.346 332.949 7,125.156 7,177.586 2,023.464 1,410.187 5,976,620.975 373,142.967 5.27 1,951.379 7.. 8,200.000 88.605 332.619 7,125.582 7,178.012 2,037.687 1,402.872 5,976,635.321 373,135.897 2.62 1,965.946 8,30Q.000 88.262 330.925 7,128.312 7,180.742 2,125.731 1,355.543 5,976,724.154 373,090.085 1.73 2,056.219 8,400.000 88.300 331.056 7,131.292 7,183.722 2,213.148 1,307.073 5,976,812.380 373,043.121 0.14 2,145.922 8,500.000 88.276 331.272 7,134.435 7,186.865 2,300.653 1,258.773 5,976,900.692 372,996.330 0.22 2,235.706 8,600.000 89.330 332.180 7,136.358 7,188.788 2,388.771 1,211.540 5,976,989.598 372,950.615 1.39 2,326.048 8,700.000 89.330 332.180 7,137.528 7,189.958 2,477.207 1,164.874 5,977,078.812 372,905.473 0.00 2,416.680 8,757.000 89.330 332.180 7,138.194 7,190.624 2,527.615 1,138.274 5,977,129.664 372,879.742 0.00 2,468.340 'Begin Geosteering @ 0.00 Dr_S: 8757.OOOft MD,7190.624ft TVD'-'6 1/8" Open 8,800.000 89.369 332.196 7,138.682 7,191.112 2,565.646 1,118.212 5,977,168.029 372,860.335 0.10 2,507.314 8,900.000 89.461 332.233 7,139.703 7,192.133 2,654.111 1,071.599 5,977,257.272 372,815.246 0.10 2,597.973 9,000.000 89.552 332.270 7,140.564 7,192.994 2,742.608 1,025.041 5,977,346.545 372,770.213 0.10 2,688.660 9,100.000 89.644 332.307 7,141.266 7,193.696 2,831.135 978.540 5,977,435.848 372,725.237 0.10 2,779.375 9,200.000 89.735 332.344 7,141.808 7,194.238 2,919.694 932.096 5,977,525.181 372,680.319 0.10 2,870.119 9,300.000 89.826 332.381 7,142.191 7,194.621 3,008.284 885.709 5,977,614.544 372,635.458 0.10 2,960.890 9,400.000 89.918 332.418 7,142.414 7,194.844 3,096.903 839.379 5,977,703.937 372,590.655 0.10 3,051.689 9,500.000 90.009 332.455 7,142.477 7,194.907 3,185.553 793.106 5,977,793.358 372,545.909 0.10 3,142.515 9,600.000 90.101 332.492 7,142.381 7,194.811 3,274.233 746.890 5,977,882.808 372,501.221 0.10 3,233.368 9,700.000 90.192 332.529 7,142.125 7,194.555 3,362.942 700.732 5,977,972.287 372,456.591 0.10 3,324.248 9,800.000 90.284 332.566 7,141.710 7,194.140 3,451.681 654.631 5,978,061.794 372,412.019 0.10 3,415.155 9,900.000 90.375 332.603 7,141.135 7,193.565 3,540.449 608.588 5,978,151.330 372,367.506 0.10 3,506.087 10,000.000 90.467 332.640 7,140.400 7,192.830 3,629.245 562.603 5,978,240.893 372,323.050 0.10 3,597.046 10,100.000 90.558 332.677 7,139.506 7,191.936 3,718.070 516.676 5,978,330.484 372,278.653 0.10 3,688.030 10,200.000 90.649 332.714 7,138.453 7,190.883 3,806.924 470.807 5,978,420.101 372,234.315 0.10 3,779.039 10,300.000 90.741 332.751 7,137.239 7,189.669 3,895.805 424.996 5,978,509.746 372,190.036 0.10 3,870.074 10,400.000 90.832 332.788 7,135.866 7,188.296 3,984.714 379.244 5,978,599.418 372,145.815 0.10 3,961,133 10,500.000 90.924 332.825 7,134.334 7,186.764 4,073.651 333.550 5,978,689.116 372,101.653 0.10 4,052.217 10,600.000 91.015 332.862 7,132.642 7,185.072 4,162.615 287.915 5,978,778.841 372,057.550 0.10 4,143.325 10,700.000 91.107 332.899 7,130.790 7,183.220 4,251.605 242.338 5,978,868.591 372,013.507 0.10 4,234.458 10,800.000 91.198 332.936 7,128.779 7,181.209 4,340.623 196.821 5,978,958.367 371,969.523 0.10 4,325.614 10,900.000 91.290 332.973 7,126.608 7,179.038 4,429.667 151.362 5,979;048.168 371,925.598 0.10 4,416.793 11,000.000 91.381 333.010 7,124.278 7,176.708 4,518.737 105.963 5,979,137.995 371,881.733 0.10 4,507.996 11,100.000 91.472 333.047 7;121.788 7,174.218 4,607.833 60.623 5,979,227.846 371,837.928 0.10 4,599.222 11,20x0.000 91.564 333.084 7,119.139 7,171.569 4,696.954 15.342 5,979,317.722 371,794.183 0.10 4,690.470 11,30:7.000 91.655 333.121 7,116.330 7,168.760 4,786.101 -29.879 5,979;407.623 371,750.497 0.10 4,781.740 11,400.000 91.747 333.159 7,113.361 7,165.791 4,875.273 -75.040 5,979,497.547 371,706.872 0.10 4,873.033 03 February, 2005 - 9:45 Page 3 of 5 COMPASS ORIGINAL ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Plan Report for Plan: CD2-17 -Plan: CD2-17 A -Plan: CD2-17 A (wpO1) Measured Sub-System Vertical Local Coordinates Map Coordinates Depth Inclination Azimuth Depth Depth +N/S +Ei-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 11,500.000 91.838 333.196 7,110.233 7,162.663 4,964.470 -120.141 5,979,587.495 371,663.307 11,600.000 91.930 333.233 7,106.946 7,159.376 5,053.691 -165.183 5,979,677.467 371,619.802 11,700.000 92.021 333.270 7,103.499 7,155.929 5,142.937 -210.164 5,979,767.462 371,576.358 11,800.000 92.113 333.307 7,099.892 7,152.322 5,232.207 -255.085 5,979,857.480 371,532.975 11,808.727 92.121 333.310 7,099.570 7,152.000 5,239.999 -259.003 5,979,865.337 371,529.191 TD (BHL)-1 1:808.720 ft MD, 7152.000 ft TYD; 1775ft FNL,& 1797ft FEL, Sec35- Based upon Minimum Curvature type calculations, at a Measured Depth of 11,808.73ft the Bottom Hole Displacement is 5,246.40ft in the Direction of 357.17° (Grid). Plan Annotations Measured Vertical Depth Depth (ft) (ft) 8,757.000 7,190.624 11,808.720 7,152.000 Vertical Section Information Angle Type User Local Coordinates +N/S +E/-W Comment (ft) (ft) 2,527.615 1,138.274 Begin Geosteering @ 0.00 DLS: 8757.OOOft MD,7190.624ft TVD 5,239.992 -259.000 TD (BHL)-11808.720 ft MD, 7152.000 ft TVD; 1775ft FNL & 1797ft FEL, Origin Origin Start Target Azimuth TYPe +N/_S +E/-W TVD (°) (ft) (ft) (ft) No Target (Freehand) 357.170 Slot 0.000 0.000 36.530 Dogleg Vertical Rate Section (°/100ft) (ft) 0.10 4,964.348 0.10 5,055.684 0.10 5,147.042 0.10 5,238.420 0.10 5,246.396 03 February, 2005 - 9:45 Page 4 of 5 COMPASS ORIGINAL ConocoPhilli s Alaska Inc. Al ine P ~ A ) - Colville River Unit North Reference Sheet for Alpine CD2 -Plan: CD2-17 -Plan: CD2-17 A Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 using datum NAD 1927 (NADCON CONUS), ellipsoid Clarke 1866 Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -150.00°, Longitude Origin:0.00°, Latitude Origin:0.00° False Easting: 500,OOO.OOOft, False Northing: O.000ft, Scale Reduction: 0.99991869 Grid Coordinates of Well: 5,974,622.100, 371,698.480 Geographical Coordinates of Well: 70° 20' 20.03" N, 151° 02' 28.01" W Grid Convergence at Surface is: -0.98° Magnetic Convergence at surface is: -24.74° (6 December 2004, , BGGM2004) T Magnetic °M odeL" BGGM 21704'" Date: 176-C~ec-i74. Declination: 23.?6° Inclinati~nJDip:> hu.6n° Field 8trengthr' S?51 ;; Grid N orih is0 S8° Vt+est ofTrue North (Grid Convergence) MagneticNarth s~3.76° Ea~'ofTrueNorih (M agnetcDedination) MagneticNOrth is 24.74° East ofGrid North (MagneticConvergence~- To converts True Diredionto a Grid Direction, Add 0.98° To tanverta MagneticDiredionto aTrue Direction,Add'23.76° ' To aonverta Magnetic Diredionto acrid Drection,Add 24,74° 03 February, 2005 - 9:45 Page 5 of 5 COMPASS ORIGINAL Halliburton Sperry-~ Anticollision Report 'y ~ o r ~~N v~, Gs Company: ConocoPhillips Alaska Inc. Field: Cdville River Unit Reference Site: Alpine CD2 Reference Well: Plan: CD2-17 Reference Wellpath: Plan: CD2-17A NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: TVD Interval: 5.00 ft Depth Range: 7142.00 to 7200.00 ft Ma:dmnm Radius: 1320.00 ft Casiug Points MD TVD Diameter Hole 5iu Name ft ft in in 11808.72 7152.43 6.125 6.125 6118" Date: 2/3/2005 Time: 11:23:00 Page: 1 Co-ordinate(NE) Reference: Well: Plan: CD2-17, True North Vertical (TVD) Reference: CD2-17: 52.4 Db: Sybase Reference: Plan: Plan: CD2-17A (wp01) & NOT P Error Model: ISCW SA Ellipse Scan Method: Horizontal Plane Error Surface: Ellipse + Casing Plan: Plan: CD2-17A (wp01) Date Composed: 12T//2004 Version: 5 Principal: Yes Tied-to: Fran: Definitive Path Summary <---------- Offset Wellpath ---- ---------> Reference Offset Ctr-Ctr No-Go Allowahle Site Well Wellpath MD MD Distance Area Deviation Warning. ft ft ft ft ft Alpine CD2 CD2-06 CD2-06 V6 Out of range Alpine CD2 CD2-10 CD2-10 V7 Out of range Alpine CD2 CD2-10 CD2-10P61 V8 Out of range Alpine Outlands Alpine 1 Alpine 1A VO 8885.94 9707.17 212.76 331.16 -118.40 FAIL: Major Risk P QRIGINAL i° • PINE ~1- .`, ~~o~oPhill~ps I ~ '~ I ~ I ~ I 1 '~ I '~ I 1 __ -.._ - - -. QL I ~: I I I I 1 I 6650 G - -• -• ~- .-~- - I - - - -1 --+ ' I I I I ~' I I I I --- I-- - - -1- -- - 1 - ~ I I 1 I I I I I ...... : I I :.....;..... ....i ... .. ;---~ I ' ~ ~ .. ! i. I I ~ ~ ' 1 I I ~ I ~ I I I I I I I I t 1 t ~ 700 : I I i I i I f.....: L, 7" @ 9432' MD _... r- -;.---i- I i i i `~- I ,,~1,L•1~ -!--:--:' --- -, --1-- - -- - -V" - _ - ---~- ~~ 1 I . 1 I --->----r--- ~-----<,---- - ---r----- ~-----?---• - ---r---<-- - t I I I I -'.----1--~-i-=- -t-=--i--~----r-'--'. -1 I P\a~. I I I I I ~ ,' I CD2-17A (Toe) I 1 --- ---------- ~ ----- i ... ; ... I ,_.- . 1 . ;.cl .~.- ~ X61/8" O n Hole ~.... I i~ - ..:---- - 1-----`--°•:---- - ---1....- ~------. ---I ........... ..1 ',, 4750 ' _ ' _- I -' I I ~` 800 1_ __ _ I _____ - I I .____I__________! __________I_____ ~ I I I t I I 1 - I ..,. - I i I I I I I I I I 1 I I I ~ I ~ ' I I I I I I ~ ~ ~ ~ i i I i i I t ? I ~ I I I I ~ 3800 , -~ -:--i--^-^-+-'-~-=- ; , --1--:--_ ___ -+-;--~- -~----I--^-^------~-;--~--~----~-- ---~ ~ I I I _ I I I I I ~ . I I 1 f f I I I 1 1 I I ~ ' ..:-... ~ I I I I ~ - I - -- I I : ~- I I I , _L. ;. ' ~ ~ I I I I I I I I ~~ I I I I I I 2850 I I --•--~--- -I r---^-^-^ I 'e1 ~ ~ -- ---- -I-- - P,CP I I i I I ~ I -- ------ - -- - - I i-^,-^--~--:--j -~ T i i I i i 11•b95 ---_ \` I 6 1/8" Open Hole I I I - .. - I i I i ---~..°-:--°° : _: •-•- --- - - -- -- - I ,,~0 I -' - _ - - ~ I I i i I CD2-17C Pt ^ I • - •: - •- - -• - I I i, ' - I ,~p5p - - ~ I I I I i ~ ..........._ ... 4 ------•-----•... I pop ~ -: r -_ I ~ ~ ' I I I I ~ , ~ 7 00 • .. :.. ... :. ' ! 17050 • I i i I i i ~ J „ . I n I i I ~1 J 1 I I ,1 ' ~ I I 1900 - _ - _;- - _ _ r _ _ } _ + _ y _ -; I I . - - _ - _ _ _ _ ....cc~~ , I I ~ 1 _ ~ _ ~ _ _ _ y _ ~ _ _ _ _;_ _;- _ - - ~. _ ,. ~ 7000 I 1 I .... I ? p I, i I .' ,r 8950 ! 1 i i I 1 i _ _ ~ 1 $pO ~ ' I - - 6900 I 1 1 ......! 9 5/8" @ 2811' MD :- ~ ~-.. :.. `~ i a- 7 r ~--° - - - --- i '~ ~ - i 6850 i i I -i ` I i ~ I I I 1 I '680 1 1 I ! 950 - -,---- - ,- -r- I-- -7- - - - - -- - - I I I 1 ---- -- - - - ----- - - -T- -r- `1 I I 1 ----~--'---[--'--7----j----.f -....:..-...t.-.--:.-....;. I 1 .. Y-...-y...---'.....i-....:__ " 't .-~: ..' ..-~ I ~ -t~- -.. ..... i.--. .---1-----'-----j--.. - - ---.f....-~---...i...l I I I 1 1 I I I i I I ~ I ~ ~ 1 f I I 0 -1900 -950 0 950 1900 2850 3800 West(-)/East(+) Sperry-sun DRILLI_N_G__SERVICES \ II \II IIIl NIA ~ IA~lll'\~l Circles of 1320' Radius ORIGINAL • ~ • r'~'C:iANICAL INTEGRITY R :PORT .~ BUD u:.IS : e '~~(o `a~Oa OPER ~ FZELD C~~ ~ \ .c r~~~~~~: ~ ~-ji~-aoo~ h:.LL NUMBER ~~ a_- \"1 C~ a-1`1 aoa-ors- ~ ~ a~5-~1'-t _N ~ LL 0AT_ ~_ TD : ~_ ?-~.. TVD ; . BTD : ~ - _ _ - m C as i~ g Shoe . \ --~ MD TVD ; D7 . ~v R ?~ •'~'4'D :.,_:,e~ . N p~ Shoe . ` ~ '~ T`TD ; _Gr . ~•~ T'iD =ub'-='S ~=Packer ~_'~ TV7i Set z~ '~l~\ ole S:~::e ~) and ~`~ Perfs p ~~ ~oPa~ A\~~ ~n3-~`1 ~i~S4-~~s~t ".~C'r'~?~=C.I., ~NTEGRITv - P 4.RT # 1 ..-. r_nruius ?ress Test: _? t~~2S; 15 nin I~SSC~ ?,0 min tFsaS Comments : ~~1--~ ~ ~~ ~~~arcy co~~~c '~~e'o~z '.-~'CHP?~IC?_:.., INTEGRITY - .PART 2 ~~^~t,~J S~4Es4v¢~.2~ l(~ bh`5 # r-'- 3l bb ~- Cement Volumes :~_ A.mt. Liner CsQ ~~~~~ DV Cwt -rot to cover aer~s 'ter 3~Zo1CS a3 bb~ c7~«~t~~ ~ wcas Su~~«Er~~ ~o a~~~c ~opc~- h~~o~r,~ b\JS ~O ~ _ eoretical TOC '~'~~`?o'KS Tt~C- ~iS ~~3~~ \o~S~~~~~v4\ '1~"y~3 - "~55Ss CµZ' ~1a3-t7~ Cement Bond Log (Yes or No) ~ctg In AOGCC File--\ . CBL Evaluation,. gone move perfs ~~ ~r~ pi~SE'y~~C,~~b~is `t 5 ~ticct 4 `~ ~.~ ~ ~ ~~ t r.~ ~r~ ~ ~ d SS -r t s `~asorc~. \~ ~Q~c.ICD~G~c-- ~-~yc- ~-~E ~DO~ ~S~ SZrM+~c~r ~~- Ec- ~~. Production Log: Type. ; Evaluation CONCLJS?ONS: ?art :1 : Nl ~ .uc~s ~cc a~ou.~~"~~~ 'art 1c: ~'-~ ~ ~S ~ - ~S~~a~$-os - C02-06 bz-D7S.4 coz-zo GD2-12 (U 2-2J J -15 Open h cD of Re iew ~ 35 z-ze 1 ~ [l7 7 ~, .. ~~~ ' ~_'~ ,j coz-la !`. „~;S'a T12N, E, UM CDZ-IJ ~ coz-1 n CRU CD2-17A Proposed Injector 2050170 Confidential wells are red SFD 2/07/2005 .I ~~~,-,~ 1-31 1 CD 2-338 T11 N, 1~4E, U C01-42 CDI-zl col Feet 0 1 ,000 2,000 3,000 4,000 • • -~-.._...._...~,.,..~..~.~.-.~.~.,.-..,.~..,.._...~.~.,,~.,..-,.,...., ,. . , A.~T~.,.,.-.~, SHARON K. ALLSUP-DRAKE 1089 f, CONOCOPHILLIPS ~; 000 S530 ~eJjd/CL/~ ~; ANCHORAGE AK 99501 ^ 'AI ./~ ~~, DATE 311 PAY TO THE ~ ~ ~ n~i N/ ~}^~~ if'( l--f C~ P, ORDER OF [/ , 1a,.i ,-~I ~ ~"'! ~ ~OO, V _~~ ~W [ S !~._ ~~ ~O~~ARS Ll o~~r,~:~a.~kx ~ CHASE Chase Manhattan Bank USA, N.A. Valid Up TO 5000 DOlla(S ~r j ' 100 Whila Clay G¢nter D.., Naw.~arh, DL 19111 ppy F1 / ~ G ~ ~ ~S ~y __.__._.__ t/ MEldO -- - - ----- _- --- - / /- -- s --- / - ~:03 L L00 L~,4~: 21847 L9079 276~i' 1089 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~',eGC C~ Z -~7 ~ PTD# 2~S- 4 ~ '7 evelopment Service Exploration Stratigraphic CHECK WIiAT ADD-OHS "CLilE". APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well Permit No, ~ API No. (lf API number Production, sbould continue io be reported as . last two. (2) digits a function~of the original API number, stated are between 60-69) above. PILOT I30LE In accordance with 20 AAC 25.005(f), all (PIS records, dais and logs acquired for the pilot bole must be clearly differentiated ~in both name (name on permit plus PIS and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject •io full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ exception. (Comuany Hamel assumes the liability of any protest to ibe spacing .exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted io the SAMPLE Commission must be in no greater than 30' . sample intervals from below the permafrost . or from where samples are first caught and ] 0' sample intervals through target zones. ELL PERMIT CHECKLIST Field & Pool COLVILLE RNER, ALPINE OIL -120100 Well Name: COLVILLE RIV UNIT CD2-17A Program SER Well bore seg ^ PTD#:2050170 Company CONOCOPHILLIPS ALASKA INC Initial Classll'ype SER I PEND GeoArea 890 Unit 50360 OnlOff Shore On Annular Disposal ^ Administration 1 Permk_feeattached------------------------------------ -------- Yes- _--__-_.___-_____- -- 2 Lease number appropriate - - - - - - Yes - - - - - ---------- 3 Unique well-name and number_________________ __..._- Yes_ ___._. 4 Well located in a-definedpool____------------------------- -------_ Yes_ ____-___ -__- -- - - - 5 INelllocatedp[operdistancefromdrillingunit_boundary______ __--___ _____ -_- Yes_ ____________________ ------------------------------------------------------ 6 Well locatedproperdistancefromotherwells___-__.-_-____ _--____ Yes_ _______________------- -__ - - 7 Sufficientacreageayail_ablein_dril_lingunit_______________________ _________ Yes ___-_--_--_---_---_--_- - -- - - 8 If deviated, is-wellboreplat_included_________________________ __--__--_ Yes_ ____-_-._ -- - - - 9 Ope[atoronlyaff_ectedparty----------------------- ------ ------ -- Yes- -------.-----------------.- - - - 10 OpQ[atorhas-appropriate.bot~dinforce________________________ _________ Yes. _._____-_________-__." 11 Permit-can be issued without conservation order__________________ __- ----_ Yes_ ____--_-______--____---__--___----_ -- Appr Date 12 ?e[mit_canbeissuedwithoutadminist[ative_approval__ _____________ _________ Yes_ ____--____--__--__--__.-_--_---_- - - SFD 2/7!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Order # (putl0# in_comments)-(Fpr. Yes - _ - -Injection governed by Area Injection Order No.-186_ _ - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells within 1l4_mile area of [eyiew identified (Far service well only) _ . _ _ _ _ _ .. " - _ _ _ - Yes _ _ .. _ -Heel of CD 2-06 is -600' to NW, CO 4432 species-a minimum well spacing of 500'_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-prpdu_ced injector; duration-ofpre-production Less than_ 3 months. (Forservice well only) - No_ _ _ _ _ _ - - _ , - , _ - - _ _ - - _ - - 17 ACMP_Finding of Consistency_has been issued_forthis project - _ . - NA- - _ _ . Engineering 18 Conductor string_provided - - - - - - - - - - - - - - - - - - - - - - NA- - - _ Conductor set_in priginal we_Ilbore CD2-17 (202-015) - . - - - 19 Surface casing-protects all known USDWs _ - _ _ _ - - _ . - - - - - - - - - - - - - - NA- _ _ _ _ _ _ - No aquifers,_pe['AIO,18A conclusion 3._ _ _ _ _ - - _ . _ _ _ _ _ _ _ _ _ 20 CMT-vol-adeguate_to circ_ul_ate_on conductor& surf_csg NA_ Surf_ace casing cement set in-original wellbore, - - _ . _ _ _ 21 CMT-vol-adequate_to tie-in long string tosurf csg- - - - - No_ , 22 CMT_will cover all known_productive horizons_ No_ Open_hole completionplanned. _ _ - 23 Casipg designs adequate fo[ C, T, B & permaf[ost_ _ _ . - - NA_ - - _ _ _ _ _ No oasing to beset in program.. - _ - _ - - - 24 Adequate tankage_or reserve pit _ . _ _ _ - _ Yes - - _ _ - - _ f3ig.isequipped With steel-pits. No reserve_pitplanned, Wast to approved annulus or disposal well. 25 If a_re-drill, has-a 10-403 for abandonment been approved NA- - Original completion_sectionwill-be retame_d. _S. McMaines wll issue administrative. abandon for Cf)2-17.- 26 Adequate wellbore separationproposed________________________ _________ Yes_ __._._Nowellboresproximate.____-____________--_________ 27 If_diverter required, does it meet regulations_ _ _ _ - _ - - - _ - - _ _ - - NA_ - _ _ BOP stack_will al[eady_b_e in place, _ _ _ _ - - - - - Appr Date 28 Drilling fluid_program schematic-$ equip listadequate- - - - - - _ _ - - Yes - - Maximum expected formation pressure 8,7_EMW._ Planned MW 9.0 - 9.6_ppg.- _ - - _ - TEM 2!9/2005 29 BOPEs,dotheymeet_regulation---------------------------- --------- Yes_ ___-___ ------------------------------------------------------------------- 30 BOPS-press rating appropriate; test to_(put psig in comments)- - - - - - Yes MA$P calculated at 2530psi, 3500-psi_appr_opriate. CPAI normally tests to 5000-psi: - - 31 Choke.manifoldcomRlieswlAPI_RP-53(May84)___________________ _________ Yes_ __-__-._____-___ --------------------------------------------------------- 32 Work willoccur-withoutoperationshutdown_--__________--___ _------__ Yes_ _------------------------ 33 Ispresence-ofH2Sgasprobable____________________________ __ ______ No__ -__-._H2Shas nQtbeenrepor#edatAlpine.__-__--_-______--__--_- 34 Mechanical cond~ion of wells within AOR verified (For service well only) _ _ _ - _ _ - - - - - - Yes _ - _ Alpine 1A, P&A acceptable.- CD2-O6, evaluated for-MIT II 11!10!03- - - - - - - - - - - - - - - - - - - - - - Geology 35 Permit can be issuedwlohydrogen_sulfidemeasures-_---__________ __ ______ Yes_ -______-----__--_____------__-__ ----------------------------------------- 36 Data-presented on_potential overpressure zones _ _ - _ _ - - - Yes _ _ _ _ - Expected mud weight is 8.7-ppg EMW; will be drilled with 9.0 -9.6ppg mud__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 37 Seismic analysis of shallovrgas-zones_ _ - - _ _ - - - _ - _ _ _ _ _ - NA__ Extension of existing well.-_--________--_-__---__--_-____-------- SFD 217!2005 38 Seabed cQnditi_on survey-(if off-shore) _ _ _ - . - _ - _ . NA - - - - - - 39 -Contact namelphone_forweekly progress_reports [exploratory only]- - _ - _ _ _ - . - - NA_ _ - - Geologic Engineering blic Commissioner: Date: Commissioner: Date loner Date ~`~ to ~ , s-~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 22 14:49:21 2006 Reel Header Service name .............LISTPE Date .....................06/02/22 ~ ,.p Origin ...................STS ~ Reel Name ................UNKNOWN f Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/02/22 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: MW-000398579 LOGGING ENGINEER: M. HANIK OPERATOR WITNESS: D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING Scientific Technical Services Scientific Technical Services CD2-17A 501032040601 ConocoPhillips Alaska, Inc. Sperry Drilling Services 22-FEB-06 2 11N 4E 1736 1543 52.43 15.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 8184.0 ~~> ep ~7 • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. CD2-17A IS A HORIZONTAL EXTENSION OF THE CD2-17 WELLBORE, STARTING AT 8756'MD/7187'TVD, THE TD OF CD2-17. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND AT-BIT INCLINATION (ABI) MAD SGRC DATA ACQUIRED WHILE RIH FOR MWD RUN 1 WERE MERGED WITH RUN 1 MWD DATA. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUN 1 REPRESENTS WELL CD2-17A WITH API#: 50-103-20406-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11819'MD/7142'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/22 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 8500.5 11765.5 RPM 8500.5 11765.5 RPS 8500.5 11765.5 RPX 8500.5 11765.5 GR 8500.5 11758.5 ROP 8500.5 11819.0 FET 8756.5 11765.5 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 8500.5 11819.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8500.5 11819 10159.8 6638 8500.5 11819 RPD MWD OHMM 2.88 46.78 13.0424 6531 8500.5 11765.5 RPM MWD OHMM 2.12 47.84 12.4042 6531 8500.5 11765.5 RPS MWD OHMM 1.52 56.1 12.0366 6531 8500.5 11765.5 RPX MWD OHMM 1.42 47.26 10.6423 6531 8500.5 11765.5 FET MWD HOUR 0.36 3.07 0.945697 6019 8756.5 11765.5 GR MWD API 40.39 106.68 60.6443 6517 8500.5 11758.5 ROP MWD FT/H 0.36 227.78 109.447 6638 8500.5 11819 First Reading For Entire File..........8500.5 Last Reading For Entire File...........i1819 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF • File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/22 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH RPD 8500.5 RPM 8500.5 RPS 8500.5 RPX 8500.5 GR 8500.5 ROP 8500.5 FET 8756.5 LOG HEADER DATA STOP DEPTH 11765.5 11765.5 11765.5 11765.5 11758.5 11819.0 11765.5 DATE LOGGED: 20-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11819.0 TOP LOG INTERVAL (FT) 8756.0 BOTTOM LOG INTERVAL (FT) 11819.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8184.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 42.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 36000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .160 71.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.840 131.0 MUD FILTRATE AT MT: .140 71.0 MUD CAKE AT MT: .180 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 S 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8500.5 11819 10159.8 6638 8500.5 11819 RPD MWDO10 OHMM 2.88 46.78 13.0424 6531 8500.5 11765.5 RPM MWDO10 OHMM 2.12 47.84 12.4042 6531 8500.5 11765.5 RPS MWDO10 OHMM 1.52 56.1 12.0366 6531 8500.5 11765.5 RPX MWDO10 OHMM 1.42 47.26 10.6423 6531 8500.5 11765.5 FET MWDO10 HOUR 0.36 3.07 0.945697 6019 8756.5 11765.5 GR MWDO10 API 40.39 106.68 60.6443 6517 8500.5 11758.5 ROP MWDO10 FT/H 0.36 227.78 109.447 6638 8500.5 11819 First Reading For Entire File..........8500.5 Last Reading For Entire File...........11819 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/02/22 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/02/22 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File