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Home My WebLink About207-056MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-302 COLVILLE RIV UNIT CD4-302 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-302 50-103-20545-00-00 207-056-0 G SPT 6776 2070560 1694 3990 3990 3990 3990 580 625 625 625 4YRTST P Bob Noble 6/25/2023 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 CD4-302 Inspection Date: Tubing OA Packer Depth 840 2120 2090 2090IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230629130400 BBL Pumped:0.9 BBL Returned:0.9 Thursday, July 27, 2023 Page 1 of 1          MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Ijegg � / P.I. Supervisor ��y I R I' q { ` l DATE: Tuesday, July 2, 2019 SUBJECT: Mechanical Integrity Tests // ConocoPhillips Alaska, Inc. CD4 -302 FROM: Adam Earl COLVILLE RIV NAN-K CD4 -302 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv•— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4 -302 API Well Number 50-103-20545-00-00 Inspector Name: Adam Earl Insp Num: mitAGEI90623112406 Permit Number: 207-056-0 Inspection Date: 6/20/2019 - Rel Insp Num: Packer Well C134-302 Type Inj 'TVD PTD 2070560 Type Test s1 Test psi BBL Pumped: I 1 BBL, Returned: Interval 4varsr P/F Notes: MIT IA ' Depth Pretest Initial 15 Min 30 YIin 45 MjnT60 Min 6776 Tubing 2710 - 271010 1694 IA 180 2090 2009 - 2060 1.4 - OA lou 886 - s„ azo Tuesday, July 2, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg1711(4' DATE: Wednesday,July 06,2016 P.I.Supervisor � �'� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-302 FROM: Guy Cook COLVILLE RIV NAN-K CD4-302 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 54 NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-302 API Well Number 50-103-20545-00-00 Inspector Name: Guy Cook Permit Number: 207-056-0 Inspection Date: 5/18/2016 Insp Num: mitGDC160519173337 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — Well CD4-302 Type Inj W 1TVD 6776 - Tubing 2205 2208 - 2205 - 2205 - 1 PTD 2070560 IType Test1 SPT Test psi 1694 - IA 136 3000 - 2970 - 2965 - Interval 4YRTST P/F P ✓ OA 732 870 . 861 854 - Notes: Tested to 3000 psi. Pumped 1.8 bbls to test pressure. , i e'.>.:.Y-.._.) NOV 2 22016 Wednesday,July 06,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim �? DATE: Monday,May 23,2016 Re P.I.Supervisor )� �( Z5�� SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-302 FROM: Guy Cook COLVILLE RIV NAN-K CD4-302 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J5 NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-302 API Well Number 50-103-20545-00-00 Inspector Name: Guy Cook Permit Number: 207-056-0 Inspection Date: 5/19/2016 Insp Num: mitGDC160519173337 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-302 : ;Type Inj W 'TVD 6776 - Tubing 2205 2208 - 2205 - 2205 PTD 2070560 iType Test SPT Test psi 1694 IA 136 3000 - 2970 - 2965 - Interval 4YRTST 1P/F P I OA 732 870 - 861 - 854 - Notes: Tested to 3000 psi. Pumped 1.8 bbls to test pressure. - SCANNED SEP 2 7 2016 Monday,May 23,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 16,2015 Jim Regg l P.I.Supervisor 1 j -alei '(i 7I i c SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-302 FROM: Johnnie Hill COLVILLE RIV NAN-K CD4-302 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2 NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-302 API Well Number 50-103-20545-00-00 Inspector Name: Johnnie Hill Permit Number: 207-056-0 Inspection Date: 6/12/2015 Insp Num: mitJWH150613213930 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-302 --Type Inj N"ITVD 6237 'TTUbingr-400 - 400 _ 400 - 400 - — —PTD 2070560 - Type Test SPT Test psi 1559 - IA 209 2021 - 1974 - 1965 - Interval 4YRTST PAF P / OA 616 826 - 816 812 - Notes: 1.8bbls diesel same) J U L 1 a 201;.:' Tuesday,June 16,2015 Page 1 of 1 ima e P•'ect Well Histo File Co~r Pa e J 1 rY J XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the originai file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~- Q~~ Well History File Identifier Organizing ~ao~e~ ^ Two-sided III IIIIIIIII III ^ Rescan Needed III IIIIII II II IIIIII RESC N Color Items: p Greyscale Items: ^ Poor Quality Originals: ~ Other: DIG AL DATA Diskettes, No.' ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: p Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: 3 Q ^ Other:: ~S~ ~ ' roo~n Pro~ect P g IIIII'IIIIIIIIIIIII eY: Maria Date: ~ ~S~ ~ Scanning Pre ration x 30 =~Q + ~~ = TOTAL PAGES (Count does not inGude cover sheet) BY: ._. Maria ~/ Date: ~ ~~D ~ ~S~ Production Scanning Stage 1 Page Count from Scanned File: -~,-l-"~ (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ r ~ /s/ ~ ~ ~~/ ~ 9 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 I) II ((I ~( I III ReScanned II I II ~III I I III II III BY: Ma~ia Date: ~~ Comments about this file: Quality Checked III IIIIII (II II'I (II 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service E 6. Permit to Drill Number: 207 -056 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -302 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG o 8. API Number: P. 0. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20545 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 312 -233 6/25/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal • drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 55965 300 381 56646 totals (bbls): 2012 / 2nd 12601 100 0 12701 13 6/7/2012 6/30/2012 CD4-213B 2012 / 3rd 0 0 58* 58 0 2012 / 4th 0 0 0 0 0 2013 / 1st 2013 / 2nd Total Ending Report is due on the 20th Volume 68566 400 439 69405 13 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. APR 0 9 2013 12. Remarks and Approved Substances .CANNku Description(s): *infectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: C. a,* Date: ltl• 61 2 _ 0 r3 Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service El 6. Permit to Drill Number: 207 -056 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -302 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20545 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal II or Continuation ❑ or Final ❑ 312 -233 6/25/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: • cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 55965 300 381 56646 5 C d totals (bbls): T 2012 / 2nd 12601 100 0 12701 13 6/7/2012 6/30/2012 CD4 -213B 2012 /3rd 2012 / 4th 2013 /1st 2013 /2nd 1 Total Ending Report is due on the 20th Volume 68566 400 381 69347 of the month following the final month of the quarter. Ex: (bbls): ( April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): PLANNED JUL 1 8 2012 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Date: 7(i ° l2crL Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Page 1 of 1 • Schwartz, Guy L (DOA) From: Samuell, John G [John.G.Samuell @conocophillips.com] Sent: Monday, June 25, 2012 2:59 PM To: Schwartz, Guy L (DOA) Cc: Brunswick, Scott A Subject: CD4 -302: Application for Annular Disposal of Drilling Waste Guy, The 10 -403 application for sundry approval for annular disposal of drilling waste that was submitted on June 22nd, 2012 will serve as a revision to the initial sundry permit #312 -197 dated 06/07/2012. The purpose of the most recent request was to increase the maximum allowable injection volume from 70,000 to 90,000 bbls. Please cancel sundry permit #312-197., w For further details please reference the original annular disposal permit for CD4 -302 (Sundry Permit #307 -257), approved on September 6, 2007 under permit to drill #207 -056. J.G. Samuel) D, iinq Engineer ConocoPhflps Alaska Direct ;907) 2(35-63001 Mohi;e. (,332) 465 -61148 J 6/25/2012 Mc Mains, Stephen E From: Schwartz, Guy L (DOA) Smmt: Juno2� 2012 n~� w,urm 25, 3:01 ?Tb ~ � �� Tm: yNoW1oi'� . 8tephen E (DOA) ^�� Cc: Fisher, Samantha J (DOA) Subject: FW: CD4-302: Application for Annular Disposal of DriIIing Waste FYI Guy Schwartz Senior Petroleum Engineer AOGCC 7S3122O (office) 7U17 - ' JUL 1 2 ^°'� 444-3433 (cell) --�-~~�—~~ � From: Samuel!, John G [mnaiKo:]ohn.G.Sannmel|Oco iUips.com] Sent: Monday, June 25 2012 2:59 PM To: Schwartz, Guy L (DOA) Cc: Brunswick, Scott A Subject: CD4-302: Application for Annular Disposal of Drilling Waste Guy, The 10-403 application for sundry approval for annular disposal of drilling waste that was submitted on June 22nd, 2012 will serve as a revision to the initial sundry permit #312-197 dated 08/07/2012. The purpose of the most recent request was to increase the maximum allowable injection volume from 70.000 to 80.000 bbls. Please cancel sundry permit . 3 12— 2.33 For further details please reference the original annular disposal permit for CD4-302 (Sundry Permit ), approved on under permit to drill #207'056. J.G. Samuell Drilling Engineer | ConncnP`mips Alaska | Direct: (907) zoo-6309|Mobile. (832) 465-8148 1 • • `f' li , a w I j \. ,k SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. _ �.. P.O. Box 100360 Anchorage, AK 99510 f 5: Re: Colville River Field, CD4 -302 Sundry Number: 312 -233 �� N ��11 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cath Fo erster Chair 1' DATED this day of June, 2012 Encl. ConocoPhillips Alaska, Inc. • • Post Office Box 100360 10 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 June 21,2012 RECEIVED Alaska Oil and Gas Conservation Commission JUN 2 2 2012 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 p C OGC Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4-302 VV Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD4 -302 (sundry permit # 312- 197 dated 6/07/2012) be re- permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. The sundry permit #312 -197 increased the maximum volume of waste to be disposed of in this well to 70,000 bbl, due to the remote location and limited available annuli on CD4. CD4 -302 was last used for annular disposal on June 18 2012. The total volume of disposed waste in this well is 63,432 bbls. This application is to re- permit the well to increase the maximum allowable disposal volume from 70,000 to 90,000 bls. '" On 6/21/2012, an injectivty test was performed with 10 bbls of diesel at a surface injection pressure of 1100 psi, which equates to injection pressure of 16.0 ppg EMW at the surface shoe depth of 2391' TVD. The initial LOT at the shoe was measured at 18.1 ppg EMW. It is therefore concluded that waste will not migrate above the confining zone provided that sustained surface injection pressures do not exceed the shoe FIT/LOT. Other wells not yet permitted for annular disposal are either in too close a proximity to exploration wells or are not good annular disposal candidates. There is also the issue that the regular disposal well at Alpine, CD1 -19A is currently out of service. This leaves us with the choice of re- permitting a previously used annular disposal well to increase the maximum allowable injection volume. For further details please reference the original annular disposal permit for CD4 -302 (Sundry Permit #307 -257), approved on September 6, 2007. Attached is an updated plot showing all the wells within quarter mile of the surface shoe on CD4 -302 and the updated annular disposal transmittal form. If you have any questions or require further information, please contact J.G. Samuell at 265 -6309; Chip Alvord can also be reached by calling 265 -6120. Sincerely, i7 7:12_1 J.G. Samuell Drilling Engineer cc: CD4 -302 Well File Rob Stinson ATO -1728 Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 • S , RECEIVED STATE OF ALASKA St9 JUN 2 2 012 ALASKA OIL AND GAS CONSERVATION COMMISSION )S 6 t/ ANNULAR DISPOSAL APPLICATION / OGCG � 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 207 -056 ConocoPhillips Alaska 4. API Number: 50- 103 - 20545 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4 - 302 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD4 - 208, CD4 - 209, CD4 - 301, Nanuk 1 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 63,432 bbls (Jun 2012 last injection) densities range from diesel to 12# /gal 2249 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 90000 bbls. / Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1 - Jun - 12 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: ig Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ❑ FIT Records w /LOT Graph Surf. Casing Cementing Data ❑ Other ❑ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: '. ! � A .• CAAW r LUDerL Title: QAMTZ-V Printed Phone Name: Chip Alvord Number: 265 - 6120 Date: 6/21/2012 Commission Use Only Conditions of approval: LOT review and approval: Subsequent form required: 1 ® L) Z3 Approval number: �J 1 2 J✓ APPROVED BY Approved by: t COMMISSIONER THE COMMISSION Date: / ZS _ / 24 Z (1° • S'Iv :ti • nt. O 4D - 1,1th q . 4 e: 1''D� �c,Ltr INSTRUCTIONS ON REVER O a� in Duplicate 00 • • Annulus Disposal Transmittal Form - Well CD4 -302 AOGCC Regulations, 20 AAC 25.080 (b) _ 1 Designation of the well or wells to receive drilling wastes: CD4 -302 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg /1. (Ref. AOGCC Conservation Order No. 443, March 15. 19991 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. The maximum volume of disposal waste allowed is 70,000 bbls. Of this amount, 63,432 bbls has already been pumped. Therefore, the maximum volume to be pumped for this re- permit application is 90,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling /completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2249 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. ✓ test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4 -213B will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0 - Jan '05 Well CD4 -302 Assumptions Date 5/25/2012 Maximum injection pressure of 1,128 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi /ft Gas/Fluid Gradient in tubing /casing annulus 0.07 psi /ft Header Pressure (for wells on gas lift) 1,000 psi on Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% = PHydrostatic + PApplied - PFormation 4,888 = ( 2,390 * 0.052 * MW ) + 1128 - ( 0.4337 * 2,390 ) N MWmax = 38.6 ppg 2,390 TVD Surface Casing String Size 9.625 in Weight 40 ppf Grade L 80 ?burst100% 5,750 psi Pburst85% 4,888 psi Depth of Shoe 2,390 ft FIT/LOT @ Shoe 18.1 ppg or 2,249 psi FIT/LOT for Annulus 16.3 ppg Max Surf. Pressure 1,128 psi TOC Est. @ 4,740' MD 3,749' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4 4,599 = ( 3,749 * 0.052 * MWmax ) + 1,128 - ( 0.0700 * 3,749 ) - 1,000 Z R MWmax = 24.3 ppg 4.5 "Tubing 2nd Casing String Size 7 in 7,096 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 3,749 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,128 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,390 * .052 * 18.1 ) Pmax allowable = 2,249 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4 -302 Rig:I Hot Oil Date: I 5/23/2012 Volume Input Pump Rate: Drilling Supervisor: 1 (Pump used: Other - SeeCommen -- V' Barrels 0.1000 Bbls /Strk IV 0.5 Bbl /min 1r Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. ■ Casing Test Pressure Integrity Test Hole Size: 8 -3/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 34.2 Ft 2,763 Ft -MD 2,391 Ft -TVD 2,793 Ft -MD 2,410 Ft -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC w 0 0 670 0 1190 Changes for Annular Adequacy Tes Pressure IntegrityTest 1 0.5 770 0.25 1160 outer casing shoe test result in comments Mud Weight: 7.2 ppg 2 1 940 0.5 1155 I Description references oute casing string Inner casing OD 7.0 In. 3 1.5 1000 1 1140 .ize is that drilled below oute casing. 4 2 1120 1.5 .timated TOC for Hole Depth 5 2.5 1130 2 1125 Enter inner casing OD at right Desired PIT EMW: I 16.3 ppg 6 3 1130 2.5 1120 Estimates for Test: 1128 psi 0.4 bbls 7 3.5 1125 3 1115 • 8 4 1125 3.5 1115 EMW = Leak -off Pressure + Mud Weight = 1128 + 7 18 p sl 1 PIT 15 Second 9 4.5 1125 4 1115 0.052 x TVD 0.052 x 2391 Shut -in Pressure, 10 5 1125 4.5 1110 EMW at 2763 Ft -MD (2391 Ft -TVD) = 16.3 1160 15 .5 1125 5 1110 20 6 1125 5.5 1105 25 6.5 1125 6 1105 30 7 1125 6.5 1105 1100 7.5 1125 7 1100 8 1125 7.5 1100 8.5 1125 8 1100 w 9 1130 8.5 1095 900 9.5 1135 9 1095 10 1135 9.5 1095 w 1 3 1150 10 1095• cc 16 1160 19 1170 700 22 1180 25 1190 500 0 3 5 8 10 13 15 18 20 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume "'lim'CASING TEST -LEAK -OFF TEST Pumped Bled Back Pumped Bled Back 0.0 Bbls IBbis 25.0 Bb's 1.OIBbls Comments: The 7.2 MW is calculated based on 56 bbls of diesel with the rest of the annulus water. (18 •) diesel / 1853'TVD- 2391'TVD is watt Initial annular LOT was 16.3 ppg and the Casing shoe test was 18.1 pp Max pressure 1230ps CD4 -302 Annular Injectivity Test - 6/21/12 CONOCOPHU 1 ms-fAII Y ANNUL AR INJECTION RECORD RIG #d I DOYON 19 I DATE 6/20/2012 t 612112012 PAGE 1 of , Injecting into well: I CD4 -302 ( 1800 HRS 1600 HRS BARRELS INJECTED FOR MUD ONLY , ( List under Proper Auld Type) O n OF g Pr t o re Pre n Uparolron that MU WAtLN to DIESEL TUiAL 'j9+ Start Stop "al Was" OI ""9 Freeze RV WaM Wale, OTHER Curtenu4swo Weight Funnel 09 la Fluids Time Time lea tPS» IPSO Mu0 WELL Proms (Sootily) voa,{„e (PPG) Viscosity IIII 1 KUTP 1417 1425 2 920 1100 10 10 6.8 24 lnjectivity Test , 2 3 Measured WHP 4 . 10006 l bbt 5 10006 2b1:1 6 12006 3bb1 7 11006 4bbI 6 11006 SbbI 9 11006 6bb1 10 ... 11006 7bbi 11 11006 8bb1 12 11006 9bbt 13 11006 10bbI i , 14 15 TOTAL FOR Cummuletive Tout • Fluid Properties MUD MUO WATER DIESEL WASH WATER OTHER TODAY from Previous Day t4ew Total FOR DAY: I 1 1 10 1 1 io f 63432 1 63442 Ytrao awed RPN W w aees4 RIM Miners{ Mewed 1D Wt Vise 600 300 Temp Y. SQpp ID Wt Vise 600 300 Temp %Sonde iD Wt Viet 600 RPM 300 Temp %Solids i1 I I I I I I P Hrwj DY CUGUCLU IWET e lt f r S SO4I 1 " I II CD4 -302 Annular Injectivity Test Chart - 6/21/12 NsvM „ ' o �d 160 T " t l P '. • p 13 `•35 • 1 ��® 8 :- 2 a W 4.q S - q y 6 g � liiL t .. L �� 4 P SURFACE CASING SHOE SEPARATION FROM CD4 -321 - CD4 -321 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 375795.28 5956945.38 Distance Ann. from Surface csg. Surface csg. Surface Details @ Disp. Ann. Object Shoe X Shoe Y Surf LOT casing TVD Annular Wells AOGCC" Permit # Permit Date Source well Vol. Start Date End Date well' Coord. Coord. (ppg) (ft) LOT (ppg) Comments CD4 -07 n 1430 376700.4 5958052.5 16.7 2396 15.4 CD4-16 y Mall- 954 376571.7 5957499.3 18.1 2388.5 17.90 Not for annular disposal, due to proximity to Nanuq 2 CD4 -17 y •11/ •-- 679 376416.3 5957221.0 18.1 2386.93 16.2 Not for annular disposal, due to proximity to Nanuq 2 CD4 -318a, CD4 -320, CD4 -214, C -208 y 306 -183 5/30/2006 CD4- 321,CD4 -211 61839 7/3/2006 1/4/2007 2344 378134.12 5956792.58 16.3 2440.26 14.4 volume extension to 70000 bbl, permit #306 -266 CD4 -209 y M _� 2175 377935.02 5957333.89 14.7 2376.79 17.5 Not for annular disposal CD4 -210 y �-� 1752 377547.47 5956963.14 18.0 2385.97 17.3 CD4 -211 y 306 -392 12/29/2006 CD4 -302, CD4-16 MEM 6/20/2007 7/11/2007 1652 377354.32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test @18.4 ppg P' Not for annular disposal. High Ann test Probably ice plug, CD4 -213 y 1687 377441.38 5956577.89 18.1 2400.5 21.40 will retest if needed CD4 -214 y " _ � 1221 377016.49 5956949.56 17.3 2400.8 17.6 Not for annular disposal CD4 -215 y IIIIII IIIII."..- -rill .- 967 376762.06 5956914.11 17.6 2400.4 17.50 Not for annular disposal . 307 -257 / 9/6/2007 Extended volume to 70,000 (64,000 bbls) 5/20/2009, CD4-302 y 309 -167 5/20/2009 CD4-213B 56647 10/21/2007 1/1/2010 3481 379247.67 5957393.4 18.1 2390.43 17.10 New ALOT was 16.3ppg 5/23/2012 CD4 -304 n /- __..J-- _ 1772 377304.4 5957874.3 16.6 2391 17.8 Not for Annular Disposal C04.306 y 307 -258 9/6/2007 CD4 -304, C04 -07 28330 9/11/2007 10/21/2007 1863 377262.19 5958093.22 18.0 2376.29 14.90 CD4 -318 y 306 -181 5/26/2006 CD4 -209, CD4 -320 MEI 5/31/2006 8/2/2006 724 376138.31 5956308.17 18.2 2375.32 17.1 Unable to pump- SD pumping CD4 -208, CD4 -318, CD4 -209, CD4 -319 y 305 -373 12/9/2005 CD4 -320 32010 12/14/2005 7/2/2006 1799 377174.72 5955790.44 18.4 2396.47 16.1 CD4 -320 y 2418 377915.36 5958108.91 17.1 2387.33 17.8 Not for annular disposal CD4 -321 y 306 -393 9/23/2010 C04 -306, CD4 -322 31117 7/14/2007 8/20/2007 0 375795.28 5956945.38 18.0 2385.47 16.3 Extension permit filed for 70,000 BBLS CD4 -322 y 307 -293 10/25/2007 CD4 -301, CD4 -05 30832 12/8/2007 1/10/2008 795 375674.64 5957731.19 18.0 2385.44 16.8 Volume extension to 70000 bbl 06/12, unable to injecl Nanuk 1 n MII- -- --� Exploration P&A'd Nanuk 2 n ` __ --- .�-- Exploration P&A'd rA' 1299 377015.63 5957391.42 11.8 1774.97 Exploration, X -Y location calculated at 2400' TVD, NOT the Nanu• 3 surface shoe depth Nanu• 3 2400" TVD _ MliiIr 828 376499.3 5957380.8 To show .roximit to Nanu. 3 at 2400' TVD Nanu • 5 '_� 2627 378326.61 5956241.68 14.9 2393.75 15.1 Not for annular disposal 3747 379541.0 5957028.4 14.8 2387 13.5 CD4-05 n 1493 377233.4 5957348.0 18.2 2388 16.5 Not for AD (too close to Nanuq 3) CD4 -25 1371 376993.5 5956278.8 17.8 2393 15.9 CD4 -26 n 979 376757.1 5956765.1 18.0 2389 17.2 CD4-24 1726 377321.7 5956140.6 16.2 2389 15.1 Planned CD4 -298 3908 379658.20 5957535.10 2390 13.9 CD4- 03w.04 2587 378180.32 5955942.15 Not for annular dis.osal CD4- 27wp07 1492 376803.42 5955845.33 Not for annular disposal • Lateral distance in feet, between surface casing shoes, in the X -Y plane **As of April 21, 2008 • Note that this sheet is not the definitive record for annular disposal volumes 1 I Project: Western North Slope ConocoPhillips Site: CD4 Nanuq Pad CD4 -302 Well: CD4 -302 Wellbore: CD4 -302 Quarter Mile View CD4 -302 0$ e Co o °` 4 r 1200 / 1 6 01 30 10 x 13 1 5/8" x 12 /4 y 9 5/8" Cp4�20pB C CD4 '� ' 7 . �9 5/8 121 /4" D I a N i / CD o ` � j -- - - o CD M V '- �� I - 9 5/8" 9 5/8" x 12 1/4" ' , ./8" x 12 1/4 4 �. I 01`..‘ r �� 9 -5/8" x 12 -1/4" p X :' x12 1/4" • 21/4" / /4" - _ - 2 10 : 3/4 I 9 5/8" x 12 1/4" O i G 4 �� /4" x 13 -1/2" TD 111 a S GD4 -301 I S 0 -1 ��, Y ' 5/8" x 121/4" 1 ‘ . 9 5/Er , a 3 p18 O g 1� C Q CD4 -301 P ? ' Q �� ••� 4213 - 180 N 4 - 7 "x 8 3/4" G �� 9 518" x 12 1/4" Na1oa cito CD4 -320 . CD4 -318A 1 G O' -1800 -1200 c -600 0 600 1200 1800 2400 3000 West( -) /East( +) (600 ft/in) • tOnOCOPhilliPS Cashlji DOM Vef1: C04 -3112 p Sl "Surface Casino Date: 6171211117 DEPTH Jt Number Nun of As COMPLETE DESORPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 13 FKB to Landing Ring 36.65 FMC fin V Hang+r 2.26 36.66 Jts 3 to 71 69 Jts 9. 616" 4011 L -90 BTC Csg 2644.03 36.91 Halliburton Fiou Collar 1.615 2682.94 Jts 1 to 2 2 Jts 9.616" 40* 490 BTC Csg 76.63 2694.09 Ray Oil Tools "surer &Met" Float shoe 2.17 2760.72 2762.$ TD 12 114" Surface Hole 2772.$ 12 114" hole MD 2.773' - 2.397' TVD 9 518" csg shoe MO 2.763.89' - 2,389' TYD TOTAL BOWSPRING CENTRALIZERS - 41 1 per jt on Jt *1 - *13 (stop ring on Jt *1 & 3 and over collars on its* 15. 17. 19, 21. 23, 25, 27, 29. 31. 33. 35, 37, 39, 41. 43, 45. 47. 49, 51, 53. 55, 57, 59. 61, 63 65. 67, 69 75 joints in the pipe shed. 71 jts to run - Last 4 jts out Use Best - o - Life 2000 pipe dope AI joints drifted • 6.791" Mal torque ' 96119 fifths RemstAx. Up Vt -666 k OnVt•144k Bock Vt • 75k Wit L7E4* /L Ail • • ConocoPhillips CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4 -302 RIG: Dolon 19 CASING DESCRIPTION: 9 518 401 L -80 BTC DATE: 06107107 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 38.33 26 39.32 51 36.66 76 101 126 151 176 2 38.30 27 37.54 52 39.87 77 102 127 152 177 3 37.96 28 38.53 53 39.48 78 103 128 153 178 4 39.07 29 36.05 54 37.18 78 104 129 154 179 5 36.23 30 37.70 55 39.82 80 1005 130 155 180 6 36.76 31 37.40 56 38.18 81 106 131 156 181 7 39.84 32 37.04 57 38.43 82 107 132 157 182 8 38.98 33 39.60 58 39.62 83 108 133 158 183 9 37.74 34 39.59 59 39.61 84 109 134 159 184 W 10 f 39.47 35 39.04 60 39.07 85 110 135 160 185 f 11 I, 37.45 36 38.98 61 39.88 86 111 136 161 186 12 37.47 37 38.48 62 38.85 87 112 137 162 187 13 37.85 38 38.14 63 37.11 88 113 138 163 188 14 37.89 39 37.29 64 37.59 89 114 139 164 189 15 37.72 40 38.88 65 37.66 90 115 140 165 190 16 39.07 41 39.61 66 39.52 91 116 141 166 191 17 38.39 42 39.86 67 37.63 92 117 142 167 192 18 36.97 43 38.31 68 37.96 93 118 143 168 193 19 39.15 44 35.28 69 38.07 94 ` 119 144 169 194 20 39.07 45 38.55 70 39.06 95 120 145 170 195 21 37.14 46 37.27 71 36.88 96 121 146 171 196 22 37.25 47 39.61 37.31 97 122 147 172 197 23 38.98 48 37.88 7.3 38.60 98 123 148 173 198 24 39.90 49 " 38.44 1 36.61 99 124 149 174 199 25 39.17 ' 50 37.99 g5 38.10 ' 100 125 150 175 200 Tol 956.15 Tol 956.38 Toe 958.75 To Tot To Tot Tot TOTAL LENGTH THIS PAGE 2871.28 DIRECTIONS: TOTAL JOINTS THIS PAGE : 75 FLOAT SHOE 2.25 FLOAT COLLAR 1.12 HANGER RKB 36.65 • • ConocoPhillips Casing Detail Well: CD4 -302 7" Casing Date: 6/14/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.40 FMC GenV Hanger 2.30 34.40 Jts 92 to 225 134 Jts 7" 26# L -80 BTCM Csg 5703.27 36.70 Weatherford /Gemoco Stage Collar 2.37 5739.97 Jts 2 to 91 90 Jts 7" 26# L -80 BTCM Csg 3827.09 5742.34 Halliburton Float Collar 1.29 9569.43 Jts 1 to 1 1 Jts 7" 26# L -80 BTCM Csg 42.58 9570.72 Ray Oil Tools " Silver Bullet " Float Shoe 2.08 9613.30 9615.38 7" Shoe @ 9615.38 8 3/4" hole @ 9626.00 *Baffle for Shut -Off plug @' (top of FC jt) 9526.35 8 -3/4" Hole TD @ 9,626' MD / 7,104' TVD 7" Shoe @ 9,615' MD / 7,096' TVD Total Centralizers: 61 Straight blade centralizer one per jt on jts # 1 -14 Straight blade centralizer one per jt on jts. 87 to 96 Straight blade cent. one per jt. on joint #'s 161,162,163 Straight blade cent.one on every other jt.# 165 to 223 235 joints in shed - 225 total jts. to run Last 10 jts. Out Perf above float collar from 9545' to 9547' ( 6 spf) Use Run & Seal pipe dope Average make up torque 8000 ft/Ibs Remarks: Up Wt - 385 k Dn Wt - 160 k Block Wt - 75k Supervisor: Lutrick / Hill / Lapiene • • ConocoPhillips CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4 -302 RIG: Doyon 19 TUBING DESCRIPTION: 7 ", 26# L -80 BTCM DATE: 06/14/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 42.58 26 41.95 51 43.04 76 43.37 101 42.24 126 42.48 151 43.58 176 43.57 2 43.08 27 43.41 52 42.58 77 41.45 102 43.41 127 41.87 152 42.16 177 42.99 3 39.75 28 43.50 53 43.41 78 42.37 103 36.94 128 43.44 153 40.03 178 42.64 4 41.75 29 41.86 54 43.29 79 41.95 104 41.36 129 40.74 154 42.14 179 42.41 5 42.92 30 43.45 55 42.94 80 43.13 105 43.14 130 43.47 155 41.56 180 42.35 6 43.10 31 43.55 56 43.47 81 43.50 106 42.53 131 39.96 156 43.08 181 42.67 7 43.45 32 41.03 57 43.35 82 43.10 107 41.98 132 43.35 157 43.52 182 43.01 8 42.49 33 42.09 58 43.52 83 43.44 108 37.68 133 39.53 158 43.58 183 42.81 9 43.58 34 38.99 59 42.77 84 41.86 109 42.34 134 43.49 159 43.46 184 42.83 10 42.65 35 43.03 60 43.51 85 41.73 110 41.90 135 43.11 160 41.77 185 43.46 11 41.34 36 43.46 61 41.10 86 42.34 111 43.58 136 38.95 161 42.40 186 43.03 12 43.45 37 43.45 62 43.49 87 41.89 112 42.56 137 41.48 162 40.50 187 42.02 13 43.46 38 43.60 63 43.00 88 43.16 113 42.92 138 43.57 163 42.10 188 42.69 14 41.84 39 42.84 64 43.41 89 42.67 114 40.90 139 43.48 164 42.56 189 43.46 15 42.72 40 42.62 65 39.60 90 41.08 115 42.76 140 43.47 165 42.86 190 40.93 16 43.46 41 42.64 66 43.01 91 43.46 116 43.56 141 43.46 166 43.58 191 43.46 17 40.68 42 43.52 67 43.47 92 42.02 117 41.86 142 42.77 167 43.54 192 42.86 18 37.19 43 40.92 68 43.43 93 42.89 118 43.57 143 42.73 168 43.43 193 42.60 19 41.15 44 43.48 69 42.82 94 43.54 119 40.97 144 43.46 169 42.32 194 43.46 20 42.23 45 42.77 70 43.45 95 43.52 120 42.99 145 41.68 170 43.54 195 42.98 21 43.53 46 43.47 71 42.04 96 43.51 121 43.46 146 42.95 171 43.44 196 43.43 22 42.95 47 42.19 72 43.43 97 42.93 122 43.57 147 42.23 172 43.36 197 43.44 23 43.45 48 43.46 73 41.30 98 42.12 123 43.47 148 43.45 173 43.47 198 36.66 24 40.16 49 43.47 74 41.74 99 43.69 124 40.33 149 43.57 174 42.67 199 42.88 25 40.99 50 41.95 75 41.35 100 43.21 125 43.57 150 43.44 175 43.21 200 42.24 Tot 1053.95 Tot 1066.70 Tot 1068.52 Tot 1067.93 Tot 1053.59 Tot 1062.13 Tot 1067.86 Tot 1064.88 TOTAL LENGTH THIS PAGE = 8505.56 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 2.1 FLOAT COLLAR 0.92 HANGER 2.4 RKB 34.59 0 • Conoc CASING TALLY PAGE: 2 of 2 WELL NUMBER: CD4 -302 RIG: Doyon 19 TUBING DESCRIPTION: 7 ", 26# L -80 BTCM DATE: 06/14/07 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 42.75 226 41.87 251 276 301 326 351 376 202 41.92 227 43.58 252 277 302 327 352 377 203 42.28 228 41.35 253 278 303 328 353 378 204 42.40 229 43.47 254 279 304 329 354 379 205 42.47 230 43.46 255 280 305 330 355 380 206 43.51 231 42.97 256 281 306 331 356 381 207 42.76 232 42.89 257 282 307 332 357 382 208 42.17 233 44-89 258 283 308 333 358 383 209 43.39 234 42.52 259 284 309 334 359 384 210 41.70 235 43498 260 285 310 335 360 385 211 43.48 236 261 286 311 336 361 386 212 43.28 237 262 287 312 337 362 387 213 43.43 238 263 288 313 338 363 388 214 43.46 239 264 289 314 339 364 389 215 41.20 240 265 290 315 340 365 390 216 42.54 241 266 291 316 341 366 391 217 43.02 242 267 292 317 342 367 392 218 41.31 243 268 293 318 343 368 393 219 42.12 244 269 294 319 344 369 394 220 43.52 245 270 295 320 345 370 395 221 43.28 246 271 296 321 346 371 396 222 42.91 247 272 297 322 347 372 397 223 42.21 248 273 298 323 348 373 398 224 42.72 249 274 299 324 349 374 399 225 43.55 250 275 300 325 350 375 400 Tot 1067.38 Tot 426.28 Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 1493.66 TOTAL LENGTH = 9999.22 DIRECTIONS: TOTAL JOINTS THIS PAGE = 35.00 TOTAL JOINTS = 235.00 AVERAGE JT = 42.55 • • • Note to File CRU CD4 -302 (PTD 2070560) May 31, 2012 Revised: June 22, 2012 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Additional Drilling Wastes within Well CD4 -302 Request ConocoPhillips requests approval to dispose of an additional 33,300 barrels of drilling waste in well CD4 - 302, increasing the total disposed in the well from 56,647 barrels to about 90,000 barrels. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at 2,335' true vertical depth subsea (TVDSS), near the base of a 410 -foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will lie within a radius of about 300' from the wellbore. 8. If injected wastes reach nearby wells Nanuk 1, CD4 -301, or CD4 -298, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from nearby wells Nanuk 1, Nanuk 2, Nanuq 5, CD4 -208, CD4 -209, CD4 -301, and CD4 -320. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided in Figure 1, below. The proposed disposal injection interval (disposal interval) in these wells lies in the Seabee formation within Section 19, T11N, R5E, UM and in Section 24, T11N, R4E, UM, which are 2 to 3 miles from the current boundary of the Colville River Unit. The 9 -5/8" surface casing shoes of these wells lie at about 1,753' to 2,335' TVDSS, near the base of a 410 -foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). The annulus open to the disposal interval extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to range from 2,335' to 3,693' TVDSS. The most • • CD4 -302 Additional Disposal June 22, 2012 Note to File Page 2 of 5 likely portion of the open annulus that will accept injected waste is a 60 -foot thick interval containing several 1- to 4 -foot thick beds of silty sandstone and sandstone that lie between about 2,395' and 2,455' TVDSS, which is just below the surface casing shoe. The aggregate thickness of these thin, potential receptor beds is about 17'. The silty sandstone and sandstone beds are separated by thin shale and claystone intervals. Beneath the disposal interval is a 55 -foot thick interval of shale, claystone and tuff that is continuous throughout the area. This interval, which lies between about 2,553' and 2,608' TVDSS, will provide lower confinement for any injected wastes. Underlying beds of shale and claystone will provide additional lower confinement as illustrated on Figure 2. , 17000 11000 Surface casing shoe marker -- 1 /4 -mile area of review ° ° °° N ° ° °o C D4 -320 PB 1 *tow Likely 9 Disposal - - 4070 4000 19000 Nanuq 1 Interval .14000 ' , NW .300D CD4 -298 3 1 4000 ♦ , 3 000 E0�4 f 1od�4r , ,30 i 700° E a000 i°,7!+: { 00 *700 000 { 1 5000 I 1 5000 1 / 1 . ' . Allow, . `�O p e ,.. CD4-302 a000\ 4°09 A\ >, , moon, a000 ... ..0 3 000 `4 °soon: ,000 MI .� AO °aoE :, .. ° °. .,,,„ CD4 -302 ;' 5000 CD4 -302 7 m* i i , 4 CD4 -208 5900 - Open 4'. t, .,. a " , �,��'` a000 , A nnulus 71 :m oq ° ° °° g Bono f i't CD4 -301 / CD4-209 -4M0 0 40 0 ' CD4 -320 / { 9000 - 5006 1 Nanuq 5 0' 500' 5000 _ -'- 23000 � ��%0 ,„„2 , soon Figure 1. CD4 -302 Index Map (all depths shown are feet TVDSS) (The magenta - colored line represents the path of the cross - section depicted in Figure 2.) The index map above presents the trajectories for all wells drilled from and near the CD4 drill site. Short tick -marks have been placed along each well trajectory at 500' TVDSS intervals and they are labeled every 1000' TVDSS. The surface location of each wellbore is represented by a gray circle that is about 100 feet in diameter, and the few bottom hole locations visible on the map are represented by 350 -foot diameter, gray circles. The locations and true vertical subsea depths of surface casing shoes for selected well bores are illustrated using green triangles and green text, and the calculated locations of the tops of cement for production casing strings or liners for these same wells are indicated by orange semi - circles. The portions of each well bore that lie between the surface casing shoe and the top of production string cement are assumed to be filled only with drilling mud, and are therefore possibly open to communication. The base of permafrost occurs at about 700' TVDSS in the CD4 drill site area. The base of permafrost lies about 1,600' above the top of the proposed injection intervals. • • CD4 -302 Additional Disposal June 22, 2012 Note to File Page 3 of 5 The shallow geologic section in the area surrounding CD4 -Pad contains methane gas. Records from the Nanuk 1 (located just off the index map above, about 3,800' southwest of CD4 -302), Nanuk 2 and Nanuq 5 exploratory wells record initial traces of methane at 460', 70', and 60' TVDSS, respectively. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.6 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log) were 1,890', 2,170' and 2,235' TVDSS, respectively. So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil shows observed in nearby wells Nanuk 1, Nanuk 2 and Nanuq 5 occur at 3,765', 4,710' and 3,770' TVDSS, respectively. The mud logging geologists rated these shows as being fair to good shows in quality. However, these oil shows occur more than 1,000' below the portion of the open annulus that will most likely accept the additional injected waste. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which govern the Nanuq and Nanuq - Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. The '/ -mile radius area of review (more correctly, a cylinder of review) surrounding the proposed disposal interval in CD4 -302 is highlighted on Figure 1 by two blue circles; one circle is centered at the location of the surface casing shoe, and the other is centered on the calculated top of cement for the production casing string. In CD4 -302, the disposal interval lies between 2,335' to 3,693' TVDSS, with the most likely waste- receiving zone between 2,335' and 2,455' TVDSS (see cross - section, below). Only Five wells open these same strata within the '/ -mile radius area of review. They are, from west to east, CD4 -209, CD4 -208, CD4 -301, CD4 -298, and Nanuk 1. Those portions of the Nanuq 5, CD4 -320 and CD4 -320 PB1 well bores that also cross through the area -of- review circle are situated below the disposal interval. These three wells will not be discussed further. The surface casing shoe of CD4 -209 lies at the western boundary of the area of review, and the open annulus below that casing shoe lies outside of the area of review. The casing shoe of CD4 -208 is located 1,270' away from the surface casing shoe of CD4 -302, which is about 50' inside the area of review. During 2007, the Commission approved CD4 -208 for disposal injection within the same geologic interval, and, as of October 2007, a total of 61,839 barrels of waste had been injected into CD4 -208. Disposal injection into CD4 -302 will likely not affect CD4 -208 due to the large separation distance (see discussion on pages 4 and 5, below). The casing shoes of CD4 -301 and CD4 -302 lie about 450' apart, and the closest approach to CD4 -301 by the open annulus of CD4 -302 is about 325'. Commission records suggest that the disposal interval of CD4 -302 is open to the CD4 -301 wellbore. The CD4 -301 wellbore may be affected by disposal injection in CD4 -302. However, the CD4 -301 daily drilling report of December 12, 2007 contains the following report concerning surface casing cementing operations: "Reciprocated pipe during job - full returns throughout — 125 bbls 10.7 ppg cmt returns to surface." If waste fluids injected into CD4 -302 reach the CD4 -301 annulus, there will be not be an open pathway to the surface. The casing shoe of CD4 -298 lies about 350' from the most likely injection interval in CD4 -302, and Commission records suggest that the disposal interval of CD4 -302 is also open to the CD4 -298 wellbore. But, Commission records from CD4 -298 indicate that the surface casing appears well cemented, with full returns noted, and pipe reciprocated throughout most of the cement job. If waste fluids injected into CD4 -302 reach the CD4 -298 annulus, there will be not be an open pathway to the surface. • • CD4 -302 Additional Disposal June 22, 2012 Note to File Page 4 of 5 Nanuk 1 is a plugged and abandoned, vertical, exploratory well located about 350' away from the top of the open annulus in CD4 -302. Several open -hole cement plugs were placed in Nanuk 1, two of which are significant here. Cement plug 3 extends from 4,110' to 3,246' TVDSS, and cement plug 4 extends upward from 1,861' into surface casing shoe to 1,575' TVDSS. The open annulus between the cement plugs, from 3,246' to 4,861' TVDSS, is filled with 10.2 pound - per - gallon, kill- weight mud. If waste fluids injected into CD4 -302 reach the Nanuk 1 annulus, there will be not be an open pathway to the surface. SW NE 2020420 2071500 2070560 1960570 501032041400 501032055700 501032054500 501032023800 ;: -- 1450' -- 450' - - - -- 325' CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK ARCO NANUQ 5 COLVILLE RIV UNIT CD4 -301 COLVILLE RIV UNIT CD4 -302 NANUK 1 2342 FSL 283 FEL 70 FEL 2882 FNL 2887 FNL 89 FEL 2627 FSL 869 FWL TWP: 11 N - Range: 4 E - Sec. 24 TWP: 11 N - Range: 4 E - Sec 24 TWP 11 N - Range: 4 E - Sec. 24 TWP: 11 N - Range: 5 E - Sec. 19 a ail. 0 t E 0 -500 r- _ -500 L } -1000 -1000 -1500 - -1500 r Surface ug 4 Casing - - -2000 Shoe \ : - - -2000 \� - Upper Confi ning = I nterval Likely - - x Di -I ) -2500 - Interval 2500 hole _.:: = { ; ` O pen 1 , ;:- . Cement Lower♦ s lugs -3000 I Beds A ,� Confining{ I } Open - — -3000 - nulus I 3 r 1 \ ; t 2 -3500 - - = ! _ IU -3500 - 4000 11735 � .,_ s. , -4000 TD = TD =21615 TD =9626 TD =7630 Figure 2. CD4 -302 Area: Structural Cross - section (Depth scale represents feet TVDSS; separation distance between wells is measured at the surface casing shoe) • • CD4 -302 Additional Disposal June 22, 2012 Note to File Page 5 of 5 The gamma ray curve recorded in CD4 -302 indicates that about 17' of net sand are present in the most likely disposal interval. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sandstone and siltstone porosity of 12% at this depth. Based on these values, the area impacted by the previous injection of 56,647 barrels lies within a radius of about 225' from the wellbore, assuming uniform, radial, piston -like displacement of the native formation fluid occurs. Injection of an additional 33,000 barrels of waste will expand the affected area to a radius of about 280' from the wellbore. Injected Fluid vs Affected Radial Distance CD4 -302 WelIbore (assumes 17' aggregate injection zone thickness and 12% porosity) 300 250 200 0 w 150 O 05 100 Q 50 0 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000 90,000 Amount of Injected Fluid (barrels) Figure 3. CD4 -302 Area Likely Affected by Annular Injection The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700' of permafrost, and is bounded above and below by continuous layers of claystone and shale. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. Injected wastes may reach nearby wells Nanuk 1 or CD4 -301, but if they do, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the disposal strata. I rec• I mend approving this additional annular disposal up to the limit of 90,000 barrels. ,_, /O� . . . , teve4 ' 2- 2- / Senior Petroleum Geologist T (DfLur• j. ","002_, / rt, • • Note to File CD4 -302 (207- 056...312 -233) Colville River Unit (Nanuk - Kuparuk) ConocoPhillips Alaska, Inc Request Increase allowed annular disposal volume from 70,000 to 90,000 barrels. Recommendation Approve annular disposal of up to 90,000 barrels of fluid in CRU CD4 -302. Discussion ConocoPhillips Alaska Inc. ( "CPAI ") has made application to increase the allowed disposal volume in the 9 -5/8" x 7" annulus of the subject well from 70,000 barrels to 90,000 barrels of fluid. Annular disposal had been previously approved for this well in May 2009. This document presents pertinent information supporting this request and recommends approval of ConocoPhillips' request. - -As authorized by sundry 309 -167, CPAI has disposed of a total of 63,000 bbls (as of 6/25/12) into the 9 -5/8" x 7" annulus of this well. They have not reported any problems. - -CPAI is making this request due the unavailability of other surface casing annuli on CD4 pad. - -An additional pump in test was performed on 5 -23 -12 with results showing injectivity well below the surface casing LOT of 18.1 ppg EMW. The Calculated bottomhole pressure for injection was 16.3 ppg EMW using a diesel gradient to the casing shoe at 2391 ft. - -A log analysis performed by Steve Davies is attached. As noted in his analysis, there are no USDWs in the area. He recommended granting CPAI's request. Based on examination of the submitted information and analysis, 1 concur and recommend approval of ConocoPhillips' request to increase the allowable disposal volume in CD4 -302 to 90,000 bbls Guy S artz Sr. Petroleum Engineer June 25, 2012 G:\AOGCC\ Common \tommaunder \Well Information\By Subject \Annular Disposal\ 120625- - -CD4- 302 increase.doc • RD \‘' SEAN PARNELL, GOVERNOR (DJ LW Li ti ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION C OHM S S I ON ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Drilling Engineering Supervisor 5 D ConocoPhillips Alaska, Inc. O f P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD4 -302 Sundry Number: 312 -197 Dear Mr. Alvord: JUL 3 . 6U1 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this / day of June, 2012 Encl. I I Iii • • . I , ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 RECEIVED May 29, 2012 MAY 3 0 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 AOGCC Anchorage, Alaska 99501 -3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4 -302 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD4 -302 (sundry permit # 309- 167 dated 5/20/2009) be re- permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. The sundry permit #309 -167 increased the maximum volume of waste to be disposed of in this well to 70,000 bbl due to the remote location and limited available annuli on CD4. CD4 -302 was last used for annular disposal in January 2010. The total volume of disposed waste in this well is 56,647 bbls. Therefore, this application is to re- permit the well to utilize the remaining 13,000 bbls of allowable' injection volume. On 5/23/2012 an annular leakoff test (LOT) was performed with diesel. Initial annular LOT of 16.3 ppg occurred at a lower equivalent mud weight than the casing shoe test (18.1 ppg LOT). Therefore, we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. The other wells not yet permitted for annular disposal are either in too close a proximity to exploration wells or are not good annular disposal candidates. This leaves us with the choice of re- permitting a previously used annular disposal well to utilize the remaining allowable injection volume. Of the wells on the CD4 pad previously used for annular disposal, CD4 -302 is a strong candidate for utilizing the remaining allowable injection volume. Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized and additional risks of spillage and vehicular accidents are possible. For further details please reference the original annular disposal permit for CD4 -302, approved on September 6, . 2007. Attached is an updated plot showing all the wells within quarter mile of the surface shoe on CD4 -302 and the . updated annular disposal transmittal form. If you have any questions or require further information, please contact Daniel Bearden at 263 -4864; Chip Alvord can also be reached by calling 265 -6120. . Si drely 11 A D " 1 earden Drilling Engineer cc: CD4 -302 Well File Liz Galiunas ATO -1500 • , ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhi I I i ps Telephone 907 - 276 -1215 Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 • STATE OF ALASKA r RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 3 0 2012 ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 AOGCC 1. Operator 3. Permit to Drill Name: Number: 207 -056 ConocoPhillips Alaska 4. API Number: 50- 103- 20545 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4 -302 • 6. Field: Colville River Field - 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD4 -208, CD4 -209, CD4 -301, Nanuk 1 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 56,647 bbls (Jan 2010 last injection) - densities range from diesel to 12# /gal 2249 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 13,000 bbls. v , Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with 16. Estimated start date: the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1- Jun -12 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 151 Cement Bond Log (if required) ❑ FIT Records w /LOT Graph Surf. Casing Cementing Data ❑ Other ❑ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. - D2 1 Ll.t fV 4 € G ittea < Signature: `�!�'L`I�i Title: gwpea -LA ti r ■ G!� 4k L. t ik�v� voS- b24+ Printed f0 a._ Phone Name: Chip Alvord Number: 265 -6120 Date: 5/29/2012 Commission Use Only Conditions of approval: e 4 / /Gj n w/1-1,1 26 .44-e 25 0 FO LOT review and approval: 0 4 " .6 " Z- Subsequent form required: /C) .` 4 - 23 Approval number: APPROVED BY r� Approved by: COMMI THE COMMISSION Date 4 / ` ( F ; ° '' $ R .') i, t r/ INSTRUCTIONS N REVERSE I I Sub it in Dupli ate ry \" / 6I 0Z_ �. • • Annulus Disposal Transmittal Form - Well CD4 -302 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD4 -302 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian horok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg /1. (Ref. AOCiCC Conservation Order No. 443, March 15. 1999) 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud. completion fluids. diesel. formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12;-Vgal. The maximum volume of disposal waste allowed is 70,000 bbls. Of this amount, 56.647 bbls has already been pumped. Therefore. the maximum volume to be pumped for this re- permit application is 13,000 bbl. 6 A description of any waste sought to be determined as drilling Cement rinsate. mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipollent after producing drillin ,completion fluid (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during ,, 4 casing shoe during annular disposal operations and disposal operations is 2249 psi. See attached calculation calculations showing how this value was determined. pave. o (�- 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports. LOT FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT /FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4 -213B _ will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. ' ' • • 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) version 1.0 - Jan X05 Well CD4 -302 Assumptions Date 5/25/2012 Maximum injection pressure of 1,128 psi "' Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi /ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi Ct Maximum Fluid Density to avoid Burst of Surface Casing ti Pburst85 o = PHydrostatic + PApplied - PFonnation 4,888 = ( 2,390 * 0.052 * MWmax ) + 1128 - ( 0.4337 * 2,390 ) MWmax = 38.6 ppg 2,390 TVD Surface Casing String Size 9.625 in .• Weight 40 ppf d Grade L 80 rburst100% 5,750 psi P burst85 /o a 4,888 psi ti Depth of Shoe 2,390 ft FIT /LOT @ Shoe 18.1 ppg or 2,249 ps FIT/LOT for Annulus 16.3 ppg .� G d T slz34 z Max Surf. Pressure 1,128 psi TOC Est. @ 4,740' MD 3,749' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,599 = ( 3,749 * 0.052 * MWmax ) + 1,128 - ( 0.0700 * 3,749) - 1,000 Z Z MWmax = 24.3 ppg 4. 5 "Tubing 2nd Casing String Size 7 in 7,096 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 3,749 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,128 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT /LOT Pmax allowable = ( 2,390 * .052 * 18.1 ) Pmax allowable = 2,249 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4 -302 I Rig: Hot Oil Date: 1 5/23/201 I Volume Input Pump Rate: Drilling Supervisor: 1 -Pump used: 0.1000! 0.5 ■ Type of Test: ■ Pumping down Casing Test Pressure Integrity Test Hole Size: v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I IFt IFt-MDI 2 391IFt -TVDI IFt -MD 1 IFt -TVD _ Bbls psi Min psi Bbls psi Min psi Casinq Size and Description: v 0 0 670 0 1190 Changes for Annular Adequacy Test 1 Pressure IntegrityTest 1 0.5 770 0.25 1160 outer casing shoe test results in comments Mud Weight: ppg 2 1 940 0.5 1155 Description references outer casing string. Inner casing OD: In. 3 1.5 1000 1 1140 � that drilled below outer casing. 4 2 1120 1.5 . t i mated TOC for Hole Depth. 5 2.5 1130 2 1125 Enter inner casing OD at right ] Desired PIT EMW: _ 16.3 ppg 6 3 1130 2.5 1120 Estimates for Test: 1128 psi 0.4 bbls 7 3.5 1125 3 1115 v 8 4 1125 3.5 1115 EMW = Leak -off P , - ssure + Mud Weight = 1128 + 18 PIT 15 Second 9 4.5 1125 4 1115 0.05 - x TVD 0.052 x 2391 Shut -in Pressure, psi 10 5 1125 4.5 1110 MW at 2763 Ft -MD (2391 Ft -TVD) = 16.3 1160 15 _. 3 1125 5 1110 20 6 1125 5.5 1105 • r' 25 6.5 1125 6 1105 1100 �� 30 1 6.5 1105 ' 7.5 1125 125 7 1100 8 1125 7.5 1100 8.5 1125 8 1100 w 9 1130 8.5 1095 Ce 900 9.5 1135 9 1095 rn 10 1135 9.5 1095 13 1150 10 1095 16 1160 / 19 1170 700 22 1180 25 1190 500 0 3 5 8 10 13 15 18 20 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume CASING TEST tLEAK -OFF TEST Pumped Bled Back Pumped Bled Back 0.0 Bbls Bbls 25.0 Bbls 1.0 Bbls Comments: The 7.2 MW is calculated basedl on 56 bbls of diesel with the rest of the annulus ovate:. X18 3' TVD diesel i 1853'TVD- 2391'TVD is water) Initial annular LOT was 16.3 ppg and the Casing shoe test was 18.1 ppg Max pressure 1 .8 *Si r / psi SURFACE CASING SHOE SEPARATION FROM CD4 -321 CD4 -321 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 375795.28 5956945.38 uistance Ann. from Surface csg. Surface csg. Surface Details @ Disp. Ann. Object Shoe X Shoe Y Surf LOT casing TVD Annular Wells AOGCC** Permit # Permit Date Source well Vol. Start Date End Date well* Coord. Coord. (ppg) (ft) LOT (ppg) Comments CD4 -07 n 1430 376700.4 5958052.5 16.7 2396 15.4 C04 -16 954 376571.7 5957499.3 18.1 2388.5 17.90 'ot or annu ar •isposa , .ue to proximity to 'anuq CD4 -17 ©1_ _ - ■-_r 679 376416.3 5957221.0 18.1 2386.93 16.2 , ot or annu ar •isposa , .ue to proximity to "anuq 3 D4 -318a, D4- 2', D4 -214, C04 -208 y 306 -183 CD4- 321,C04 -211 61839 7/3/2006 1/4/2007 2344 378134.12 5956792.58 16.3 2440.26 14.4 volume extension to 70000 bbl, permit #306 -266 CD4 -209 y _ 2175 377935.02 5957333.89 14.7 2376.79 17.5 of o n r anu ar isposa CD4 -210 y 111111...- IM_" 1752 377547.47 5956963.14 18.0 2385.97 17.3 CD4 -211 y 306 -392 . /t5r2ue'. D4 -302, C04 - 6/20/2007 `. 1652 377354.32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test @18.4 ppg PIWPWPPIt or annu ar .isposa . ' igh ' nn test •ro .a. y ice p ug, CD4 -213 y 1687 377441.38 5956577.89 2400.5 21.40 will retest if needed CD4 -214 y �- r_ 1221 377016.49 5956949.56 17.3 2400.8 17.6 `ot or annu ar •isposa CD4 -215 © -- 967 376762.06 5956914.11 17.6 2400.4 17.50 `ot or annu ar .isposal 307 -257 / 9/6/2007 Extend( 000 (64,000 bbls) 5/20/2009. � -302 y 309 -167 5/20/2009 CD4 -2138 . 10/21/2007 1/1 /2010 3481 379247.67 5957393.4 18.1 2390.43 17.10 New Ali , !23/20 , 2 CD4 -304 n 1772 377304.4 5957874.3 2391 17.8 Not for Annular Disposal CD4 -306 y 307 -258 9/6/2007 C04 -304, 9 -4 28330 9/11/2007 10/21/2007 1863 377262.19 5958093.22 18.0 2376.29 70 CD4 -318 y 306 -181 5/26/2006 CD4 - 209, 004 - 320 942 5/31/2006 8/2/2006 724 376138.31 5956308.17 18.2 2375.32 17.1 Ina. e to pump- 1 pumping CD4 - 208, C04f8, C04 - 20 2 9, CD4 -319 y 305 -373 12/9/2005 CD4 -320 ® 12/14/2005 7/2/2006 1799 377174.72 5955790.44 18.4 2396.47 16.1 CD4 -320 y /- 2418 377915.36 5958108.91 - ' 2387.33 17.8 of f1� or annular disposal CD4 -321 y 306 -393 9/23/2010 D4 -306, 004 - 322 3111. 7/14/2007 8/20/2007 0 375795.28 5956945.38 18.0 2385.47 16.3 xtension permit i e. or 1,1111 :: CD4 -322 y 307 -293 10/25/2007 004 - 301, 004 - 30832 12/8/2007 "008 795 375674.64 5957731.19 18.0 2385.44 16.8 Nanuk 1 n �� -- Exploration P &A'd Nanuk 2 n --_ -� I I I ��- I I -lw- Exploration P &A'd Nanu. 3 �� Exploration, X -Y location calculated at 2400 TVD, NOT 1299 377015.63 5957391.42 11.8 1774.97 the surface shoe depth Nanu. 3 2400" TVD -_- -� 828 376499.3 5957380.8 Nanu. 5 2627 378326.61 5956241.68 14.9 2393.75 15.1 Not for annular disposal � E _ CD4 -301 3747 379541.0 5957028.4 14.8 2387 13.5 CD4 -05 1493 377233.4 5957348.0 18.2 2388 16.5 CD4 -25 1371 376993.5 5956278.8 17.8 2393 15.9 CD4 -26 n 979 376757.1 5956765.1 18.0 2389 17.2 CD4 -24 1726 377321.7 5956140.6 16.2 2389 15.1 Planned CD4 -298 3908 379658.20 5957535.10 2390 13.9 CD4- 03wp04 2587 378180.32 Not for annular dis osal CD4- 27w•07 1492 376803.42 .177d4 o. .;.: Not for annular disposal Lateral distance in feet, between surface casing shoes, in the X -Y plane iik, As of April 21, 2008 ote that this sheet is not the definitive record for annular disposal volumes Project: Westem North Slope ConocoPhillips Site: CD4 Nanuq Pad CD4 -302 Well: CD4 -302 Wellbore: CD4-302 CD4 -302 Quarter Mile View GOa -J0 /��ao G A''1.0� I — -- Ix p a D A G 1200 A ‘j--11011111 1 Dao 60 i - 10 • " x 131 95/8" x 12 1 /4" 9 5/8" , + 20 ,400, .-� C C p4-30 .•... 7 i I . T ■ ` 9 • 121/4 "'TD • ..- - " O U � q co _ ....1.4 � 1� . • 9 __. 5/8" . _ te - • I. ^ + 1 II_ % r�� S/E" x 12 1/4" Et tom' � � , • x 121/4 t VP 0 GD „ " 9-sir x 12-1!4" J 05 2 1/4" � x 1 /4j x 12 1/4" 1 _ • i s . ,. J,l }' +' 10� ��j��4 i " ` 9 518" x 121/4" I 0 G A•Z ,f• < 4" " x 13- 1/2" �/ O . V� ii D �� p4-301 5/E" x 12 114" A , % i S'� ( 4.91P Y a 1 D �� E 3/4" GD / 9 5IE" x 121/4" a a5 -180 1 - _ a • �R∎ 11N ■ G DA CD4 -31 CD . I CD4 3 . I `_ -1810 -12000 0 600 1200 1800 2400 3000 West( -) /East( +) (600 ft/in) • • 'conoccPhNI Ii ps cash, Detail VeII: CD4 -302 9 SC8 "Surface Casing Date: 6/712007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.65 FMC Gen V Hanger 2.26 36.65 Jts 3 to 71 69 Jts 9 -518" 40# L -80 BTC Csg 2644.03 38.91 Halliburton Float Collar 1.15 2682.94 Jts 1 to 2 2 Jts 9.518" 40# L -80 BTC Csg 76.63 2684.09 Ray Oil Tools "Silver Bullet" Float Shoe 2.17 2760.72 2762.89 _ 0 12 114" Surface Hole 2772.89 hole hi. 97' TYD csg sho '9' - 2.389' TVO TOTAL BOVSPRING CENTRALIZERS - 41 1 per jt on Jt 11 - #13 (stop ring on Jt 11 & 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67, 69 75 joints in the pipe shed. 71 jts to run - Last 4 jts out Use Best - o - Life 2000 pipe (lope All joints drifted - 8.781" MU torque ' 8600 IUlbs Remakts. Up Wt -165k DnWt -144k Block Wt -75k Swermisco' L7 affh= /4. 69'96 eNa a3JNVH 611 dVllOO 1 ?O1J 932 3OHS 1'dOl3 9L ° 39Vd SIH1 SINIOP 1V1O1 :SNOI1O3H1O 8ZlL8Z SIH1 H19N31 1V1O1 101 101 101 101 1 61'866 101 86 101 61966 l o 1 006 ! ®■ 061 !®— ii 018E QEEN '�IEEN® 661 ! ®!ECI!EISIlEPEZEPQICIENCI 06'66 ID 861 ! ®_O®!O 09'86 QEEEND L _ ®!_ ®!®!ED®©��® 661 ! ®!c!®!® 90'66 Eg �ep L ®ap 461 !CI!III !E9!1 L0 86 ISPEEEIREPIESP® 661 !C1■®■011lELPEZENIVEENECIIIMPEIP 661 INNICIIIIIIMEMI!EPEINEIIIIMPIDEEMPEDEINEP 181 !�! ®!�lEP�EDIEP L0' Ep 061 •E11! 041 !®!EIPEMP® CPEENEP 681 !IIII!ES!OlEPEENIMPIEMPESEIBRIP 881 ! ®!ES! ®! ®EPIIIMPIPENIP® L81 ! ®■®!®■11011MDEP 84' IMPERIPEP 981 ! ®! ®! ®!Ci ® EVESEIPEP 681 MIIIP 091 ! ®■1:11!® 1066 @ 4066 ®EZIPEP 481 ! __® __ __ ��_� £81 ! ®! ®lLii7lED�ED 0966 ®EIEN© Z81. ! ®! ®!EYlEP ISEPI 40L£ ®EISPD 181 ! ®!®!OlOIIMIND 04L£ EPETIN® 081 ®! 061 !1:19! @EPI OL IMPITIPEIP 611 ! ®■131!CMIIIIPED_IN 6090 ID 1060 D 811 !®!MIlECP�l� £980 ; MEMO 111 !®!EI∎E3lEP ED 49L£ 0£'86 EP 911 161 961 101 91 99'90 16 60'60 93 00'86 1aa j ory 1aa j ory 1aa j ory 1aa j ory 1aa 3 ON 1 j ory 1aa j ory Iaa j ory g uwnlo0 1 uuinloO 9 uumloO g uwnloO 1 uumlo0 E uumlo0 Z uwnloO 1 uWnlo3 101 L0190 :31VO 318 08 10* . _816 6 :NOI1d183S3O 9NISVO B1 uoioO =9161 Z0E *O0 1:1381 113A Jo 1 :39Vd A11V1 9NISVO • • • • ConocoPhillips Casing Detail Well: CD4 -302 7" Casing Date: 6/14/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.40 FMC GenV Hanger 2.30 34.40 Jts 92 to 225 134 Jts 7" 26# L -80 BTCM Csg 5703.27 36.70 Weatherford /Gemoco Stage Collar 2.37 5739.97 Jts 2 to 91 90 Jts 7" 26# L -80 BTCM Csg 3827.09 5742.34 Halliburton Float Collar 1.29 9569.43 Jts 1 to 1 1 Jts 7" 26# L -80 BTCM Csg 42.58 9570.72 Ray Oil Tools " Silver Bullet " Float Shoe 2.08 9613.30 9615.38 7" Shoe @ 9615.38 8 314" hole @ .00 "Baffle for Shut -Off plug @' (top of FC jt) 9526.35 8 -3/4" Hole TD @ 9,626' MD / 7,104' TVD 7" Shoe @ 9,615' MD 17,096' TVD otal Centralizers: 61 Straight blade centralizer one per jt on jts # 1- Straight blade centralizer one per jt on jts. 87 to 96 Straight blade cent. one per jt. on joint ' Straight blade cent.one on every other j..r, 235 joints in shed - 225 total jts. to run Last 10 jts. Out Perf above float collar from 9545' to 9547' (6 spf) Use Run & Seal pipe dope Average make up torque 8000 ft/lbs Remarks: Up Wt - 385 k DnWt- 160k Block Wt - 75k Supervisor: Lutrick / Hill / Lapiene ConocoPhillips CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4 -302 RIG: Doyon 19 TUBING DESCRIPTION: 7 ", 26# L -80 BTCM DATE: 06/14/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 42.58 26 41.95 51 43.04 76 43.37 101 42.24 126 42.48 151 43.58 176 43.57 2 43.08 27 43.41 52 42.58 77 41.45 102 43.41 127 41.87 152 42.16 177 42.99 3 39.75 28 43.50 53 43.41 78 42.37 103 36.94 128 43.44 153 40.03 178 42.64 4 41.75 29 41.86 54 43.29 79 41.95 104 41.36 129 40.74 154 42.14 179 42.41 5 42.92 30 43.45 55 42.94 80 43.13 105 43.14 130 43.47 155 41.56 180 42.35 6 43.10 31 43.55 56 43.47 81 43.50 106 42.53 131 39.96 156 43.08 181 42.67 7 43.45 32 41.03 57 43.35 82 43.10 107 41.98 132 43.35 157 43.52 182 43.01 8 42.49 33 42.09 58 43.52 83 43.44 108 37.68 133 39.53 158 43.58 183 42.81 9 43.58 34 38.99 59 42.77 84 41.86 109 42.34 134 43.49 159 43.46 184 42.83 10 42.65 35 43.03 60 43.51 85 41.73 110 41.90 135 43.11 160 41.77 185 43.46 11 41.34 36 43.46 61 41.10 86 42.34 111 43.58 136 38.95 161 42.40 186 43.03 12 43.45 37 43.45 62 43.49 87 41.89 112 42.56 137 41.48 162 40.50 187 42.02 13 43.46 38 43.60 63 43.00 88 43.16 113 42.92 138 43.57 163 42.10 188 42.69 14 41.84 39 42.84 64 43.41 89 42.67 114 40.90 139 43.48 164 42.56 189 43.46 15 42.72 40 42.62 65 39.60 90 41.08 115 42.76 140 43.47 165 42.86 190 40.93 16 43.46 41 42.64 66 43.01 91 43.46 116 43.56 141 43.46 166 43.58 191 43.46 17 40.68 42 43.52 67 43.47 92 42.02 117 41.86 142 42.77 167 43.54 192 42.86 18 37.19 43 40.92 68 43.43 93 42.89 118 43.57 143 42.73 168 43.43 193 42.60 19 41.15 44 43.48 69 42.82 94 43.54 119 40.97 144 43.46 169 42.32 194 43.46 20 42.23 45 42.77 70 43.45 95 43.52 120 42.99 145 41.68 170 43.54 195 42.98 21 43.53 46 43.47 71 42.04 96 43.51 121 43.46 146 42.95 171 43.44 196 43.43 22 42.95 47 42.19 72 43.43 97 42.93 122 43.57 147 42.23 172 43.36 197 43.44 23 43.45 48 43.46 73 41.30 98 42.12 123 43.47 148 43.45 173 43.47 198 36.66 24 40.16 49 43.47 74 41.74 99 43.69 124 40.33 149 43.57 174 42.67 199 42.88 25 40.99 50 41.95 75 41.35 100 43.21 125 43.57 150 43.44 175 43.21 200 42.24 Tot 1053.95 Tot 1066.70 Tot 1068.52 Tot 1067.93 Tot 1053.59 Tot 1062.13 Tot 1067.86 Tot 1064.88 TOTAL LENGTH THIS PAGE = 8505.56 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 2.1 FLOAT COLLAR 0.92 HANGER 2.4 RKB 34.59 • ConocoPhillips CASING TALLY PAGE: 2 of 2 WELL NUMBER: CD4 -302 RIG: Doyon 19 TUBING DESCRIPTION: 7 ", 26# L -80 BTCM DATE: 06/14/07 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 42.75 41.87 251 276 301 326 351 376 202 41.92 43-58 252 277 302 327 352 377 203 42.28 41.35 253 278 303 328 353 378 204 42.40 43A7 254 279 304 329 354 379 205 42.47 230 43-46 255 280 305 330 355 380 206 43.51 231 42.97 256 281 306 331 356 381 207 42.76 232 42.89 257 282 307 332 357 382 208 42.17 41-09 258 283 308 333 358 383 209 43.39 42.52 259 284 309 334 359 384 210 41.70 4386 260 285 310 335 360 385 211 43.48 236 261 286 311 336 361 386 212 43.28 237 262 287 312 337 362 387 213 43.43 238 263 288 313 338 363 388 214 43.46 239 264 289 314 339 364 389 215 41.20 240 265 290 315 340 365 390 216 42.54 241 266 291 316 341 366 391 217 43.02 242 267 292 317 342 367 392 218 41.31 243 268 293 318 343 368 393 219 42.12 244 269 294 319 344 369 394 220 43.52 245 270 295 320 345 370 395 221 43.28 246 271 296 321 346 371 396 222 42.91 247 272 297 322 347 372 397 223 42.21 248 273 298 323 348 373 398 224 42.72 249 274 299 324 349 374 399 225 43.55 250 275 300 325 350 375 400 Tot 1067.38 Tot 426.28 Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 1493.66 TOTAL LENGTH = 9999.22 DIRECTIONS: TOTAL JOINTS THIS PAGE = 35.00 TOTAL JOINTS = 235.00 AVERAGE JT = 42.55 • • Annulus Disposal Transmittal Form - Well CD4 -302 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD4 -302 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, March 15. 1999) 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. The maximum volume of disposal waste allowed is 70,000 bbls. Of this amount, 56,647 bbls has already been pumped. Therefore, the maximum volume to be pumped for this re- permit application is 13,000 bbls. • 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 225 psi. See attached calculation calculations showing how this value was determined. page. 14-'1 1 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4 -213B will be generated. - . 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. . • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.O- Jan '05 Well CD4 -302 Assumptions Date 5/25/2012 Maximum injection pressure of 1,233 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi /ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi /ft Header Pressure (for wells on gas lift) 1,000 psi GU Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% = PHydrostatic + PApplied - PFormation 4,888 = ( 2,390 * 0.052 * MW ) + 1233 - ( 0.4337 * 2,390 ) v, N c MWmax = 37.7 PPg Z . . TVD Surface Casing String Size 9.625 in Weight 40 ppf CI.) d Grade L 80 Y a 5,750 psi pp burst100 /o Pburst85% '7, R burst85 4,888 psi /o U Depth of Shoe 2,390 ft FIT/LOT @ Shoe 18.1 ppg or 2,249 psi FIT/LOT for Annulus 17.1 - ppg ' ° o c I Max Surf. Pressure 1,233 psi _ r *N TOC Est. @ 4,740' MD l` 3,749' TVD • Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader • 4,599 = ( 3,749 * 0.052 * MW ) + 1,233 - ( 0.0700 * 3,749) - 1,000 Z X MWmax = 23.7 ppg 4.5 "Tubing 2nd Casing String Size 7 in G 7,096 TVD Weight 26 ppf Grade L 80 Ycollapse100% 5,410 Psi Pcollapse85% 4,599 psi Top of Cement 3,749 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,233 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,390 * .052 * 18.1) • Pmax allowable = 2,249 .psi ✓ This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". SUPERSEDED O m . m m o 3 ' PRESSURE * m m N 0 o XI _y 9 Z rj o 0 0 o II j - Irt N to c 3 °m="0 V? 0 0 0 0 0 m " 0 Q cc O y 6 CD -0 • • D) o = fD S Q 3 O o 0 g o 0. 0 N N "n K 5 --4 RR bA CO 2a -, CD 0 N —� o O y M O° 7 ii" 0 N w y ' SD o Ex-1 pm m - I • W 0 _ y 0 0 N 3 m= N Z C -0 ° c C N C W 7 y 'S c) pf CO CO .--1- " - c p -D• c Csi+ m N+ ?• n su w N N 0 � r N G~'� g a a a N O 0 o. W c m rt p T W W '77 c �i O >31 r•F 111 7 / N y co rt (1 O O D • C C 03 -I k cO. N y n N (.3 O- N o 0 S rt =.5•o nD 0 o q N II y 3 rt W 0 m. . Q f CO = = Ln - TI en g O = 4 c o. N IG D I -. 0. 0, m o r 8° S (D L3' p O m 0 s N O '2 N 0 co O T v N O W 4 -' -1 II >< - co co • 0 , m N W -� r► = N -1 0 C _.0 � (0 W t O 3 N , o C') CD - m (00 0 0 0 m .+ w + y N a (D Z '� N o 1 O N 3 3 O � Q N V/ N N o �� m tQ a) N . . o T G' 03 ^ ID K O c o O 'V ! C N 0 N �o Q0,. CA 0� w o. a 2 m p c /2 -n * p r CD = 0) rt = ' c m 0 3 m o = g.71 NO) •..IVY 00 3 m CO E 00 C 0 3 T ) N O 1:$ 'C ' CD N D N � e' y� Na m p) • CD O f_ O y (D Co 3 W CO w 1 1 y a G 11 CD 0 e N n (n 1 0 - 1 —I .0-.. m a o • o= o s= c N O N 3 m 3 = cD i. -. O'0. O N •O N c (1 y 3• oo c E -I _ _ (D O G. O 0(010 01 0(000 V 0)01 - W N -0 C ...I. O W c 6 a 0.1 C) ID y u+ C y , cn 0 N• N W 1 • p m a C N N - -+ (0 00 V 0) 01 . W N -• 0 Cr C O � c O (1N(o0) W O(.1(o(1 V (1 0) 01 CS) 01 (7J W (.1 (1 - (nO CD 3 (D Oa 3 , ,,, - la m c IS . o - -- O (0 V 0) (1)O -1 N (o 00V0)(10)o 0) IVNNNNN N r r. NW WN O.V V O 0 00000(101001(101 101(1 01 (1 (31(1 (1000 0000 ► c (D 03 W _, (0 CO V 0) 01 -P W N -• 0 IV 1 3 o . O O(31(o(3100a1 .1 10)(31 a 0 133,01 W (1N01 •- (31(10 C 3 rt Ca W C F. I9 0 co N n m j -_ _ j _ -- - _, _,- N .. O 0 O O _ . (0 (0(0(00 0 0000 001 NN Co 0 1 00 ' 01010101000010101 0 00101 (31 0(1 (31 0(31 00 1 • • • Note to File CRU CD4 -302 (PTD 2070560) May 31, 2012 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Additional Drilling Wastes within Well CD4 -302 Request ConocoPhillips requests approval to dispose of an additional 13,000 barrels of drilling waste in well CD4 - 302, increasing the total disposed in the well from 56,647 barrels to about 70,000 barrels. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at 2,335' true vertical depth subsea (TVDSS), near the base of a 410 -foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will lie within a radius of about 250' from the wellbore. 8. If injected wastes reach nearby wells Nanuk 1 or CD4 -301, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from nearby wells Nanuk 1, Nanuk 2, Nanuq 5, CD4 -208, CD4 -209, CD4 -301, and CD4 -320. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided in Figure 1, below. The proposed disposal injection interval (disposal interval) in these wells lies in the Seabee formation within Section 19, T11N, R5E, UM and in Section 24, T11N, R4E, UM, which are 2 to 3 miles from the current boundary of the Colville River Unit. The 9 -5/8" surface casing shoes of these wells lie at about 1,753' to 2,335' TVDSS, near the base of a 410 -foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). The annulus open to the disposal interval extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to range from 2,335' to 3,693' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 60 -foot thick interval containing several 1- to 4 -foot thick beds of silty sandstone and sandstone that lie between about 2,395' and 2,455' • • CD4 -302 Additional Disposal May 31, 2012 Note to File Page 2 of 5 TVDSS, which is just below the surface casing shoe. The aggregate thickness of these thin, potential receptor beds is about 17'. The silty sandstone and sandstone beds are separated by thin shale and claystone intervals. Beneath the disposal interval is a 55 -foot thick interval of shale, claystone and tuff 1 that is continuous throughout the area. This interval, which lies between about 2,553' and 2,608' TVDSS, will provide lower confinement for any injected wastes. Underlying beds of shale and claystone will provide additional lower confinement as illustrated on Figure 2. 17000 . 100° Surface casing shoe marker l {�p,1,1 ccmcm um! rr 1 /4 -mile area of review /\ x'1°000 x10000 CD4 - 320 PB1 11 Likely N o° "° ,,°° i Disposal ` 4000 Interval 4000 19000 Nanuq 1 4000 9000 - -3O ' CD4 -298 00 30 U t 40°0 3 ©0�, / �.0 �'�w 4 V r i� 0 i.0 #. lir I. 3000 w. : 7000 8000 '.. 5 000 0 .. . f � 1 ��::. 500 �. 6000 9 '10 ' 00'' �_ { ♦�°°a, 3Q" 4'AinD oo° moo 1 0 D4..'O,. %0001 4000000 — .... 1 �ti '44 - 2000 9000 000 ' M CD4 -208 „" CD4 -302 ` . e 5000 C D4 -302 V ik ,4000 ,600° • 1 1,,, , Open / 800,p,. �� _ -4 ,00 / / I �. • 409° Annulus 50405000 6000 / 7000 f- CD4 -301 i i MOO 'me- 4 o°° 4 ° gin 7000 4000 CD4 -320 l 4"°°9-4000 5000 l� °° Nanuq 5 0' 500' 5009 23000 - e� <: 9°48b0 �� Figure 1. CD4 -302 Index Map (all depths shown are feet TVDSS) The index map above presents the trajectories for all wells drilled from and near the CD4 drill site. Short tick -marks have been placed along each well trajectory at 500' TVDSS intervals and they are labeled every 1000' TVDSS. The surface location of each wellbore is represented by a gray circle that is about 100 feet in diameter, and the few bottom hole locations visible on the map are represented by 350 -foot diameter, gray circles. The locations and true vertical subsea depths of surface casing shoes for selected well bores are illustrated using green triangles and green text, and the calculated locations of the tops of cement for production casing strings or liners for these same wells are indicated by orange semi - circles. The portions of each well bore that lie between the surface casing shoe and the top of production string cement are assumed to be filled only with drilling mud, and are therefore possibly open to communication. The base of permafrost occurs at about 700' TVDSS in the CD4 drill site area. The base of permafrost lies about 1,600' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD4 -Pad contains methane gas. Records from the Nanuk 1 (located just off the index map above, about 3,800' southwest of CD4 -302), Nanuk 2 and Nanuq 5 exploratory wells record initial traces of methane at 460', 70', and 60' TVDSS, respectively. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights • • CD4 -302 Additional Disposal May 31, 2012 Note to File Page 3 of 5 (typically 9.6 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log) were 1,890', 2,170' and 2,235' TVDSS, respectively. So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil shows observed in nearby wells Nanuk 1, Nanuk 2 and Nanuq 5 occur at 3,765', 4,710' and 3,770' TVDSS, respectively. The mud logging geologists rated these shows as being fair to good shows in quality. However, these oil shows occur more than 1,000' below the portion of the open annulus that will most likely accept the additional injected waste. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which govern the Nanuq and Nanuq - Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. The 'A -mile radius area of review (more correctly, a cylinder of review) surrounding the proposed disposal interval in CD4 -302 is highlighted on Figure 1 by two blue circles; one circle is centered at the location of the surface casing shoe, and the other is centered on the calculated top of cement for the production casing string. In CD4 -302, the disposal interval lies between 2,335' to 3,693' TVDSS, with the most likely waste - receiving zone between 2,335' and 2,455' TVDSS (see cross - section, below). Only Five wells open these same strata within the 'A -mile radius area of review. They are, from west to east, CD4 -209, CD4 -208, CD4 -301, CD4 -298, and Nanuk 1. Those portions of the Nanuq 5, CD4 -320 and CD4 -320 PB1 well bores that also cross through the area -of- review circle are situated below the disposal interval. These three wells will not be discussed further. The surface casing shoe of CD4 -209 lies at the western boundary of the area of review, and the open annulus below that casing shoe lies outside of the area of review. The casing shoe of CD4 -208 is located 1,270' away from the surface casing shoe of CD4 -302, which is about 50' inside the area of review. During 2007, the Commission approved CD4 -208 for disposal injection within the same geologic interval, and, as of October 2007, a total of 61,839 barrels of waste had been injected into CD4 -208. Disposal injection into CD4 -302 will likely not affect CD4 -208 due to the large separation distance (see discussion on pages 4 and 5, below). The casing shoes of CD4 -301 and CD4 -302 lie about 450' apart, and the closest approach to CD4 -301 by the open annulus of CD4 -302 is about 325'. Commission records suggest that the disposal interval of CD4 -302 is open to the CD4 -301 wellbore. The CD4 -301 wellbore may be affected by disposal injection in CD4 -302. However, the CD4 -301 daily drilling report of December 12, 2007 contains the following report concerning surface casing cementing operations: "Reciprocated pipe during job - full returns throughout — 125 bbls 10.7 ppg cmt returns to surface." If waste fluids injected into CD4 -302 reach the CD4 -301 annulus, there will be not be an open pathway to the surface. The casing shoe of CD4 -298 lies about 350' from the most likely injection interval in CD4 -302, and Commission records suggest that the disposal interval of CD4 -302 is also open to the CD4 -298 wellbore. But, Commission records from CD4 -298 indicate that the surface casing appears well cemented, with full returns noted, and pipe reciprocated throughout most of the cement job. If waste fluids injected into CD4 -302 reach the CD4 -298 annulus, there will be not be an open pathway to the surface. Nanuk 1 is a plugged and abandoned, vertical, exploratory well located about 350' away from the top of the open annulus in CD4 -302. Several open -hole cement plugs were placed in Nanuk 1, two of which are significant here. Cement plug 3 extends from 4,110' to 3,246' TVDSS, and cement plug 4 extends upward from 1,861' into surface casing shoe to 1,575' TVDSS. The open annulus between the cement • CD4 -302 Additional Disposal May 31, 2012 Note to File Page 4 of 5 plugs, from 3,246' to 4,861' TVDSS, is filled with 10.2 pound - per - gallon, kill- weight mud. If waste fluids injected into CD4 -302 reach the Nanuk 1 annulus, there will be not be an open pathway to the surface. The gamma ray curve recorded in CD4 -302 indicates that about 17' of net sand are present in the most likely disposal interval. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sandstone and siltstone porosity of 12% at this depth. Based on these values, the area impacted by the previous injection of 56,647 barrels lies within a radius of about NE 1450' 450' 326' 0 ,12/ Plug 4 Surface Casing Shoe Upper Confining Liken , Interval Disposal -C Interval { Open hole Cement Lower -* { Plugs Confining Open I / Beds Annulus J Plug 3 Figure 2. CD4 -302 Area: Structural Cross - section (Depth scale represents feet TVDSS; separation distance between wells is measured at the surface casing shoe) • • CD4 -302 Additional Disposal May 31, 2012 Note to File Page 5 of 5 225' from the wellbore, assuming uniform, radial, piston -like displacement of the native formation fluid occurs. Injection of an additional 13,000 barrels of waste will expand the affected area to a radius of about 250' from the wellbore. Injected Fluid vs Affected Radial Distance CD4 -302 Wellbore (assumes IT aggregate injection zone thickness and 12% porosity) 300 250 ; 200 2 m Ws 150 _ 6 c 100 d 50 0 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 Amount of Injected Fluid (barrels) Figure 3. CD4 -302 Area Likely Affected by Annular Injection The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700' of permafrost, and is bounded above and below by continuous layers of claystone and shale. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. Injected wastes may reach nearby wells Nanuk 1 or CD4 -301, but if they do, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the disposal strata. I reco end approving this additional annular disposal up to the limit of 70,000 barrels. Steve Davies Senior Petroleum Geologist A 01 rit.. ceir,„ 4 4-4-"'" G G �L • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, July 05, 2011 t �, P.I. Supervisor r' e ''' e (f 14 j/( SUBJECT: Mechanical Integrity Tests `` CONOCOPHILLIPS ALASKA INC CD4 -302 FROM: Matt Herrera COLVILLE RIV NAN -K CD4 -302 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN -K CD4 -302 API Well Number: 50- 103 - 20545 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110701084825 Permit Number: 207 -056 -0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD 302 'Type Inj. W ' TVD 6237 - IA 1080 2340 2318 2313 H P.T.D 2070560 f TypeTest SPT Test psi 1559 . OA -- 520 641 634 630 Interval 4YRTST - P/F P - Tubing 1513 1514 1515 1516 Notes: IA tested to 2300 psi .9 BBL's e 1 �- 3��,p3� JUL � ' 0 I I Tuesday, July 05, 2011 Page 1 of 1 R~ !i ~L.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL I tJ ~ €i! '°~ ?. X110 Alaska Oil Et "~~ "'^:°:. 4'~rnmissi©n erator: 1 O 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-056 . p ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^ or Final 0 309-167 5/20/2009 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred ~ ~~~ `S E~ _ `l ~~~ ~'° fluids, formation fluids and ~1i*~7 any necessary water added Previous 31545 100 355* 32000** totals (bbls): 2009 / 2nd 0 0 16.5* 16.5 2009 / 3rd 0 0 0 0 2009 / 4th 22426.5 100 0 22526.5 23 12/4/2009 12/31/2009 CD4-24 2010 / 1st 2004 100 0 2104 2 1/3/2010 1/4/2010 CD4-24 2010 / 2nd 0 0 0 0 0 Total Ending Report is due on the 20th Volume 55975.5 300 371.5 56647 25 of the month following the final month of the quarter. Ex: (bbls): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, freeze rotect volumes and in'ectivi test **volume from revious sund #307-257 ct to the best of my knowledge. o rr e I hereby certify that the foregoing is true and c / ( ~ _ ~ Signature: ~ ~ ~°"'~ Date: 7l(9 ~Z~ (~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~~ ~_. ~. ~, ~ ~ ~~, d .~ ~ ~} ` ""`' ~ ~~ ; s, l~ a sac i '- ~a: MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL ..UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ECEt~E~ APR 1 3 2010 Oil&Gas~ons.Ccammisah~an STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: C Philli 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-056 onoco ps Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 309-167 5/20/2009 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion fluids formati n fl id d occurred ~ ~~~~ , o u s an y t ~~ any necessary water - - added Previous totals (bbls): 31545 100 355* 32000** 2009 / 2nd 0 0 16.5* 16.5 2009 / 3rd 0 0 0 0 2009 / 4th 22426. 100 0 22526.5 23 12/4/2009 12/31/2009 CD4-24 2010 / 1st 2004 100 0 2104 2 1/3/2010 1/4/2010 CD4-24 2010 / 2nd Total Ending volume 55975.5 300 371.5 56647 25 Report is due on the 20th (bbls): of the month following the final month of the quarter. Ex: A il 20 f th fi t pr or rs e quarter, July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ . fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, freeze protect volumes and in~ectivit test **volume from revious sund #307-257 I hereby certify that the foregoing is true and correct to the best of my knowledge. ^ Signature: /~ 'G. ~ Date: ~< L (Z~r 3 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 309-167 5/20/2009 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal '~ nn { drillin mud, com letion 9 P occurred ~, ~ ~ V .,,.~;~„~ ~A IV fluids, formation fluids and any necessary water added Previous 31545 100 355* 32000** totals (bbls): 2009 / 2nd 0 0 16.5" 16.5 2009 / 3rd 0 0 0 0 2009 / 4th 22426.5 100 0 22526.5 23 12/4/2009 12/31/2009 CD4-24 2010 / 1st 2010 / 2nd Total Ending Report is due on the 20th volume 53971.5 200 371.5 54543 23 of the month following the final month of the quarter. Ex: (bbis): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, freeze rotect volumes and in'ectivit test **volume from revious sund #307-257 I hereby certify that the foregoing is true and correct to the best of my knowledge. / l~w(2°~~ ~ ~ .~/L_ Date: Signature: ~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 M Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^Q or Final ^ 309-167 5/20/2009 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal ~ ~n~ ~ drilling mud, completion occurred , V ~~ ~A~~~ fluids, formation fluids and any necessary water added Previous 31545 100 355* 32000"'" totals (bbls): 2009 / 2nd 0 0 16.5* 16.5 2009 / 3rd 0 0 0 0 2009 / atn 22426.5 100 0 22526.5 23 12/4/2009 12/31 /2009 CD4-24 zolo/1st 2010 / 2nd Total Ending Report is due on the 20th volume 53971 5 200 371.5 54543 23 (bbis): . of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: *annular flush, freeze rotect volumes and in~ectivi test **volume from revious sund #307-257 to the best of my knowledge. I hereby certify that the foregoing is true and c orrect / ~ / / ~ I ~j2®~'~ Signature: /~ 1..c~ Date: ` Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-056 ConocoPhiilips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: _ , . P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ ~~.. . 50-103-26545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 309-167 5/20/2009 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal ~ ~~~ i s~~ i'~ T~`.~ •~~`~`~ ` ~~ ~ drilling mud, completion occurred s~ ~~ % ' fluids, formation fluids and any necessary water added Previous 31545 100 355* 32000** totals (bbls): 2009 / znd 0 0 16.5* 16.5 2009 / 3rd 0 0 0 0 2009 / 4th 2010 / 1st 2010 / 2nd T°'a' E"a~"9 Report is due on the 20th vo~ume 31545 100 371.5 32016.5 0 ~bbis~: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances ~escr~ption~s~: *annular flush, freeze rotect volumes and in~ectivi test **volume from revious sund #307-257 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: _ ~.1 ~_~ii~ Date: ~fl~'~°1 t~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~ 1_J MEMORANDUM To: Jim Regg ~~~ ~ ~~~ P.I. Supervisor 7 ~ FxoM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-302 COLVILLE RIV NAN-K CD4-302 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. 5uprv ~ 2- Comm Well Name: COLVILLE RN NAN-K CD4-302 API Well Number: 50-i03-20545-00-00 Insp Num: mitRCN090729092651 Permit Number: 207-056-0 .i Rel Insp Num: Inspector Name: Bob Noble Inspection Date: ~~23/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4-302 Type Inj. W ~j'~ 6237 jA 864 1836 1817 1815 P.T.D 2070560 TypeTest SPT Test psi 1836 QA 575 655 643 639 Interval axaTST p~ P •' Tubing >>~g ti2s iiza i~2s NOtes• No packer depth in RBDMS, so I used operators 1"~1 r \ 4 1"_"J"~ ~ ~'rJ,S~.~:~~ ~ ~~ ~ ~ ~ ..,~ A ., `M:~. ~~_ .. ~ ~ _..~f[ Wednesday, July 29, 2009 Page I of 1 ~ f ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070560 Well Name/No. COLVILLE RIV NAN-K CD4-302 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20545-00-00 MD 9626 ND 7104 Completion Date 6/21/2007 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu, USiT, CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~yp meairrmt rvumoer Name aca~e mea~a wo start 5top ~h rcecervea ~ommencs og Sonic 5 Coi 1 4000 9540 .~perr- ~7/3/2007 USIT, UCE, CCL, GR 19- C 45+~- Jun-2007 D D Asc Directional Survey 0 9626 Open 8/23/2007 og See Notes Blu 1 100 9510 Open 8/27/2007 RST Water Flow w/Press, , Temp, Spin 27-Ju1-2007 ED C Pds 15834~nduction/Resistivity 0 0 Open 1l15/2008 ROP, DGR, EWR, CTN, ALD in PDF, EMF and CGM graphics pt LIS Verification 2737 9626 Open 1/15/2008 LIS Veri, GR, DRHO, , RHOB, NCNT, FCNT, I NPHI, PRM, RPS, FET, ' ROP ED C Lis 15836 Induction/Resistivity 2737 9626 Open 1/15/2008 GR, DRHO, RHOB, NCNT, FCNT, NPHI, PRM, RPS, FET, ROP Well Cores/Samples Information: ~J ~ Sample lnterval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070560 Well Name/No. COLVILLE RIV NAN-K CD4-302 Operator CONOCOPHILLIPS ALASKA INC MD 9626 ND 7104 ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? 1`tid-' Analysis ~ Y / N Received? Completion Date 6/21/2007 Comp~etion Status WAGIN Daily History Received? Formation Tops Current Status WAGIN ~J~'"` ~Y'N Comments: API No. 50-103-20545-00-00 UIC Y ~ Compliance Reviewed By: ~-~ Date: r~-'~ wV~ ~~~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 309-167 5/20/2009 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Welis: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 31545 100 355* 32000** totals (bbls): 2009 / 2nd 0 0 16.5" 16.5 2009 / 3rd 2009 / 4th 2010 / 1 st 2010 / 2nd Total Ending Report is due on the 20th vo~ume 31545 100 371.5 16.5 0 ~bbis>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal PerFormance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances oescr~pt~on~s~: *annular flush, freeze rotect volumes and in'ectivi test "`*volume from revious sund #307-257 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /c~l ~ l.Jt~ Date: `7~7(~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 i ~ Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Page 1 of ~ ~ • ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 27, 2009 3:19 PM To: 'Galiunas, Elizabeth C'; Anderson, Nina M Cc: Regg, James B (DOA) Subject: RE: CD4-302 (207-056) AD Increase Liz and Nina, Thanks much for the information. I concur with your calculations. The pressure plot is not a lot different than the initial pump-in performed 6/18/07. You have submitted the new pump-in test as required by the sundry. CPAI is clear to resume AD into Cb4-302 with a 70000 bbl volume maximum. Call or message with any questions. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Wednesday, May 27, 2009 2:59 PM To: Maunder, Thomas E (DOA) Cc: Anderson, Nina M Subject: RE: CD4-302 (207-p56) AD Increase Tom, here is the plot you requested. I attached a sheet to show how the EMW was calculated at the shoe. ~et me know if you have comments or questions. Liz Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 From. nder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wedn May 27, 2009 8:34 AM To: Galiunas, Elizabe Cc: Anderson, Nina M Subject: RE: CD4-302 (207-056) crease Liz or Nina, Do you have any "plot" of the information showing the h e pressure changed as pumping proceeded? I was expecting a document similar to the pump-ins normally p ' ed with the applications. Thanks in advance. Tom Maunder, PE AOGCC Prom: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Wednesday, May 27, 2009 7:12 AM 5/27/2009 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. ',Well Name: CD4-302 Rig: Doyon 19 Date: 5/27;2009 Drilling Supervisor: D. Burley Pump used: Cement Unit ~ Volume Input garrels ~ 0.1000 Bbis/Strk ~ Type Of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pt Hole Size: USE PICK LIST ~ Casin Shoe De th Hole De th Pum in Shut-in Pu RKB-CHF: ~4 2 Ft 2.762 Ft-MD 2,394 Ft-TVD 4,740 Ft-MD 3,749 Ft-TVD Bbls psi Min psi Bbls Casinq Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 ( mp Rate: Bbl/min ~ e rit Test Shut-in Min psi 0 995 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.1 606 0.25 974 uter casing shoe test results in comments Mud Weight: 7 2 ppg 2 0.2 712 0.5 964 Description references outer casing string. Inner casing OD: 7.0 In. 3 0.3 808 1 95 ize is that drilled below outer casing. 4 0.4 904 1.5 timated TOC for Hole Depth. 5 0.5 974 2 93 Enter inner casing OD at right Desired PIT EMW: 15.0 ppg 6 0.6 1040 2.5 924 Estimates for Test: 973 psi -0.1 bbls 7 0.7 1095 3 914 ~~~ ~~ 8 0.8 ' 1136 ~~! 3.5 909 EMW = Leak-off Pressure + Mud Weight = 1040 PIT 15 Second 9 0.9 1207 4 899 0.052 x TVD 0.052 x 2394 + 7'18 Shut-in Pressure, psi 10 1 1191 4.5 894 EMW at 2762 Ft-MD (2394 Ft-ND) = 15.5 9~4 15 ' 1160 5 889 isoo 20 1~ 1121 5.5 888 25 1075 6 878 30 ~ { 1060 6.5 873 iooo w ~ ~ ~ ~ w ~ a 500 Oa I I I ~ ~ 0 1 2 3 4 5 Barrels ~~CASING TEST tLEAK-OFF TEST ;: The 7.2 MW is calculated based on 56 bbls of die~ Initial annular LOT was 17.1 ppg and the Casing s 6 0 5 10 15 20 25 30 Shut-In time, Minutes O PIT Point he rest of the annulus water. (1853 test was 5 ume iesel / 1853'TVD-2394'TVD is wate • • CD4-302 Nanuq Kuparuk Injector Completion 16" Insulated Conductor to -114' Diesel 6.8 ppg Water 8.5 ppg ', ~ ~ ~ ~ 1984' MD / 1853' TVD 2762' MD / 2394' TVD M Surface Casing 56 bbls of diesel and fresh water in in annulus 56bbls ' 35.427 ft/bbl = 1984 ft MD Diesel = 1853' TVD Pressure at 1853' TVD = 655.2 psi For Water section: (2394 - 1853) " 0.052 * 8.5 ppg = 239.1 psi Pressure at shoe: 239.1 psi + 655.2 psi = 894 psi EMW = 7.18 ppg ~ . Page 1 of 2 Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Wednesday, May 27, 2009 9:59 AM To: Maunder, Thomas E (DOA) Cc; Anderson, Nina M Subject: FW: CD4-302 (207-056) AD Increase Tom, I apologize for the confusion. What I sent is what the guys use to see if they can pump down an annulus. They are rigging up hardline to CD4-302 and will have the cement unit pump an annular LOT type test on the well. The injection unit is still down. I was miss informed when I wrote the previous note. Even though we are almost done with our work on CD4 for a few months, it is still valuable to get this test complete and have an annulus on CD4 to use for annular disposal when we come back in October. I will send the plot tomorrow Liz Galiunas Alpine Drilling Engineer ConocoPhitlips Alaska Office: 907-265-6247 Cell: 907-903-1200 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 27, 2009 8:34 AM To: Galiunas, Elizabeth C Cc: Anderson, Nina M Subject: RE: CC~4-302 (207-056) AD Increase Liz or Nina, Do you have any "plot" of the information showing the how the pressure changed as pumping proceeded? I was expecting a document similar to the pump-ins normally provided with the applications. Thanks in advance. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.corn] Sent: Wednesday, May 27, 2009 7:12 AM To: Maunder, Thomas E (DOA) Cc: Anderson, Nina M Subject: RE: CD4-302 (207-056) AD Increase Tom, Finally the injectivity test has been done. We got the injection pump working again yesterday. Sorry for the long delay. Thanks, Liz Liz Galiunas 5/27/2009 • ~ Page 2 of 2 Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 From: Maunder, Thomas E(DOA) jmailto:tom.maunder@alaska.gov] Sent: Tuesday, May 19, 2009 10:26 AM To: Galiunas, Elizabeth C Subject: CD4-302 (207-056) AD Increase Liz, Following up on our call, I am working on the request to increase the AD volume. Regarding new pump in information, you indicated that you plan to get that information as disposal starts. That is acceptable. The only requirement will be to provide that information to us/me prior to pumping in earnest. Call or message with any questions. Tom Maunder, PE AOGCC 5/27/2009 GOj~OCOPHILLtPS-DAILY p~NULAR INJEC IDN RECORD h'1G #; ~OT OIL' ` DATE 5!26izoos ~a 5I2612009 PAGE~__of__y___, ..~_.s. ~ Injecting into welt: CD4-302 0 R 1800 HR5 BARRELS 1NJECTED FOR MUD ONLY ( Llst under Praper flufd Type) ~i'i in Of ~ Fluids Start Time Stop T~me PUMP ~TE BP~~ Static pressure ~PSq injection Pressure (PS~) P~raton t at 9enerated Was2e MUD MUD or Overflushing WELL DfESEL for Freeze Protecting Rig Wash Water OTHER S eci T L Cummulative Volume Weight (PPG) Funnet Viscosity Comments KUTP 1310 1315 •9 600 1100 5 5 6.8 24 ~njectivityTest iD 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Fluld Properties rara~ va~uMes FOR DAY.~ Water Based Rpp~ ° s MUD WA7ER DIESEL WASH WATER OTHER ~ ~ 5 I ~ Water Basecl RPM ID Wt Visc 600 300 Temp %Solids TOTAL FQR ~ummulative Total TODAY New Total from Previous Day 5 32006 32011 Mineral Oil Based ID Wt Visc 600 RPM 3OO Temp %Solids , , C~~"~~°"" '''l3Ai~1~~, ~~F8~1 'OP'€ `~'°"~..~.~ ARRY SCHACHLE EREMY HOLT ~~ ~ C.~'^ ~~l~y~ ~ ~.~ .. ~ ~ Note to File CD4-302 (207-056...309-167) Colville River Unit (Nanuk-Kuparuk) ConocoPhiilips Alaska, Inc Request increase allowed annular disposal volume from 35,000 barrels to 70,000 barrels. Recommendation Approve annular disposal of up to 70,000 barrels of fluid in CRU CD4-302. Discussion ConocoPhillips Alaska Inc. ("CPAI") has made application to increase the allowed disposal volume in the 9-5/8" x 7" annulus of the subject well from 35,000 barrels to 70,000 barrels of fluid. Annular disposal had been previously approved for this well through sundry 307-257, approved September 6, 2007. This document presents pertinent information supporting this request and recommends approval of ConocoPhillips' request. --As authorized by sundry 307-257, CPAI has disposed of a total of 32,000 bbls (as of 12/6/07) into the 9-5/8" x 7" annulus of this well. They have not reporteded any problems. --CPAI is making this request due the unavailability of other surface casing annuli on CD4 pad. .~ --AD is the standard method CPAI uses to dispose of drilling waste. The grinding equipment is part of the rig equipment and solids are processed for disposal on-site. --In support of this application, CPAI provided surface-cementing information on the 1 additional well drilled since 307-257 was approved and comments regarding a proximate exploration well. CD4-301 is ~468' distant and Nanuk #1 is 370' distant. Examination of the provided records did not reveal information that would preclude approval of CAPI's request. --A log analysis performed by Steve Davies is attached. As noted in his analysis, there are no USDWs in the area. He recommended granting CPAI's request. Based on examination of the submitted information and analysis, I concur and recommend approval of ConocoPhillips' request to increase the allowable disposal volume in CD4-302 to 70,000 bbls. ~~ Tom Maunder, PE Sr. Petroleum Engineer May 19, 2009 G:~AOGCC\Common\tommaunder\Well Information~By Subject\Annular Disposal\090519---CD4- 302 increase.doc ~ ~ Note to File CRU CD4-302 (PTD 2070560) May 12, 2009 Re: ConocoPhillips' Application for Sundry Approval far Annular Disposal of Additional Drilling Wastes within WeD CD4-302 Request ConocoPhillips requests that the annular disposal volume limit of 20 AAC 25.080(d)(1) be increased from 35,000 barrels to 70,000 barrels for well CD4-302. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at 2,390' true vertical depth ("TVD"), near the base of a 410-foot thick shale and claystone interval that persists throughout the azea. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and Iaterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will be limited to a radius of less than 250' from the wellbore. 8. If injected wastes reach nearby wells Nanuk 1 or CD4-301, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from nearby wells Nanuk 1, Nanuk 2, Nanuq 5, CD4-208, CD4-209, CD4-301, and CD4-320. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided in Figure 1, below. The proposed disposal injection interval (disposal interval) in these wells lies in the Seabee formation within Section 19, Tl 1N, RSE, UM and in Section 24, T11N, R4E, UM, which are 2 to 3 miles from the current boundary of the Colville River Unit. The 9-5/8" surface casing shoes of the wells lie at about 1,753' to 2,335' TVDSS, near the base of a 410-foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). The annulus open to the disposal interval extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to range from 2,335' to 3,693' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 60-foot thick interval containing several 1- to 4-foot Yhick beds of silty sandstone and sandstone that lie between about 2,395' and 2,455' CD4-302 Additional Disp~ • May 12, 2009 Note to File Page 2 of 5 TVDSS, which is just below the surface casing shoe. The aggregate thickness of these thin, potential receptor beds is about 17'. The silty sandstone and sandstone beds are separated by thin shale and claystone intervals. Beneath the disposal interval is a 55-foot thick interval of shale, claystone and tuff that is continuous throughout the area. This interval, which lies between about 2,553' and 2,608' TVDSS, will provide lower confinement for any injected wastes. Underlying beds of shale and claystone will provide additional lower confinement as illustrated on Figure 2. CD4-320 PB 1 Surl~ucu ai~in~ ,n~ic n;~,u~l.,ci - ;A- . ~ ~ 1/4-mile area of review ~~~ ~ ~ O~ ~~ L~kely ~ ~` ' Nanuk 1 nj ~~ ~ 1 Disposal ~ ~ ' ~ ~ ,~_ Interval ~, ~ ~ ~ rl ~ . f \'~ ~ ~. ~ V ~~ , -~'~ ~ __ ;.. ~ ~ - ~ ~~, ~O \ _ ` , - _ - ii ~1. -_- * ' CD4-302 ~aoo,~ ~ tL CD4-302 ~ i , ~ N ' ~, ~pen ~ __. , , __, i !r ~ t f~T111U1U5 ~ ,~ , _ '', \ ~{ - ' CD4-301 ~ CD4-208 ~~, - ' .. ~~ T ~. 1 j' CD4-320 ~' S00' . CD4-209 Nanuq 5 Figure 1. CD4-302 Index Map (all depths shown are feet TVDSS) The index map above presents the trajectories for all wells drilled from and near the CD4 drill site. Short tick-mazks have been placed along each well trajectory at 500' TVDSS intervals and they are labeled every 1000' TVDSS. The surface location of each wellbore is represented by a gray circle that is about 100 feet in diameter, and the few bottom hole locations visible on the map are represented by 350-foot diameter, gray circles. The locations and true vertical subsea depths of surface casing shoes for selected well bores are illustrated using green triangles and green text, and the calculated locations of the tops of cement for production casing strings or liners for these same wells are indicated by orange semi-circles. The portions of each well bore that lie between the surface casing shoe and the top of production string cement are assumed to be filled only with drilling mud, and are therefore possibly open to communication. The base of permafrost occurs at about 700' TVDSS in the CD4 drill site area. The base of permafrost lies about 1,600' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD4-Pad contains methane gas. Records from the Nanuk 1(located just off the index map above, about 3,800' southwest of CD4-302), Nanuk 2 and Nanuq 5 exploratory wells record initial traces of inethane at 460', 70', and 60' TVDSS, respectively. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.6 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of i CD4-302 Additional Disposal Note to File ~ May I2, 2009 Page 3 of 5 methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log) were 1,890', 2,170' and 2,235' T'VDSS, respectively. So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil shows observed in nearby wells Nanuk 1, Nanuk 2 and Nanuq 5 occur at 3,765', 4,710' and 3,770' TVDSS, respectively. The mud logging geologists rated these shows as being fair to good shows in quality. However, these oi1 shows occur more than 1,004' below the portion of the open annulus that will most likely accept the additional injected waste. Supporting docurnentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which govern the Nanuq and Nanuq-Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. The '/4-mile radius area of review surrounding the proposed disposal interval in CD4-302 is highlighted on Figure 1 by two blue circles; one circle is centered at the location of the surface casing shoe, and the other is centered on the calculated top of cement for the production casing string. In CD4-302, the disposal interval lies between 2,335' to 3,693' TVDSS, with the most likely waste-receiving zone between 2,335' and 2,455' TVDSS (see cross-section, below). Only four wells open these same strata within the '/4-mile radius area of review. They are, from west to east, CD4-209, CD4-208, CD4-301, and Nanuk 1. Those portions of the Nanuq 5, CD4-320 and CD4-320 PB1 well bores that also lie inside the area-of-review circle are situated well below the disposal interval. These three wells will not be discussed further. The surface casing shoe of CD4-209 lies at the western boundary of the area of review, and the open annulus below that casing shoe lies outside of the area of review. The casing shoe of CD4-208 is located 1,270' away from the surface casing shoe of CD4-302, which is about 50' inside the area of review. During 2007, the Commission approved CD4-208 for disposal injection within the same geologic interval, and, as of October 2007, a total of 61,839 barrels of waste had been injected into CD4-208. Disposal injection into CD4-302 will likely not affect CD4-208 due to the large separation distance (see discussion on pages 4 and 5, below). CD4-301 is the closest wellbore to CD4-302 in the disposal interval, and Commission records suggest that the disposal interval of CD4-302 is also open to the CD4-301 wellbore. T'he casing shoes of the two wells lie about 450' apart, and the closest approach to CD4-301 by the open annulus of CD4-302 is about 325'. The CD4-301 wellbore may be affected by disposal injection in CD4-302. However, the CD4-301 daily drilling report of December 12, 2007 contains the following report concerning surface casing cementing operaxions: "Reciprocated pipe during job - full returns throughout - 125 bbls 10.7 ppg cmt returns to surface." If waste fluids injected into CD4-302 reach the CD4-301 annulus, there will be not be an open pathway to the surface. Nanuk 1 is a plugged and abandoned, vertical, exploratory well located about 350' away from the top of the open annulus in CD4-302. Several open-hole cement plugs were placed in Nanuk 1, two of which are significant here. Cement plug 3 extends from 4,ll0' to 3,246' TVDSS, and cement plug 4 extends upward from 1,861' into surface casing shoe to 1,575' TVDSS. The open annulus between the cement plugs, from 3,246' to 4,861' TVDSS, is filled with 10.2 pound-per-gallon, kill-weight mud. If waste fluids injected into CD4-302 reach the Nanuk 1 annulus, there will be not be an open pathway to the surface. To date, approximately 32,000 barrels of Class II waste materials have been injected into CD4-302. ConocoPhillips has requested the Commission increase the allowable injection limit to 70,000 barrels of i • CD4-302 Additional Disposal May 12, 2009 Note to File Page 4 of 5 waste. The chart above presents an estimate of the affected areas surrounding the wellbore. From the gamma ray curve, a count of sand indicates that about 17' of net sand are present in the most likely disposal interval. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sandstone and siltstone porosity of 12% at this depth. Based on these values, SW NE zozoazo zo~,soo zo~osso ~ssos~o 50103204i400 501032055700 1460' ~ --~~ ~ ~ 50103205~500 460' - 501032023800 326' CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILIIPS ALASK ARCO NANUQ 5 COLVILLE RIV UNIT CD4301 COLVILLE RIV UNIT CD4302 NANUK 1 2342 FSL 283 FEL 70 FEL 2882 FNL 2887 FNL 69 FEL 2827 FSL 869 FWL TWP: 11 N- Ranpe: ~ E- Sec. 24 TWP: 11 N- Ranye: 4 E- Sec. 24 TWP: 11 N• Rarpe: 4 E- Sec. 24 TWP: 11 N- Ranye 5 E- Sac. 19 ".,~ - O ~ .. O -r _ ~ _~~"~ . ~ p ~ d(' ~ i - S S ~ ,~ _~ _ ' r{ ~ -~ ~ C ~ ~ _ ~~ ~ _1000 { V- . i' ~ -100i t - ;` f - ) ; _ .~~ - ', - -~sa ~: Surface ' ~ ~ ' ~ Casing ~. zooo , ~ Shoe ~ - _ -zooc ~ Upper Confining y ~ Interval ~r ~ _ ~ Likeh , -~ : ~ f ~ Uisposal { ~ ~ ~ 25°° _ Interval { _ i ry ~zsoc , ~ ~ - ` Open h~ _ ~ / { ~ , - ' ~ Gemeni ~ ~ - Lower• ' ~. ~lugs ~ , Confining{ Open _3ooc : Beds ~ AHnulus _ ~I ~ f ~ ~ F ~ 1 ', c 'i 3500 ~ , {~ ~ i ~ ~. -350C ~ f ~ , PIUg;3~ . ~ f t ~ ~~ ~ ~ ~- ~ ~~ 4~ TD=11735 TD=21615 TD=8828 TD=~630 ~~ Figure 2. CD4-302 Area: Structural Cross-section (Depth scale represents feet TVDSS; separation distance between wells is measured at the surface casing shoe) ~ CD4-302 Additional Disposal Note to File May 12, 2009 Page 5 of 5 the area impacted by the previous injection of 32,000 barrels is limited to a radius of about 170' from the wellbore, assuming uniform radial displacement occurs. Injection of an additional 38,000 barrels of waste will expand the affected area to a radius of about 250' from the wellbore. Injected Fluid vs Affected Radial Distance CD4-302 Welibore (assumes 1~' aggregate InJecUon zone thickness and 12°k porosity) 300 - _ - ,_ _ -- - -- _ 250 ' ~ ~_ f, m , a -~~•_ 3 z°° , . ~ E ,. 0 ~ 150 ~ ~„ `m O m ~~ q 100 K 7 m ~ ~ : Q ~ ~ a ~~.D00 2~.~00 30,000 40.00~ 50.00~ 6~.000 ~~,D00 Amount of Injected Fluid (barrela) Figure 3. CD4-302 Area Likely Affected by Annular Injection The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700' of permafrost, and is bounded above and below by continuous layers of claystone and shale. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. Injected wastes may reach nearby wells Nanuk 1 ar CD4-301, but if they do, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the disposal strata. I recommend approv'ng this annular disposal project. ~ Steve Davies Senior Petroleum Geologist ~ ~ ~d,~cv~ ~~~~' ~ ~i?/o ~ 4~ s • z ~ > F _ ~` , ~ € ~ t p ~r~ r E ~r ~ ~ i r _ A ~ ~ ~ ~~ ~ ~, f 5 u {' t ; ; , ~, ~ ~ a, r~ ~~ , _ ~ . .. _~ ~ _.~~ ~. ~L1~S8A OIL Ai1TD G~5 CO1~T5ERQATIOI~T COMI~IISSIOI~T Cllip Alvord Alpine Drilling Team leader ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Nan.uq-Kuparuk oil Pool, CD4-302 Sundry Number: 309-167 Dear Mr. Alvord: Enclosed is the approved Applicatian for Sundry Approval relating to your request to increase tl~e allowable volume that may be disposed into the surface casing annuliis of the above-referenced well. ~our request to increase the allowable disposal volume to 70,000 barrels is GRANTED. 20 AAC 25.480(dj(1} restricts the maxirriurn disposal volume to 35,000 barrels unless ". .. the operator demonstrates that compliance with (the) limitation is imprudent. " A:vailable Ga~didate wells for annular dzsposal are limited at t~ais drill site and s~nce the o~ly physical solids processing equipment avaxlable at Alpine is part of the rig equap~nent, tllere is no practicable grinding alternative in the axea. The Cominission is satisfied that CPAI has demonstrated that meeting the regulatory volume requirement is, in this case, imprudent. Please note that dispQSal into the surfacefprctduction casing annulus of CD4-302 must comply with the remaining requirements and limitations of 24 AAC 25.0$0. As provided in AS 31.05.080, within ZQ days after written notice of this decision, or such furth~r time as the Cammission gra~rts ~or good cause shown, a person affected by it may ~le with the Commission an application for rehearing. A request for rehearing is considered timely if it is received ~~~ ~ ~~ f « ~ ~ by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A persQn may not appeal a Cominission decision to Superior Court unless rehearing has been requested. DATED this~day of May, 2009 Sincerely, Cathy , Foerster Commissioner Encl. ~~~~~ ~. ~ '~' ~ ~ ~oo~ a~G~,~ d~ ~ ~ STATE OF ALASKA I~`~ ~~Y ~ ~ ~ ALASKA OIL AND GAS CONSERVATION COMMIS~~ ~ii ~~~-~ ~~~~" ~~~i~~SS~n~i ANNULAR DISPOSAL APPLICATION A~'c~'q`~~a 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 207-056 ConocoPhillips Alaska 4. APi Number. 50-103-20545-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-302 6. Field: Colville River Fieid ° 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD4-208, CD4-209, CD4-301, IVanuk 1 Torok and Seabee formation, shale, siltstone and sandstone • ca~~S~C°~~'~C v.~~~~i +~~C'~M~~ZO~ ~~S -~ ~~L~'~h T~ F~'c-Se~"~c~1fc vJrc~~ ~~~~ b) Waste receiving zone: b) water welis within one mile: ~~~ Sand layers below the C30 marker in the Seabee formation • 1 ~ `~ None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' ND None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: ~ 3. Maximum anticipated pressure at shoe: 32,000 bbls (12/6/2007 last injection) ~ densities range from diesel to 12#/gal 2249 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 bbls. ~ Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- ~ contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 11-May-09 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ^~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph ~ Surf. Casing Cementing Data ^ Other ^ previous authorization for new product cleanuo fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,P ~ Signature: .•~ LJ~ Title: r ~ '~~^~-r3~ Printed Phone Name: Chip Alvord Number: 265-6120 Date: 5/5/2009 Commission Use Onl Conditions of approvaL ~p N.~~~ G+~~ ~ I ~O Q+A~,,~S . 0 SSu LOT review and approval: p~~~~~ ~~.~ ~ ~ r ~ ~ ' p9 - Subsequentform required: 'A"~~~ ~S~ t~~~i ~-~L] ~h~ fi ''~~ Approval number: l[a ~ ~~`'~~~'~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~~ ~ A~ !N Form 10-403AD Re~6/2004 k IN,STRUCTIONS ON REVERS~,,~ _~~~,,, I~~~ ~ 7 Submit in D p te'~~ ~-%~' . ~ ~ ~a~ 3/~~ ~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 6, 2009 Alaska Oil and Gas Conservation Commission 333 West 7'i' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ~ ~ • w ~~r~+~Ct~~'!~ y , v~ ~~ . ~x~ ,~~4` '~ ~ 2~Q~~ ~~t'~~it~ ;,~i~ ~ ~8S f;Ot~S. ~-Ofttt'~~ .....,,., Anchorage Re: Application for Sundrv Anuroval for Annular Disnosal of Drillin~ Waste on well CD4-302 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit far CD4-302 (sundry permit # 307- 257) be re-permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on CD4, it is requested that the volume limit described in 20-ACC 25.080 d. 1. be increased from 35,000 bbl to 70,000 bbl. -~ The other wells not yet permitted for annular disposal are either in too close a proximity to explorations wells or are not good annular disposal candidates. This leaves us with the choice of re-permitting a previously used annular disposal well to increase the allowable injection volume. Of the wells on the CD4 pad previously used for annular disposal, CD4-302 is a strong candidate for increasing the allowable injection volume. ~ Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized and additional risks of spillage and vehicular accidents are possible. Injection pressure has typically been significantly below our original surface casing shoe test pressure. CD4-302 ~ was last used for annular disposal on 12/06/2007, after injecting 32,000 bbls. Increasing the allowable disposal volume for CD4-302 will allow for time to drill more wells and potentially other candidates for annular disposal For further details please reference the original annular disposal permit for CD4-302, approved on September 6, 2007. Attached is an updated plot showing all the wells within quarter mile of the surface shoe on CD4-302 and the information for CD4-301, which is not already at the AOGCC. This well was drilled after submitting the sundry far annular disposal operations on CD4-302. Also attached is the updated annular disposal transmittal form. It should be noted that in the previous sundry submitted for CD4-302, the quarter mile plot and CD4 wells summary table did not include Nanuk 1. This information was submitted to the best of our knowledge at the time and was missed due to a database error not including the confidential exploration wells. This well is on the updated quarter mile surface casing plot, but has only surface casing. The surface casing (at 1792' MD/TVD) is 370' away from the surface casing on CD4-302. The intermediate section once drilled, was logged, and cemented of£ Since there is no un-cemented annulus on Nanuk 1, this well will not be a risk to annular disposal operations on CD4-302. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, ,~ r I~'_ F''r:~/ :~ ? Liz Galiui~ia~~~~ ~ Drilling Engineer ~ ~ ConocoPhitlips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 cc: CD4-302 Well File Chip Alvord Sharon Allsup-Drake ~ • • ~~'Ji'11C'~~~J~`~1 ~ ~ 1 ~JJS ATO-1570 ATO-1530 ~ ~ Annulus Disposal Transmittal Form - Well CD4-302 AOGCC Reeulations. 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD4-302 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information su~cient to support a marine shales and claystones of the Albian Torok Formation commission fmding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/L (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating we11s within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maa~imum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 70,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1&2 authorization). 7 An estimate of m~imum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2249 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calcnlation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-26, CD4-24, CD4-25 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. ~ ~ Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Well CD4-302 Assumptions Date 5/5/2009 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg ~~~u~qilu i~ iwl~~ii ~ Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft ~ Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi Version 1.0 -Jan'OS pburst85% - PHydrostaric + PApplied - PFormaUon 4,888 = ( 2,390 * 0.052 * MWm~ ) + 1500 - ( 0.4337 * 2,390 ) MWmax = 35.6 PPg Surface Casin~ String Size 9.625 in Weight 40 ppf Grade L 80 rburst100% 5,750 psi Pburstas% 4,888 psi Depth of Shoe 2,390 ft FIT/L,OT @ Shoe 181 ppg or 2,249 psi FIT/LOT for Annulus 17.1 ppg MaY Surf. Pressure 1,500 psi ~.: , TOC Est. @ 4,740' NID ~ 3,749' TVD Maximum Fluid Densitv avoid Collapse of 2nd Casing Strin~ Pcoilapse85% - PHydrostatic + PApplied - PGasGradient ' PHeader 4,599 = ( 3,749 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 3,749 ) - 1,000 MWmax = 22.4 PPg 2nd Casin~ Strin~ Size 7 in Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 pSl Top of Cement 3,749 ft Gas Gradient 0.07 psi/ft Ma7c Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe P,,,~ ~uoWable = Shoe TVD Depth *.052 * Shoe FIT/LOT pma:c allowable - ( 2,390 * .052 * 18.1 ) Pmax allowable - 2,249 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD4-302 CD4-302 x v Surface Casin Shoe ASP 4 Coordinates NAD 27: 379247.67 5957393.40 elis Details ~ AOGCC" Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ance from Object well` Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing ND (ft) Annular LOT (ppg) omments CD4-07 y 2631 376700.4 5958052.5 16.7 2396 15.4 Too close to CD4-26 (planned source well) CD4-76 2678 376571.7 5957499.3 18.1 2388.5 17.90 Not for annular disposal, due to proximity to Nanuq 3 CD4-17 y 2837 376416.3 5957221.0 18.1 2386.93 16.2 Not for annular disposal, due to proximity to Nanuq 3 CD4-208 y 306-183 5/30/2006 CD4-318a, D4320, CD4-214, CD4321,CD4-211 61839 7/3/2006 1l4t2007 1265 378134.12 5956792.58 16.3 2440.26 14.4 volume extension to 70000 bbl, permit #306-266 CD4-209 y 1314 377935.02 5957333.89 14.7 2376.79 17.5 Not for annular disposal CD4-210 y 1754 377547.47 5956963.14 18.0 2385.97 17.3 CD4-211 y 306-392 12129/2006 CD4-302, CD4-16 31937 6/20/2007 7/11/20D7 1896 377354.32 5957492.92 18.1 2400.1 15A 2nd annular LOT, 1 st ann test@18.4 ppg CD4-213 y 1982 377441.38 5956577.89 78.1 2400.5 21.40 Not for annular disposal. High Ann lest Probably ice p~ug, will retest if needed CD4-214 y 2275 377016.49 5956949.56 17.3 2400 8 17.6 Not for annular disposal CD4-215 y 2531 376762.06 5956914.11 17.6 2400 4 17 50 Noi for annular disposal CD4-302 y;; 307-257 9I6/2007 - 04, p4- 32000 10/21/2007 ` 1276/2007 .= 379247:67 59573934 18,1 2390 . 17.10 CD4304 y 2002 377304.4 5957874.3 16.6 2391 17.8 Not for Annular Disposal CD4-306 y 307-258 9/6/2007 D4304, CD4-07 28330 9/11/2007 10l21/2007 2105 377262.19 5958093.22 18.0 237629 14.90 C04-318 y 306-187 5l26/2006 C 4-209, CD4-320 942 5/31/2006 8/2/2006 3293 376138.31 5956308.17 18.2 2375.32 17.1 Unable to pump- SD pumping CD4-319 y 305373 1219/2005 CD4-208, D4318, CD4-209, CD4-320 32D10 12/14/2005 77212006 2620 377174.72 5955790.44 18.4 2396.47 16.1 CD4-320 y 1512 377915.36 5958108.91 17.1 2387.33 17.8 Not for annular disposal CD4-327 y 306393 1f2l20D7 CD4306, CD4-322 31117 7/14/2007 8f20/2047 3481 375795.28 5956945.38 18.0 2385.47 16.3 CD4-322 y 307-293 10J25/2007 CD4-301, D4-05 3D632 12/8/2007 1f1012008 3589 375674.64 5957731.19 18.0 2385.44 16.8 Nanuk 1 Nanuk 2 Nanu 3 Nanu 5 n n 370 2232 1475 379124.4 377015.63 378326.61 5957742.68 5957391.42 5956241.68 77.8 14.9 1792 1774.97 2393.75 5.1 Exploration P&A'd 1996 (no intermedate casing) Exploration P&A'd Ex loralion PB~A'd in A ril 2007 Not for annular dis osal CD4-307 included 468 379541.0 5957028.4 14.6 2387 13.5 Low Surface LOT. CD4-05 2015 377233.4 5957348.0 18.2 2388 16.5 Toa close to Nanu 3 risk ressurin annulus Nanu 3 2400' ND 2748 376499.3 5957380.8 ~nter olated for 2400' ND CD4-26 Planned 2607 376726.8 5956727.9 2400 Planned * Lateral distance in feet, between surface casing shoes, in the X-Y plane *" As of May 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes ~ ~ ConocoPhillips Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4 -302 Wellbore: CD4 -302 CD4 -302 CD4 -302 Quarter Mile View Ci 9 G��`y�° r s V = 5/8 G � �� 9 5/8" x 121/4 15/8 " 5/8" x 121/4" ' .+ GpA 21 /'� 4•' x 13 -1/2" TD 3/4" 1 — �` -.. GDa 30 p4 -301 CD4 318A 18 1 0 -1200 ` D4 -3 , 0 West( -) 0 600 /East( +) (600 1200 1800 2400 ft/in) 3000 ~ ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ /~,~~, ` ~~~ 3 ~~~~~~ .9 ~ `F, ~~~~ ~ ~ ~~''~~ ~ ~ ~~ ~R ~~~ A~ G~~ ~~~ ~q~~~~~~~~~ ~~~ 9 ~ ~~~~~ ~ ._ ~ ~~ ~ ~ ~ r ~~ 1 i ,°- ~j,~ ~- l.. ~° ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed 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 18~', 2009. 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. Sinc ~ ~ Perry ~uem 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) Aipine Field Date 3/19/2009 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # cement um ed cement date inhibitor sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 ~n4_m ~m_~ ~R ~F Na ~~~ Na n 4~ 3/18/2~09 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 ' 206-077 SF NA 7" NA 1.27 3/18/2009 ' CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-a6 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321• 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL ~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final Q 307-257 9/6/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 355* 355 0 totals (bbis): 200~ i 3rd 0 0 10* 10 0 200~ i ath 31535 100 0 31635 29 10/21 /2007 12/5/2007 CD4-304, CD4-05 2008 / 1 st 0 0 0 0 0 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 Total Ending Report is due on the 20th Volume 31535 100 365* 32000 29 (bbls): of the month followin the final month of the uarter. Ex: g q A h fi t J l 20 f th d t quar er, pril 20 for t e rs quarter, u y or e secon 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ 12. Remarks and Approved Substances ~escr~ption~s>: "annular flush, freeze rotect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /tT`!~~ -~ Date: ~d <<~¢~% Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 307-257 , 9/6/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Welis: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) d isposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 355* 355 0 200713rd 0 0 10" 10 0 zoo~ i ath 31535 100 0 31635 29 10/21/2007 12/5/2007 CD4-304, CD4-05 2008 / 1 st 0 0 0 0 0 2008 / 2nd 0 0 0 0 0 T°ta' E"d'"9 * Report is due on the 20th vo~ume 31535 100 365 32000 29 (bbis): of the month following the ~nal month of the quarter. Ex: Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Expfain) ^ fourth quarter. 12. Remarks and Approved Substances ~escription(s): *annular flush, freeze rotect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ Date: ~~ ~~ $ /~v-~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL ~ ~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service 0 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 307-257 9/6/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 355" 355 0 totals (bbis): 2007 / 3rd 0 0 10" 10 0 200~ ~ 4th 31535 100 0 31635 29 10/21/2007 12/5/2007 CD4-304, CD4-05 2008 / 1 st 0 0 0 0 0 2008 / 2nd Total Ending Report is due on the 20th vo~ume 31535 100 365* 32000 29 Ex: of the month following the final month of the quarter ~bbis~: . Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances ~escription~s): *annular flush, freeze rotect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. \ D t Y ~73 ~o~' ~ Signature: a e: -•-,- Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • . To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-302 January 4, 2008 AK-MW-5030868 CD4-302: Digital Log Images: 50-103-20545-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~IG AND RETURIVING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 , - ) ~ ~~~ q ~~ 3 Z I ::~~~ ~ " ~- ~+ _~, . .~. _-< Da~:''•~~ ~~ '~ ,~~{'~ Signed: ~- ~~~- - ~5 ~ ~ IS~3Y ~ • WELL LOG TRANSMITTAL To: State of Alaska January 4, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-302 AK-MW-503086 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20545-00 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _~ , ~ :~ , ~ ~~~ ~ ~' > ~ ~ ~~.t ~ ~ ~ °~ >> . N~ _.~ ~~~ `,J~t,; ~ '`~ Signed: , ~~. ~ ~ _ ~. . ~. r .e -. ~.~~ ao~--d5~ ~ ~s~3~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-056 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation QQ or Final ^ 307-257 9/6/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 355* 355 0 totals (bbls): 200~ i 3rd 0 0 10* 10 0 200~ / ath 31535 100 0 31635 29 10/21/2007 12/5/2007 CD4-304, CD4-05 2008 / 1 st 2008 / 2nd Total Ending Report is due on the 20th vo~ume 31535 100 365* 32000 29 ~bbis>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances ~escription(s): *annular flush, freeze protect volumes and in~ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. ` <°--- / Si D t ~ yt ~o ~ ' t \ gna ure: e: ( r --_ a Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number. c~7-~~ ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20545-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 307-257 9/6/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 355* 355 0 totals (bbls): 2007 / 3rd 0 0 10"` 10 0 2007 / 4th 2008 / 1 st 2008 / 2nd Total Ending Report is due on the 20th vo~ume 0 0 365* 365 0 ~bb,s>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal PerFormance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances ~escription~s~: *annular flush, freeze protect volumes and in~ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: 1 ` -- Date: l d(?~ / 4 7 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~ i D ~ ~ ~ ,~ SARAH rALIN, GOVERNOR ~~A 0~ ~D ~ 33 7 C011TSERQ.~~'IO1~T CODIIri15SI011T 3 W. 7thAVENUE, SUITE 100 ANCHORAGE, AIASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-302 Sundry Number: 307-257 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing, A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~day of September, 2007 Encl. l •~d' t 1 ~., a..~ ~ ConocoPhillips Alaska, Inc. Post O~ce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 4, 2007 Alaska Oil and Gas Conservation Commission 333 West 7`~ Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Correction on 10-403AD for CD4-16 CD4-306 & CD4-3Q2 Dear Sir or Madam: ~ ConocoPhillips Alaska, Inc. recently requested that 3 wells, CD4-16, CD4-306, and CD4-302 be permitted for pumping of fluids occuning as a result of drilling fluids. An error was found in the X and Y surface casing coordinates for CD4-16 and CD4-306 and therefore the 10-403AD for each well is being re-submitted. Please note, that to help with viewing the surface casing shoes within the quarter mile radius, the wells with surface casings outside the quarter mile plot are excluded. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form CD4-16 2. CD4-16 Plan View of Adjacent Wetls 3. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-16. 4. Annular Disposal Transmittal Form CD4-306 ~ 5. CD4-306 Plan View of Adjacent Wells 6. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-306. 7. Annular Disposal Transmittal Form CD4-302 8. CD4-302 Plan View of Adjacent Wells 9. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-302. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Galiunas Drilling Engineer cc: CD4-16 Well File CD4-302 Well File CD4-206 Well file Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1530 ~ ~5'~'°~ ~ ~ R~C~I~I~D ~~ STATE OF ALASKA ~ SEP 0 4 z007 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~,_._- ANNULAR DISPOSAL APPLICATION ~1~aska Oil & Gas Cons. Cammissi~n-~-~ 20 AAC 25.080 Anchorage 1. Operator 3. Permit to Drill Name: Number: 207-056 ConocoPhillips Alaska 4. API Number: 50-103-20545-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-302 6. Field: Colviile River Field 7. Publicly recorded welis 8. Stratigraphic description: a) All welis within one-quarter mile: a) Interval exposed to open annulus: CD4-2Q8, CD4-209 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1 600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2253 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbis. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 8-Sep-o7 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ^~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ~ Other ^~ previous authorization for new aroduct cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: T Title: ~~ ~ t/t Printed Phone Name: Chip Alvord Number: 265-6120 Date: 9/4/07 Commission Use Only Conditions of approval: Cb~,~~'~~~;y,^~a~~ ~~ ~~ a ~y `~~-~ LOT review and approval: - l- "~' ~~~~""'~3~ Subsequent form required: ~ V"~ Approval number: L3 l' -~~ l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~~ ,/~ ~ .,, 0 / ~J t~ 1 l7 I C'V H4~ ~"~ ~-d a~r i~- ~uu~ Form 10-403AD Rev. 6/ 4 TRUCTI ON REVERSE Submit in Duplicate SURFACE CASING SHOE SEPARATION FROM CD4-302 CD4-302 x v Surface Casing Shoe ASP 4 Coordinates NAD 27: 379247.67 5957393.40 ells Nanuk 7 Nanuk 2 Details @ AOGCC*' n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ance from Object weil* Surface csg. Shoe X Coord. Surtace csg. Shoe Y Coord. Surt LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments Exploration P&A'd Exploration PRA'd Nanu 3 2748 376499.5 5957382.0 11.8 1781 Exploration, X-Y location calculated at 2400' TVD, NOT the surface shoe depth Nanu 5 1475 378326.6 5956241.7 14.9 2393 15.1 Not for annular disposal CD2-319 305-373 12/9I2005 CD4-208, CD4-318, CD4-209, CD4320 32010 12/14I2005 7/2/2006 2620 377174.7 5955790.4 18.4 2400 16.1 CD4208 306-183 5/30/2006 CD4318a, CD4-320, CD4-214, CD4321,CD4-211 61839 7I3I2006 1/4/2007 1265 378134.2 59567927 16.3 2439 14.4 volume extension to 70000 bbl, permit #306- 266 CD4318 306-181 5/26/2006 CD4-209, CD4-320 942 5/31/2006 8/2l2006 3293 376138.4 5956308.2 18.2 2375 ' 17.1 Unable to um - SD umpin CD42t19 1314 377934.9 5957333.9 14.7 2377 17.5 Not for annular dis sal CD4210 1754 377547.4 5956963.2 18.0 2386 17.3 CD4320 1511 377914.2 5958105.0 17.1 2378 17.8 Not for annular disposal CD417 2837 376416.3 5957221.0 18.1 2387 16.2 Not for annular disposal, due to proximity to Nanuq 3 CD4327 306393 1/2/2007 31177 7/14/2007 8/20/2007 3481 375795.6 5956945.4 18.0 2385 16.3 CD4-214 2248 377040.9 5956962.8 17.3 2365 17.6 Not for annular disposal CD4-211 306392 12/29/2006 CD4302, CD4-16 31937 6/20/2007 7/11/2007 1892 377358.3 5957494.0 18.1 2391 15.0 2nd annular LOT, 1st ann test 18.4 CD4-215 2522 376770.5 5956918.7 17.6 2392 17.50 CD4-213 1973 377446.8 5956586.6 18.1 2389 21.40 Not for annular disposal. High Ann test Probabl ice lu , will retest if needed CD4-302 0 379247.7 5957393.4 18.1 2394 17.10 CD4-16 2678 376571.7 5957499.3 18.1 2388 17.90 CD4306 2114 377254.7 5958097.0 18.0 2377 14.90 * Lateral distance in feet, between surface casing shoes, in the X-Y plane " As of August 31, 2007 Note that this sheet is not the definitive record for annular disposal volumes ~ ~ ~ • • _-- r • ~ HALLIBUR'TON ConotoPhi ~ i ps _____.._______ _ _ __ _ m_ ____~_ __ .__ . Quarter Mile Alaska $perr~r ~riuin~ services (1320 feet) radius plot i ~- Note ta File CD4-302 (207-05fi 307-257) Colville River Unit (Nanuq-Kuparuk) ConocoPhillips Alaska, Inc Phillips Mas made application for annular disposal for the subject well. This document examines the perkinent information for the well and recc~mmends approval ofi ConocoPhillip~ request. --No unusual events were reported while dritfing the surface hole of the wefl. --Surface casing was cemented to surface. No probfems were reported. Approxima#e#y 8G bbls of cemerrt was circulat~t to surfac:e. The n+et cemen# remaining in the surface hale was 52°lo XS af the calculated hole va#ume. --On the initial leak off test, the pressure slope rises with some inflections to the determined F!T point at 1~.1 EMW. Minimal fluid was pumped into the formations, During the observation peric~d, the pressure declined to abou# 15.5 EMW. The initial leak off indicates #hat the surf'ace casing shoe is well cemented. --No problems are reported dr~iting the inter~ediate hole, huw~ver signifcant problems were encountered cementing the T qsing. Hole cleaning issues caused solid bridges in the annulus ~nd it was necessary #o perforate the casing to cement it. The casing was successfully c:~ment~d and iso{ation verifred with a water flow log. --An injectiv'~ijr test down 9-5/8' x 7' annulus was conducted. Pressure steadily increases un#il the break a# 17.9 ENNY. The pressure dec~ines w-ith additional pumping to 14.9 ENNV. During the observation period, the pressure declined to 13.7 EMW. The lower EMW 4# the pump ~n tests indicate that the planned disposal should be conducted a# EMWs below that of the shoe integrity. --CPA provided a listing of al! surfac~ casing shoes within %4 mile radius of CD4-302. The nearest well is CQ4-ZCi8 ~1265 distant wi#h CD4-2~9 ~131t~ distant, Nanuq 3 and Nanuq 5 are beyond the % mile radius. Based on examination of the submitted informat+on, I recommend approval of ConocoPhillip~ request for the subject well. ~~~~'~ Tom Maunder, PE Sr. Petroleum Engineer September 5, 2007 G:\common\tommaunderlWaii Information~By SubjectlAnnuiar Disposa.l\U7U9U5--CD4-302.doc ~ • Note to File CRU CD4-16 (PTD 2061310) CRU CD4-302 (PTD 2070560) ~ CRU CD4-306 (PTD 2070940) August 15, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Wells CD4-16, CD4-302, and CD4-306 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annuli ofwells CD4-16, CD4-302, and CD4-306. Recommendation Approve ConocoPhillips' request. Conclusions The 9-5/8" surface casing shoes are set in these wells between 2,319' to 2,335' true vertical depth subsea ("TVDSS"), near the base of a 35-foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandstone open to the annulus of these wells to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 225' from the wellbores. Discussion CPAI's application was reviewed along with records from nearby wells Nanuk 1 and Nanuk 2. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided, below. The proposed injection interval in these wells lies in the Seabee formation within Section 19, T11N, RSE, UM and in Section 24, Tl iN, R4E, UM, which are 2 to 3 miles from the current boundary of the CRU. The 9-5/8" surface casing shoes of the wells lie at about 2,319' to 2,335' TVDSS, near the base of a 35- foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to range from 3,693' to 3,717' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 40 to 55-foot thick interval containing several 1- to 4-foot thick beds of silty sandstone and sandstone that lie between about 2,400' • CD4-16, CD4-302, and CD4-306 Note to File CJ August 15, 2007 Page 2 of 3 and 2,450' TVDSS, which is just below the surface casing shoe. The aggregate thickness of thin potential injection beds is about 9' to 11'. The injection beds are separated by thin shale and claystone intervals. Beneath the injection zones is a 55' thick interval of shale, claystone and tuff that is continuous throughout the area. This interval, which lies between about 2,565' and 2,660' TVDSS, will provide lower confinement for any injected wastes. Index Map In this area, the base of permafrost occurs at about 700' ~TVDSS in this area. The base of permafrost lies about l,700' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD4-Pad contains methane gas. Records from Nanuk 1 and Nanuk 2 indicate that traces of inethane were first measured between and 460' and 70' TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.9 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of inethane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 1,890' and 2,170' TVDSS, respectively. So, the entire proposed disposal zone may contain some methane gas. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which governs the Nanuq and Nanuq-Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. The shallowest oil shows observed in nearby wells Nanuk 1 and Nanuk 2 occur at 3,765' TVDSS and 4,710' TVDSS, respectively. The mudlogging geologists rated these shows as being fair to good shows in quality. However, these oil shows occur more than 1,000' below the proposed disposal intervals. ~ CD4-16, CD4-302, and CD4-306 Note to File August 15, 2007 Page 3 of 3 The following chart provides an estimate of the affected areas surrounding the affected wellbores. A worst-case assumption will be made. A count of sand in the most likely disposal zone between 2,400' and 2,450' TVDSS indicates that about 10' of net sand can be counted using the gamma ray curve. [nspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sand and siltstone porosity of 12% at this depth. Based on these values, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 225' from the wel lbores. Injected Fluid vs Affected Radial Distance CD4-16, CD4-302, CD4-306 Wellbores (assumes 10' aggregate injection zone thickness and 12% porosity) 300 _ -- - - - - - - ------- -- -- -- ~ ~ i F 250 i - - - ----- ~ -- ~ L _ _ - -- -- I ~ g E --- _ _ - ~ -- ---- -- - ~ ~ _. __ 3 zoo ; - _ - I . _ . :_ , -- -- - E , ~,, - o !-~ - -__ . _ -_ _ ~- I ----. . . __r~'_ . . ._ ' i ='~- ~ ~ -"+ ~ ~ 150 ! _ _ _. _..._ _ _ __ , -'" ~ O : - - . . ,~'~~ . . I i0 ~ /r% ~ ~ ~ ~ . . .l/ . . . ' _ - .' _"'^ "'_ ._--_ ~ D ~~ - ------ ~ , ~ ~: - , m , li ~ Q 50 -~ -- - ~ --- ------- . _ _ y--;-~~-~ ~' /~ ~ - ~ F ~1 I 1- I I '-~~-~~T ~ ~ 0 5,000 10,000 15,000 20,000 25,000 30.000 35,000 Amount ot Injected Fluid (bartels) The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700' of permafrost, and is bounded above and below by continuous layers of claystone and shale. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. This injection zone lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I rec mend approval of this annular disposal project. ~ Steve avies Senior Petroleum Geologist • • • Well CD4-302 Date 7/30/2007 d d ~ ~ ~ ~ c .~ U Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version I.0-lan'OS Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/fr Header Pressure (for wells on gas lift) 1,000 psi ~n ~ Maximum Fluid Densitv to avoid Burst of Surface Casing R v PburstRS% - Pfiydrostatic + PApplied - PFormation : 4,888 = ( Z~ 0.052 * MWmax ) + 1500 - ( 0.4337 * 2 4 ) ~ ~3~5 M p ~ ~~ o~ Wmax = 35.6 p g ~2,3s~'4 TVD Surface Casin~ String ! ~~V~ Size 9.625 W i 40 ~~ h in f g e t pp ~ ~' Grade L 80 ~ ~ f'burst100% 5,750 PS~ Pburst85°/ 4,888 psi Depth of Shoe 2,394 ft FIT/LOT @ Shoe 18.1 ppg or 2,253 psi FIT/LOT for Annulus 17.1 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 4,740' MD 3,749' TVD ~ 4.5 "Tubing ~7,104 TVD 2nd Casing Strin~ Size 7 in Weight 26 ppf Grade L 80 t'collapseloo% 5,410 PS~ Pcollapse85% 4,599 ps~ Top of Cement 3,749 f~ Gas Gradient ~•~~ psi/fr Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax auoWabie = Shoe TVD Depth *.052 * Shoe FIT/LOT Pmax allowable - ( 2,394 * .052 * 18.1 ) Pmax allowable - Z,253 ps- This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". 4,599 = ( 3,749 * 0.052 * MWmax )+ 1,500 - ( 0.0700 * 3,749 ) - 1,000 MWmax = 22.4 PPg Maximum Fluid Densitv avoid Collapse of 2nd Casin~ String Pcollapse85°~ - PHydrostatic + PApplied - PGasGradient - PHeader ~/ ConocoPhillips ,~5~ MALLI BURTON i'wr~ DAW~ ~w~r4w 181~ 90E + ~ s C 0 ~ ~ ~ 0 ~ -90E -181~ -271; c 4-2~a~rc~~4-2nR~ _ CD4-208 (CD4-208PB~ ', _ Ri : CD4-306 (_ • CD4-306 ~ CD4-210 CD4-210 °. I ~ , - ~ - - ~ ~ I I ~I ' CD4-214 CD4 -214 ~ ~ - ' ~ ~ D~ ~ ~ ~ ~213 CD4-213 CD4-211 CD4-211 CD4-209 CD4-209 : ~ - { -- Nanu 5 anu 5 _ -- -- - --- ~ -2717 -1812 -906 0 906 1812 2717 3623 4529 5435 West(-)/East(+) [ft] SURFACE CASING SHOE SEPARATION FROM CD4302 CD4302 x v Surface Casin Shoe ASP 4 Coordinates NAD 27 379247.67 5957393.40 ells Nanuk 7 Nanuk 2 Nanu 3 Nanu 6 Detafls ~ AOGCC'• n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date s ance from Object well• 748 1475 Surtace csg. Shoe X Coord. 76499.5 378326.6 Surtace csg. Shoe Y Coord. 957382. 5956241. Surf LOT (ppg) 1.8 14.9 Surface casing ND (it) 781 2393 Annular LOT (ppg) 5.1 omments Exploration P8A'd Exploratio~ P&A'd Exploration, X-Y location calculated at 24 7VD, NOT the surface shoe de th Not for annular dis osal CD2-378 305-373 12/9/2005 CD4208, CD4318, CD4209, CD4320 32010 12/14/2005 2/2006 2620 377174.7 5955790. 18.4 24 16.1 Dq.~p$ , CD4318 ~,rp;~,~ CD4210 CD4320 306-183 306-181 5/30l2006 5/26/2006 CD4318a, CD4320, CD4214, CD4321,CD4-211 CD4209, CD4320 61 9 94 ' /2006 1/ 1/4/20 8/2/20 65 329 1314 1754 611 378134.2 76138.4 7547.4 3 7914.2 5956792. 5956308. 5957333. 963.2 595 16.3 18.2 14.7 18.0 17.1 2439 2375 2377 23 237 14.4 17.1 17.5 17.3 S 7.8 volume extension to 70000 bbl, permit #3 266 Unable to um SD pum ing Not for annular disposal Not for annular dis osal CD417 ~ 283 76416.3 5957221. 18. 2387 16.2 Not far annular disposal, due to proximity t Nanuq 3 CD4321 CD4214 CD4277 CD4215 n 306-393 306-392 1/2/2007 12/29/2006 CD4302, CD416 19091 + 6/20/200 3481 2248 1892 2522 375 5.6 3 04 3 3 76 59 5. 5 5 2. 9 74 . 5956918. 18.0 17.3 18.1 17.6 2365 2391 2392 16.3 7.6 1. 17.50 Not for annular dis osal annular LOT, 1st ann test 18.4 CD4213 n n 973 377446.8 3T3247. 5956586. 18.1 18.1 238 21.40 17.7 Not for annula ' sal. High Ann test Probabl ice lu , wil rf needed CD416 n 1366 377883.1 5957456. 18.1 2388 17.90 ~, ~ n 1175 378077.4 5957502. 18.0 2377 14.90 ' Lateral distance in feet, between surface casing shoes, in the X-Y plane " As of Nov. Dec. 8, 2006 Note that this sheet is not the definitive record for annular disposal volumes ~~ ~ ~ ! • ConocoPhillips Casing Detail 9 5/8 Surface Casinq Well: CD4-302 Date: 6/7/2007 ~ DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.65 FMC Gen V Hanger 2.26 36.65 Jts 3 to 71 69 Jts 9-5/8" 40# L-80 BTC Csg 2644.03 38.91 Halliburton Float Collar 1.15 2682.94 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 76.63 2684.09 Ray Oil Tools "Silver BulleY' Float Shoe 2.17 2760.72 2762.89 TD 12 1/4" Surtace Hole 2772.89 12 1/4" hole MD 2,773' - 2,397' TVD 9 5/8" csg shoe MD 2,763.89' - 2,389' TVD TOTAL BOWSPRING CENTRALIZERS - 41 1 per jt on Jt #1 -#13 (stop ring on Jt #1 & 3) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67, 69 I I I ~5 joints in the pipe shed. 71 jts to run - Last 4 jts out I I I Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque - 8600 ft/lbs Remarks: Up Wt - 165 k DnWt-144k Block Wt - 75k / D. Burley / L. Hill . ~ ConocoPhillips CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-302 RIG: Doyon 19 CASING DESCRIPTION: 9 5/8", 40# L-80 BTC DATE: 06/07/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 38.33 26 39.32 51 36.66 76 101 126 151 176 2 38.30 27 37.54 52 39.87 77 102 127 152 177 3 37.96 28 38.53 53 39.48 78 103 128 153 178 4 39.07 29 36.05 54 37.18 79 104 129 154 179 5 36.23 30 37.70 55 39.82 80 105 130 155 180 6 36.76 31 37.40 56 38.18 81 106 131 156 181 7 39.84 32 37.Q4 57 38.43 82 107 132 157 182 8 38.98 33 39.60 58 39.62 83 108 133 158 183 9 37.74 34 39.59 59 39.61 84 109 134 159 184 10 39.47 35 39.04 60 39.07 85 110 135 160 185 11 37.45 36 38.98 61 39.88 86 111 136 161 186 12 37.47 37 38.48 62 38.85 87 112 137 162 187 13 37.85 38 38.14 63 37.11 88 113 138 163 188 14 37.89 39 37.29 64 37.59 89 114 139 164 189 15 37.72 40 38.88 65 37.66 90 115 140 165 190 16 39.07 41 39.61 66 39.52 91 116 141 166 191 17 38.39 42 39.86 67 37.63 92 117 142 167 192 18 36.97 43 38.31 68 37.96 93 118 143 168 193 19 39.15 44 35.28 69 38.07 94 119 144 169 194 20 39.07 45 38.55 70 39.06 95 120 145 170 195 21 37.14 46 37.27 71 36.88 96 121 146 171 196 22 37.25 47 39.61 ~ 37.31 97 122 147 172 197 23 38.98 48 37.88 ~3 38.60 98 123 148 173 198 24 39.90 49 38.44 ~4 36.61 99 124 149 174 199 25 39.17 50 37.99 ~3 38.10 100 125 T 50 175 200 Tot 956.15 Tot 956.38 Tot 958.75 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2871.28 DIRECTIONS: TOTAL JOINTS THIS PAGE = 75 FLOAT SHOE 2.25 F~OAT COLLAR 1.12 HANGER RKB 36.65 ~ ~ r = ~..E. Cement Detail Report CD4-302 Security Level: Development ~ig: DOYON 19 ~~~rin ~ ~~ ; . ~~ ~ ° Daily Drilling Report CD4-302 Report Number: 5 Report Date: 6/712007 .~~ 10171479 5,168,091.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) DepYh End (ftK6) Depth Progress (ft) CD4-302 Development NANUQ KUPARUK 6/4/2007 2.80 2,773.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 7,876.61 79,578.05 318,052.61 1,181,685.05 Last Casing String Neut Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,763.OftKB Ops and Depth @ Morning Report 24hr Forecast Picking up DP. Test BOP. PU and stand back DP. PU BHA and RIH. Drill shoetrack and 20' of new hole. CBU. FIT. Change mud to LSND ' and DriIL Last 24hr Summary POOH and laid down BHA. Rigged up and ran 71 jts 9 5/8" casing. Circulated and cemented casing. Tested casing. Nippled down riser. Nippled up and tested BOP. General Remarks Weather Head Count 37 NE @ 21 mph 47.0 ~ .~: ~h<. . . . .. ~.. . . ...~~~.: u;. , t:. ..e,~ . . s.e4, $~;?ItStlr *~ , ~;..~:f T~'~e,,. .... ~~ ~#iz . .. . . ... , , .: ., . ..a. . .. ._.: . ; . .. ... .; , . ~ ::.. ,,.. ~ Dave Burley, Rig Supervisor Rig Supervisor ', Larry Hill, Rig Supervisor Rig Supervisor Scott Lapiene, Rig Supervisor Rig Supervisor 00:00 0130 1.50 SURFAC DRILL TRIP P 1,461.0 170.0 POOH from 1461' to 170' - flow check well at 894', static 01:30 04:00 2.50 SURFAC DRILL PULD P 170.0 0.0 Stand back collars - plug in and check ' MWD calibrations - lay down bha ' components - clear toots from floor and clean up trip mess 04:00 05:45 1.75 SURFAC CASING RURD P 0.0 0.0 Lay down drilling bails - pull riser sleeve - PU casing bails and fiil up tool - RU 9 5/8" slips, elavators and casing tongs 05:45 06:00 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Prejob safety and opts meeting with crew ' 06:00 09:00 3.00 SURFAC CASING RNCS P 0.0 1,724.0 Ran 9 5/8" 40 # L-80 BTC csg as follows: FS (Silver bullet) 2 jts. FC (Halliburton) 2 jts.( first 4 connections made up w/8akerLoc - filled pipe & checked floats) 41 jts. to 1724' (45 jts. total) PUW 140K SOW 115K 09:00 09:30 0.50 SURFAC CASWG CIRC P 1,724.0 1,724.0 Stage pumps up to 6 bpm - CBU - ', FCP=280 psi PUW 135K SOW 124K 09:30 11:00 1.50 SURFAC CASING RNCS P 1,724.0 2,763.0 continue running 9 5/8", 40#, L-80 BTC csg from 1724' to 2723' (71 jts total) MU FMC fluted hanger and land csg w/ FS @ 2,763' & FC @ 2,683' 11:00 11:30 0.50 SURFAC CEMENT RURD P 2,763.0 2,763.0 RD fill up tool - MU cement head and lines 1130 13:15 1.75 SURFAC CASING CIRC P 2,763.0 2,763.0 Establish circulation 4 bpm / 260 psi - stage pumps up to 8 bpm - circulate and condition mud for cementing - FCP=310 psi PUW 165K SOW 144K - Held Prejob safety and opts meeting with rig team Latest BOP Test Data ~ ~... ~. ~mment ~ i ~. ~:~ Page 1/3 Report Printed: 7/27/2007 Security Level: Development ;ig: DOYON 19 Daily Drilling Report CD4-302 Report Number: 5 Report Date: 6/7/2007 13:15 15:15 2.00 SURFAC CEMENT DISP P 2,763.0 2,763.0 Cemented 9 5!8" casing as follows: Rig pumped 40 bbls of viscosified water w/ nutplug marker - line up to Dowell - Pumped 5 bbls of fresh water - test lines to 3700 psi - Dropped btm plug - Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 5.7 BPM @ 195 psi - Mixed & pumped 10.7 ppg Lead slurry (AS~) @ 7.0 BPM / 206 - 266 psi - Observed nut plug marker @ shakers w/ 285 bbls lead slurry pumped - (pumped down surge can 301 bbls total) Switched to tail slurry - Mixed & pumped 50 bbls 15.8 ppg tail slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 5.6 BPM @ 368 psi - Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 184 bbls 9.9 ppg mud @ 8.0 BPM / 380 to 550 psi slowed pump to 3.5 BPM / 430 psi (for the last 4 bbls of displacement) Bumped plug to 1020 psi - Check floats OK - CIP @ 1500 hrs. - Full circulation throughout job w/ 86 bbls 10.7 ppg cement returns to surface - reciprocated pipe while cementing until last 24 bbls of displacement 15:15 16:00 0.75 SURFAC CASING DHEQ P 2,763.0 2,763.0 Tested casing to 3629 psi - holding 3568 psi after 30 minutes - Used Dowell pump for test - bleed off lines 16:00 17:00 1.00 SURFAC CEMENT RURD P 2,763.0 0.0 Rig down cement head and lines. Lay down landing jt. 17:00 18:00 1.00 SURFAC CASING NUND P 0.0 0.0 Nippled down riser. 18:00 18:45 0.75 SURFAC WELCTL NUND P 0.0 0.0 Installed and tested FMC Speed Head. 18:45 20:45 2.00 SURFAC WELCTL NUND P 0.0 0.0 Nippled up BOP and changed solid 3 1/2" rams to VBR. 20:45 00:00 3.25 SURFAC WELCTL BOPE P 0.0 0.0 Set test plug and Tested BOPE 250/3500/5000 psi. Mu+d G he ck [ ?a~~" ~; •;' ' / _ ` ~ ~ ~ ~ ~ `" .,,,. ' YP Ca 3a ' G . e! (3fls~ ~; t~ ,.., 1 {yt#m~? "+,~~e1 {3 9m~ ~ HT Hp Filt L7e~stEy TamP ScrCids, Co[r,-~ ' ry pe o~p~ { iucs} Faer,s {~wg at} vis (siqt) ~v Cstc {cP} fat~ttoo n~} (i ett~flt~} `t~ i~~~' ~'~,~c m~3 ra~ei ~rrt~ ~.:;(m u~~m~j I~;~:., ~'~. .. , ` {'s~) Spud Mud 2,773.0 9.90 60 15.0 20.000 11.0 21.0 27.000 25.0 9.0 75.0 1E~'eGtlt'9~3 ~..3y ~C! . '' '' i.' ' ,~ ~ ~, ~,~ `.r ~~ ~.~ ~ ~ . ; ... .. " .: :~IUid ; ... . , ' Strur~e : ! ~z ~tm~1.8~SS (bb1~ ..:. ~'~„ £3eStirs~ii~n ~t ' Nute Diesel 15.0 CD4-302 to 211 Water 20.0 Same Water Based Mud 1010.0 Same ~7n~~~rari s.~~ +4•;l+t~~`~~~~'~l!~5urf~c~8`~~.~;~'3~i~'~~~~. 1-.:'12114in ~1~ hesGhrist~ts~ri',MXL-1Y,;~'t78~~2; ;':~, ~. ;~ Depth In (ftK6) Depth Out (ftKB) TFA (incl Noz) (in') Noules (/32") IADC Bit Dull String Wt (10001b~ WOB (max) (100... WOB (min) (1000... 114.0 2,773.0 0.53 14l10/14/14 2-4-BT-A-E-2-HC-TD 44 0 0 Drill Strin Com onents -;~Its ;; ~~~~ , ~~;;-. ? :` 7~r; d3esan~t„ ~~~;? ~4 ' ,' ,,,... „ . „; €3D {in~ ~' ~A 4~~ ;. Top Ga~n Sz (~ T ' "~hread ;;:~ h -: ~um i.~ {ft~ ,.;; : Motor with Stabilizer 8 4.947 6 5/8 H 90 30.82 Float Sub 7 7/8 3.000 6 5/8 H 90 33.40 Stabilizer 8 2.875 6 5/8 H 90 40.31 XO Sub 8 3.250 6 5/8 Reg 42.31 Page 2/3 Report Printed; 7/27/2007 MWD (HCIM) MWD (TM) UBHO NMDC NMDC Drilling Jars - Mechanical 24 HWDP 7.98 1.920 6 5/8 Reg 60.20 8.02 3.250 6 5/8 H 90 69.84 8 3.500 6 5/8 H 90 73.21 7 1/2 2.813 6 5/8 H 90 104.18 7 3/4 2.813 6 5/8 H 90 134.97 7 3/4 2.750 4 1/2 I F 169.53 5 3.000 41/21F 893.17 t]rilEirr P ar ameters ' ~' , „ ~`~ ~:~. ;„ .: ~~ : . s F ~ ' S[iciirx,~~~ ~ ~ ° 3~~~" ~~X,i~te ~ , ~ CL~i3n ~ '~`~~ ~~ ~ ~~ ~ ~ ~+:Ptu~ . ` ~ ' , ~ „ .. , PU Str UUt t7stll5fr~Nt 5C3~irYlf , ~ ~ ` ~ v ~ S#8r~ ~ftK~ j ', . ~nd (ff[~B} .. 7ime',{!~~ ~~pth (fE} d ~ ~~ ', Tirr~.~ " Itit~ ~~rP!n) ? :i~4~ 5PP ~PSE~"~., . £i#Hmlbfj . .: ., fi(iQOH3t} , . ,. ,,,~i~6~bfJ Oif 8ttn T 4 , . , i7r~lt~q . .:,:' 2,773.0 2,659.00 22.71 0 0.0 0 2,201.0 0 0 0 0.0 0.0 1iVetii~ore~ ~~' ~~,''. t ... .. , . ,, Wellbore Name Wellbore APi/UWI CD4-302 501032054500 se~ii~rn Size (m) Act roP ~ifKB} - ~[ B3tn~C6~.~ ~... start Bafe:: End Dat~ .. COND1 36 0.0 114.0 2/6/2007 2/7/2007 SURFAC 12 1/4 114.0 2,793.0 6/5/2007 6/7/2007 PROD1 8 3/4 2,793.0 9,287.0 6/9/2007 6/12/2007 ~asin ~trin ' 3~~~..... caser~ De~cript~ n f~s aate ' oQ {ttr~ wt (lasrn~ Gr~ ~aet {5gp~ t't1~Ei ` Coinmgnf . ,.: ,. Surface 6/7/2007 9 5/8 40.00 L-80 2,763.0 Ceinent' ' - .......~.y, ,,,r~~~.: ' ~.~„s~;-'. ~ < .. ~ . a ,. .,,,,,.r. ,,. ,,,. .3 .., '20 'k ~~~, t . __ . ..._-. :a. , , , .,, t Surface - Started 6/7/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD4-302 Surface, 2,763.OftK6 Stg No. Description Top (ftKB) Bottom (ftK6) Q(end) (bbl/... P(final) (psi) Surface 36.6 2,762.9 5 430.0 .n . ... .: ~. Y .... ~IUa~ . . class ~ ~saelSS} . ~~, ~' ~bbl)': ; • ,"~ t]eqts~l~i~db7ga8} ,: Y~i~l fNlsacK~ . ( . .\ ..Y:~~sE~;[ ~aP.{fE~£6j, ;; ' Esi Bkm {ltKB) ., Lead Cement G 340 301.0 10.70 4.63 36.0 2,263.0 Tail Cement G 234 50.0 15.80 1.17 2,263.0 2,763.0 Page 3/3 Report Printed: 7l27/2007 Well Name: CD4-302 Drilling Supervisor: Typ@ Of TeSt: OpenholeTest LOT/FIT Hole Size: 8-3/4" ~ Cas RKB-CHF: 36.7 Ft 2763.0 F Casinq Size and Description: 9-5 Casin Test Mud Weight: 9.9 ppg Mud 10 min Gel: 21.0 Lbl100 Ft2 Test Pressure: 3500.0 psi Rotating Weight: 74000.0 Lbs Blocks/Top Drive Weight 74000.0 Lbs Estimates for Test: 2.7 bbls EMW = Leak-off Pressure + Mud Weight = 0.052 x ND EMW at 2763 Ft-MD (238 aooo 3500 3000 W 2500 ~ ~ N zooo w ~ a ~soo iooo 500 0 0 1015 + 9 9 PIT 15 Secc 0.052 x 2389 ' f Shut-in Press~ I Ft-ND) = 18.1 1005 Lost 50 psi during test, held I 98.6% of test pressure. Ft2 6 687 3 3614 3 120 1.00 8 949 4 3614 4 250 1.50 10 1222 5 3609 5 350 2.00 12 1484 6 3609 6 450 2.50 0.7 bbls 14 1756 7 3609 7 520 3.00 161 20141 I 81 36041 I 81 6001 I 3. 50 I 81 15 3594 11 800 ~ 20 3583 12 860 5.50 1 9.50 1 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ~~CASING TEST tLEAK-OFF TEST O PIT Point PUCTI ed Bled Back PUCTI ed BI@d 68C . S S . S S Tested 9 5/8" csg after bumping plug on cmt. Job Rig: D. Burley PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 6/9/2007 Volume Input Volume/Stroke Pump Rate: Pump used: #1 Mud Pump ~ Strokes ~ 0.10001 Bbls/Strk ~ ~ 8.00 Strk/min ~ ~ Pumping down annulus and DP. ~ Casin Test Pressure Inte rit Test in Shoe Depth Hole Depth Pum in Shut-in Pumpin Shut-in t-MD 2389.0 Ft-TVD 2793.0 Ft-MD 2410.0 Ft-TVD Strks psi Min psi Strks psi Min psi /8" 40#/Ft L-80 BTC ~ 0 0 0 3628 0 0 0.~0 101 Pressure InteqrityTest 2 131 1 3624 1 40 0.25 100 PP9 Mud 10 min Gel: 21.0 Lb/100 Rotating Weight: ####### Lbs Blocks/Top Drive Weight: 74000.0 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1006 psi ~ Summary ~ ConocoPhilli s p Casing Detail 7" Casin_q ~ Well: CD4-302 Date: 6/14/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.40 FMC GenV Hanger 2.30 34.40 Jts 92 to 225 134 Jts 7" 26# L-80 BTCM Csg 5703.27 36.70 WeatherfordlGemoco Stage Collar 2.37 5739.97 Jts 2 to 91 90 Jts 7" 26# L-80 BTCM Csg 3827.09 5742.34 Halliburton Float Collar 1.29 9569.43 Jts 1 to 1 1 Jts 7" 26# L-80 BTCM Csg 42.58 9570.72 Ray Oil Tools " Silver Bullet " Float Shoe 2.08 9613.30 9615.38 7" Shoe @ 9615.38 8 3/4" hole @ 9626.00 *Baffle for Shut -Off plug @' (top of FC jt) 9526.35 8-3/4" Hole TD @ 9,626' MD / 7,104' TVD 7" Shoe @ 9,615' MD / 7,096' TVD Total Centralizers: 61 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. 87 to 96 Straight blade cent. one per jt. on joint #'s 161,162,163 Straight blade cent.one on every other jt.# 165 to 223 235 joints in shed - 225 total jts. to run Last 10 jts. Out Perf above float collar from 9545' to 9547' ( 6 sp~ Use Run & Seal pipe dope Average make up torque 8000 ft/Ibs Remarks: Up Wt - 385 k Dn Wt - 160 k Block Wt - 75k Supervisor: Lutrick / Hill / Lapiene ~ ConocoPhillips ~' CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-302 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 06/14/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 42.58 26 41.95 51 43.04 76 43.37 101 42.24 126 42.48 151 43.58 176 43.57 2 43.08 27 43.41 52 42.58 77 41.45 102 43.41 127 41.87 152 42.16 177 42.99 3 39.75 28 43.50 53 43.41 78 42.37 103 36.94 128 43.44 153 40.03 178 42.64 4 41.75 29 41.86 54 43.29 79 41.95 104 41.36 129 40.74 154 42.14 179 42.41 5 42.92 30 43.45 55 42.94 80 43.13 105 43.14 130 43.47 155 41.56 180 42.35 6 43.10 31 43.55 56 43.47 81 43.50 106 42.53 131 39.96 156 43.08 181 42.67 7 43.45 32 41.03 57 43.35 82 43.10 107 41.98 132 43.35 157 43.52 182 43.01 8 42.49 33 42.09 58 43.52 83 43.44 108 37.68 133 39.53 158 43.58 183 42.81 9 43.58 34 38.99 59 42.77 84 41.86 109 42.34 134 43.49 159 43.46 184 42.83 10 42.65 35 43.03 60 43.51 85 41.73 110 41.90 135 43.11 160 41.77 185 43.46 11 41.34 36 43.46 61 41.10 86 42.34 111 43.58 136 38.95 161 42.40 186 43.03 12 43.45 37 43.45 62 43.49 87 41.89 112 42.56 137 41.48 162 40.50 187 42.02 13 43.46 38 43.60 63 43.00 88 43.16 113 42.92 138 43.57 163 42.10 188 42.69 14 41.84 39 42.84 64 43.41 89 42.67 114 40.90 139 43.48 164 42.56 189 43.46 15 42.72 40 42.62 65 39.60 90 41.08 115 42.76 140 43.47 165 42.86 190 40.93 16 43.46 41 42.64 66 43.01 91 43.46 116 43.56 141 43.46 166 43.58 191 43.46 17 40.68 42 43.52 67 43.47 92 42.02 117 41.86 142 42.77 167 43.54 192 42.86 18 37.19 43 40.92 68 43.43 93 42.89 118 43.57 143 42.73 168 43.43 193 42.60 19 41.15 44 43.48 69 42.82 94 43.54 119 40.97 144 43.46 169 42.32 194 43.46 20 42.23 45 42.77 70 43.45 95 43.52 120 42.99 145 41.68 170 43.54 195 42.98 21 43.53 46 43.47 71 42.04 96 43.51 121 43.46 146 42.95 171 43.44 196 43.43 22 42.95 47 42.19 72 43.43 97 42.93 122 43.57 147 42.23 172 43.36 197 43.44 23 43.45 48 43.46 73 41.30 98 42.12 123 43.47 148 43.45 173 43.47 198 36.66 24 40.16 49 43.47 74 41.74 99 43.69 124 40.33 149 43.57 174 42.67 199 42.88 25 40.99 50 41.95 75 41.35 100 43.21 125 43:57 150 43.44 175 43.21 200 42.24 Tot 1053.95 Tot 1066.70 Tot 1068.52 Tot 1067.93 Tot 1053.59 Tot 1062.13 Tot 1067.86 Tot 1064.88 TOTAL LENGTH THIS PAGE = 8505.56 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 2.1 FLOAT COLLAR 0.92 HANGER 2.4 RKB 34.59 ~ ConocoPhilli s p ~ CASING TALLY PAGE: 2 of 2 WELL NUMBER: CD4-302 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# 1-80 BTCM DATE: 06/14/07 Column 9 Column 10 Column 11 Column 12 Column 73 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 42.75 226 4a-~~ 251 276 301 326 351 376 202 41.92 227 4~-a~ 252 277 302 327 352 377 203 42.28 228 4a-~~ 253 278 303 328 353 378 204 42.40 229 4~:4~ 254 279 304 329 354 379 205 42.47 230 4~-46 255 280 305 330 355 380 206 43.51 231 4~SZ 256 281 306 331 356 381 207 42.76 232 42~9 257 282 307 332 357 382 208 42.17 233 4'~99 258 283 308 333 358 383 209 43.39 234 423~ 259 284 309 334 359 384 210 41.70 235 4~-9~ 260 285 310 335 360 385 211 43.48 236 261 286 311 336 361 386 212 43.28 237 262 287 312 337 362 387 213 43.43 238 263 288 313 338 363 388 214 43.46 239 264 289 314 339 364 389 215 41.20 240 265 290 315 340 365 390 216 42.54 241 266 291 316 341 366 391 217 43.02 242 267 292 317 342 367 392 218 41.31 243 268 293 318 343 368 393 219 42.12 244 269 294 319 344 369 394 220 43.52 245 270 295 320 345 370 395 221 4328 246 271 296 321 346 371 396 222 42.91 247 272 297 322 347 372 397 223 42.21 248 273 298 323 348 373 398 224 42.72 249 274 299 324 349 374 399 225 43.55 250 275 300 325 350 375 400 Tot 1067.38 Tot 426.28 Tot TOTAL LENGTH THIS PAGE _ TOTAL LENGTH = TOTAL JOINTS THIS PAGE _ TOTAL JOINTS = AVERAGE JT = Tot Tot Tot Tot Tot 1493.66 9999.22 DIRECTIONS: 35.00 235.00 42.55 Cement Detail Report CD4-302 Intermediate Casing Cement uescription ob~ectrve Top (ftKB) Bottom (ftK8) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing Block Squeeze 9,369.0 9,415.0 Y~s No No Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 1 1 1 1,050.0 No > No riwa lype riwa oescnption Estimatetl Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 9,369.0 9,415.0 73 G 15.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.10 4.90 15.90 2.50 Additives Additive Type Concentration Conc Unit label ~7~ pi il ~ '.~.., f~' ~, Description Objective Top (ftKB) Bottom (ftKB) Full Retum? Cmnt Rtrn (... Top Plug? Btm Plug? Circulating Squeeze 4,740.0 8,357.0 Yes No No Q (start) (bbl/min) Q (end ) (bbl/min) Q (avg) (bbl/min~ P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 4 720.0 No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK8) Drill Out Diameter (in) Fluitl rype Fluitl Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Squeeze Perforations 4,740.0 8,457.0 218 130.0 Yield (ft'/sack) Mix H20 Ratio (gaUsa... Free Water (°/,) Density (Ib/gat) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 3.35 11.29 11.00 6.50 Additives Security Level: Development Daily Drilling Report CD4-302 Report Number: 12 ~ig: DOYON 19 Report Date: 6/14/2007 ~.~~5~~~~ % N~ ~~, ,~~ .z~~; "f;~.tts~1AFE'~-Sup s"; ~"',:` , ~ ,~,:. ,. , ,,, : r:< . , r ~ . ,..,. 5,,. 10171479 5,168,091.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-302 Development NANUQ KUPARUK 6/4/2007 9.80 9,626.0 9,626.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,732.57 351,867.77 164,493.57 2,704,357.77 Last Casing String Neut Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 9,615.4ftKB Ops and Depth @ Morning Report 24hr Forecast Circulating casing. Circulate casing and cement. tast 24hr Summary Ran 7" casing to 9616'. Landed casing and circulated. Hoie packed off and casing stuck. Waited on and rigged up Slumberger e line. General Remarks Weather Head Count Perfed casing - 20' below baffle plate 9,545' to 9,547'. 2' gun 6 spf. 500 psi on casing when 36 NE @ 9 mph 49.0 shot, perssure bled to 0 and had activity in annulus. ~ ? <. ;~ r,~~s~.;. ~ "•" % T~ ;~ . ..~a~_. >.. .. ~._., . ... ,..< $~. , ..,. ,. Donnie Lutrick, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor 00:00 00:15 0.25 INTRMI CASING CIRC P 5,820.0 5,820.0 Continue to circ and condition mud at 4 bpm at 540 psi. 00:15 04:30 4.25 INTRMI CASING RNCS P 5,820.0 8,938.0 RIH w/ 7" csg from 5828' to 8938'. 0430 06:15 1.75 INTRM1 CASING CIRC P 8,938.0 8,938.0 CBU. Stage pumps to 4 bpm at 430 psi. 06:15 07:30 1.25 INTRM1 CASING RNCS P 8,938.0 9,616.0 RIH w/ 7" csg to 9579'. MU hanger and land csg at 9616'. No hole problems. 07:30 08:00 0.50 INTRM1 CASING RURD P 9,616.0 9,616.0 RD csg running equipment. Blow down top drive. RU cementing equipment. 08:00 09:15 1.25 INTRMI CEMENT CIRC P 9,616.0 9,616.0 Establish circ. Stage pumps to 5 bpm at 560 psi. 09:15 12:00 2.75 WTRM1 CEMENT CIRC T Cement - Other 9,616.0 9,616A " fo rec~proc~~'p~: ~!/eM•packed Primary e~f. ~`pipm. R~tablished circ. Stage pumps to 2 bp~n. 12:00 18:30 6.50 INTRMI CEMENT CIRC T Cement - Other 9,616.0 9,616.0 Atterq~ toreciprocate pipe. Well packed Primary off. Vlforked pipe. Re-established circ. Stage pumps to 2.5 bpm and hole packed off again. Attempted to work pipe, stuck. Regained circulation staged pumps to 4 bRm 17% flow and 380 psi. Hole packed ofF again. Continued working stuck pipe to 465,000 and pressuring up to 1500 psi without movement or returns. 18:30 19:00 0.50 INTRMI CEMENT RURD T Directional Other 9,616.0 9,616.0 Rigged down cement line and head. 19:00 19:30 0.50 INTRM1 RIGMNT SVRG P 9,616.0 9,616.0 Serviced rig. 19:30 22:30 3.00 INTRM1 CEMENT WOEQ T Cement - Other 9,616.0 9,616.0 Rigged up pump in head and waited on Primary Schlumberger and perf guns. 22:30 00:00 1.50 INTRM1 CEMENT RURD T Cement - Other 9,616.0 9,616.0 Spotted up wireline unit and rigged up Primary Schlumberger e line. Water 9,626.0 9.90 37 12.0 20.000 11.0 15.0 17.000 5.3 6.7 9.5 11.5 Based Mud Water 9,626.0 9.80 38 12.0 21.000 11.0 16.0 17.000 5.3 0.0 9.4 11.0 Based Mud Latest BOP Test Data 6!8/2007 250/3500/5000 si Page 1/2 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-302 Diesel Water Water Based Mud COND1 SURFAC PROD1 ~ig: DOYON 19 CD4-302 36 12 1/4 8 3/4 45.0 150.0 845.0 501032054500 Rct~tm~~ ~.;, ', S~art.~a€e 0.0 114.0 2/6l2007 114.0 2,793.0 6/5l2007 2,793.0 9,287.0 6/9/2007 Report Number: 12 Report Date: 6/14/2007 2/7/2007 6/7/2007 6/12/2007 Page 2/2 Report Printed: 7/27/2007 Security Level: Development~ Daily Drilling Report CD4-302 Report Number: 13 ;ig: DOYON 19 Report Date: 6/15/2007 :: ~~r~n~ ~ ~~ ~ N~ ..~~~~ > ' ..., .;. .. ,. , ~~ . ~ :,:: r~~~~u ; ; ,.~ .; ._ 10171479 5,168,091.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftK6) Depth Progress (ft) CD4-302 Development NANUQ KUPARUK 6/4/2007 10.80 9,626.0 9,626.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,214.46 354,082.23 396,019.46 3,100,377.23 Last Casing String Next Casing OD (in) Neut Casing Set Depth (ftKB) intermediate, 9,615.4ftKB Ops and Depth @ Morning Report 24hr Forecast Rigging up Schlumberger. CBU and POOH. RU Schlumberger. RIH and perf casing at bottom of Kup sand. POOH and RD Schlumberger. RIH and set Cement Retainer. Cement casing. POOH. Last 24hr Summary Schlumberger fired gun and POOH. RD wireline and established circufation. Hole packed off after 1/2 hour at 2 BPM. RD and set packoff. RIH with cleanout BHA and drilled out stage collar. Continue RIH and drilled baffle. General Remarks Weather Head Count 36 ENE ~ 8 moh 48.0 Larry Hill, Rig Supervisor Rig Supervisor 00:00 01:45 1.75 INTRM1 CEMENT PERF T Cement - Other 0.0 0.0 PJSM. Make 2 7/8" perf guns. Primary 01:45 03:45 2.00 INTRM1 CEMENT PERF T Cement - Other 0.0 0.0 RIH w perf guns to 20' below baffle plate. Primary Pressure csg to 500 psi. Perf 7" csg with 6 spf from 9545' to 9547'. Pressure bled to 210 psi. 03:45 05:15 1.50 INTRM1 CEMENT PERF T Cement - Other 0.0 0.0 POH w/ guns. RD Schlumberger. Primary 05:15 05:30 0.25 INTRMI CEMENT RURD T Cement - Other 0.0 0.0 Rig up circulating equimpment. Primary 0530 06:00 0.50 INTRM1 CEMENT CIRC T Cement - Other 0.0 0.0 Establish circulation. Stage pumps to 3 Primary bpm at 420 psi. 06:00 07:00 1.00 INTRMI CEMENT CIRC T Cement - Other 0.0 0.0 Annulus packed off. Pressure spiked to Primary 3600 psi. Stage tool sheared open. Increase flow rate to 5 bpm at 230 psi. 07:00 10:30 3.50 INTRM1 CEMENT CIRC T Cement - Other 0.0 0.0 Pump nut plug pill for fluid caliper to Primary confirm stage collar was open. Screen out weil bore strengthing material. 10:30 11:30 1.00 INTRMI CASING RURD P 0.0 0.0 RD circulating equipment. LD landing jt. Pull thin wear bushing. 11:30 12:00 0.50 INTRMI CASING NUND P 0.0 0.0 Install pack off and test to 5000 psi. 12:00 14:00 2.00 INTRM1 CASING NUND T Cement - Other 0.0 0.0 Changed out top rams to 4" and tested. Primary 14:00 15:30 1.50 INTRM1 CEMENT TRIP T Cement - Other 0.0 561.0 Made up cleanout BHA RIH to 561'. Primary 15:30 19:30 4.00 INTRMI CEMENT TRIP T Cement - Other 561.0 5,794.0 RIH from 561' to 5,600'. Closed Annular Primary and estabilished circulation out the casing valve. Opened Hydril and continued RIH to 5,740'. Closed Stage Collar with 20 K down weight. Set 45 K down and pressured casing to 250 psi to confirm Collar clsed. Drilled out Stage Collar. 19:30 20:00 0.50 INTRM1 CEMENT CIRC T Cement - Other 5,794.0 5,794.0 CBU. 423 GPM 100 RPM 1680 psi. Primary Latest BOP Test Data I Page 1/2 Report Printed: 7/27/2007I Security Level: Development Daily Drilling Report CD4-302 Report Number: 13 ~ tig: DOYON 19 Report Date: 6/15/2007 °3~r~[~' ~~ ~ ~~ ;~ ~~:~ . , , ~~' ~...z ~ ~ Sf~f ' Et~i Riu' " ~ ~ ~ ~~~ ? ~ _, ~'~e ` ' ' ; I~GH~~farf ~epth~ftd y„ ; ~~e ` ~ ' ~` ' 1 ime Tim~.; ~hesl. ', ..<Phase ~0~3 k ,.~,, ~p~~r G~sde - ~=~ 7r~1 Cot~ . .. Ttb{ G 1ass. ,:: :.. {#~KB} {~KB} : ~~isin , ~, 20:00 21:30 1.50 INTRMI RIGMNT SVRG P 5,794.0 5,794.0 Slipped and cut drilling line. 21:30 23:15 1.75 INTRM1 CEMENT TRIP T Cement - Other 5,794.0 9,525.0 RIH to 9,508' Singled in 3 jts from pipe Primary shed tagged Baffle @ 9,5 25'. 23:15 00:00 0.75 INTRM1 CEMENT DRLG T Cement - Other 9,525.0 9,526.0 Drilled Baffle. 423 GPM 100 RPM WOB Primary 5/10 K. 2400 psi. ~Ul~ ~ 'r~ll~~ 1~21~R ~°';.. ... ~ ~ ~~~~~ : YP ~ale Gel {i#f~} ~el {~1#knj k GaI ~3 0my r ;, H~t#F F~ ~, : ~td~'~e2r~ So[[ds Ctur. ; ds Ty pQ {~epth (fEKH) ~enS ~Ibfga4) . ~is {sfqij i?Sf Ca~ (cP)', . ~1bf%~OOftT) - {ttsFt]€ft7f~?~ . < (~ft'1t~AA'j (Ib€IStX lR'~ . NtBT {lE~f17ta1).. ,.~~Q!~?~}. P}3' ~~~~ . ..: „ ~°~~ ;"s ' r LSND 9,616.0 9.60 38 7.0 14.000 5.0 7.0 9.000 15.0 9.7 20.0 CD4-302 501032054500 COND1 36 0.0 114.0 2/6/2007 2/7/2007 SURFAC 12 1/4 114.0 2,793.0 6/5/2007 6/7/2007 PROD1 8 3/4 2,793.0 9,287.0 6/9/2007 6/12/2007 Page 2/2 Report Printed: 7/27/2007 Security Level: Development~ Daily Drilling Report CD4-302 Report Number: 14 tig: DOYON 19 Report Date: 6/16/2007 F,;3.,.. ;,;..~ ....., r~us~~v~ ~~~ .~, s.,,_.::. ~ac~ia.~~s~ 10171479 5,168,091.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-302 Development NANUQ KUPARUK 6/4l2007 11.80 9,626.0 9,626.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,154.69 357,236.92 162, 565.69 3,262,942.92 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 9,615.4ftKB Ops and Depth ~ Morning Report 24hr Forecast Pressure up casing to sqeeze cmt in upper perf. Cement squeeze. POOH and CBU. POOH. RIH and perf with e line. Squeeze 2nd zone. Last 24hr Summary Cfeaned casing out to float collar. CBU. POOH and laid down BHA. RU Schlumberger and made 2 Perf runs. Set Cement Retainer on e line above lower perfs. RIH with cement stinger on DP. General Remarks Weather Head Count Squeezed 6 Bbls cement below retainer. Left 9 Bbls on top. 36 NE @ 12 mph 49.0 uonme ~utncK, rcig supe Larry Hill, Rig Supervisor Rig Supervisor 00:00 00:30 0.50 INTRMI CEMENT DRLG T Cement - Other 9,526.0 9,568.0 Finish drilling bafFle at 9525'. Wash down Primary and tag float collar at 9568'. 00:30 01:00 0.50 INTRM1 CEMENT CIRC T Cement - Other 9,568.0 9,525.0 Pull above bafffe at 9525'. CBU at 424 Primary gpm - 2410 psi - 70 rpm 01:00 05:30 4.50 INTRM1 CEMENT TRIP T Cement - Other 9,525.0 0.0 POH w/ bit. Check flow at HWDP. Static. Primary 05:30 06:15 0.75 INTRM1 CEMENT RURD T Cement - Other 0.0 Clear floor. RU Schlumberger eline. Primary 06:15 08:30 2.25 INTRM1 CEMENT PERF T Cement - Other RIH w/ 2 7/8" guns. Perf at the bottom of Primary the Kuparuk sands from 9410' to 9415' - 6 spf. POH. RD Schlumberger. 08:30 10:00 1.50 INTRM1 CEMENT OTHR T Cement - Other Close blind rams. Open lower annulus to Primary pits. Pressure annulus to 1100 psi in 200 psi stages. No fluid to surface. Pressure bled to 500 psi. Establish injection rate at 1 bpm at 750 psi. Pump 5 bbls. 10:00 10:30 0.50 INTRM1 CEMENT OTHR T Cement - Other Pressure bled to 220 psi in 10 min. Bled Primary off pressure. Open well. Monitor well for 15 mins. Fluid loss - 4 bph. 10:30 11:30 1.00 INTRM1 CEMENT RIfRD T Cement - Other RU Schlumberger eline. Primary 11:30 1330 2.00 INTRM1 CEMENT PERF T Cement - Other 0.0 0.0 RIH with Perf gun and Perforate casing Primary from 9,369 to 9,371'. 2' gun 6 SPF. POOH. 13:30 16:00 2.50 INTRM1 CEMENT RURD T Cement - Other 0.0 0.0 Rig down perf gun. Rigged up to run Primary Cement Retainer. 16:00 20:00 4.00 INTRM1 CEMENT OTHR T Cement - Other 0.0 0.0 RIH with Slumberger and set Baker Primary Cement Retainer @ 9,390'. POOH with e line. RD Slumberger. 20:00 00:00 4.00 INTRM1 CEMENT TRIP T Cement - Other 0.0 6,646.0 Made up Stinger and RIH to 6,646'. Primary Water 9,626.0 9.60 Based Mud 15. 9.51 I 9.51 Latest BOP Test Data I Page 1/2 Report Printed: 7/27/2007I Security Level: Development Based Mud :ig: DOYON 19 Daily Drilling Report CD4-302 7.01 9.01 10.0001 5.3 Report Number: 14 Report Date: 6/16/2007 ~ ;~ t3~r~tY Ta~ ~ ~ .: pN= { ~},. t°~} '= ! ' ~ 9 0 ~ 9.5 CD4-302 501032054500 Section ~ "~~^,~e~"~} ..:.: Aet~cap(ftKe}; r : p.~t.s&n~{rt]~E3) ' " ~ ~na;~at,a i~~: ~.,~, . ;,5~t, ., ~~° „~~. COND1 36 0.0 114.0 2/6/2007 2/7/2007 SURFAC 12 1/4 114.0 2,793.0 6/5/2007 6/7l2007 PROD1 8 3/4 2,793.0 9,287.0 6/9/2007 6/12/2007 Page 2/2 Report Printed: 7/27/2007 Daily Drilling Report CD4-302 Security Level: Developmentl Report Number: 15 tig: DOYON 19 Report Date: 6/17/2007 Make up cleanout BHA. Circulate and clean up DP. POOH and lay down BHA. Make up and RIH with Cleanout BHA. Last 24hr Summary RIH and engaged retainer. Established circulation and did squeeze job. POOH 5 stands and CBU. POOH and laid down BHA. Rigged up e line and Perfed casing @ 8,457 - 59'. Made up Cement Retainer and RIH on DP. Set Retainer @ 8,357'. Circulated. Did 130 Bbl Circulating squeeze. General Remarks Weather Head Count 31 NE Ca) 14 mph Foq 49.0 Larry Hill, Rig Supervisor Rig Supervisor 00:00 01:30 1.50 INTRM1 CEMENT TRIP T Cement - Other 6,646.0 9,390.0 RIH and tag cement retainer at 9390'. Primary 01:30 01:45 0.25 INTRM1 CEMENT CIRC T Cement - Other 9,390.0 9,390.0 Sting into retainer. Establish circ through Primary perfs at 1 bpm - 880 psi. Unsting. Circ at 10 bpm for 5 min. Check flow. OK. 01:45 02:15 0.50 INTRM1 CEMENT OTHR T Cement - Other 9,390.0 9,390.0 Break out top drive. Space out DP w/ Primary pup and TIW valve. MU head pin and cement hose. 02:15 02:30 0.25 INTRM1 CEMENT OTHR T Cement - Other 9,390.0 9,390.0 Sting into retainer w/ 25k wt. Pump 1 Primary bpm. Returns were intermittent. Pressure 410 psi to 950 psi. Stage pumps up to 2.5 bpm 1320 psi. Open lower annulus valve. No communication to surface. Pumped 35 bbls. 02:30 02:45 0.25 INTRM1 CEMENT OTHR T Cement - Other 9,390.0 9,390.0 Shut down pumps. Monitor pressure. Primary Pressure bled from 1300 psi to 130 psi in 10 min. 02:45 03:15 0.50 INTRMI CEMENT CIRC T Cement - Other 9,390.0 9,390.0 Unsting from retainer. Close bag. Circ Primary through choke to fill gas buster. Test lines to 2500 psi. 03:15 04:00 0.75 INTRMI CEMENT DISP T Cement - Other 9,390.0 9,390.0 Mixed and displaced 15 Bbis 15.9 PPG Primary cement to the stinger holding 200 psi backpressure on choke. Stabed into Retainer and displaced 6 Bbls of cement @ 1 BPM with returns. Unsting from Retainer dumping the remaining 9 Bbls on the retainer. 04:00 04:45 0.75 INTRM1 CEMENT TRIP T Cement - Other 9,390.0 8,914.0 POH w/ 5 stds DP Primary 04:45 05:15 0.50 INTRM1 CEMENT CIRC T Cement - Other 8,914.0 8,914.0 Circulate surface to surface at 10 bpm at Primary 1940 psi. 05:15 05:45 0.50 INTRM1 CEMENT OTHR T Cement - Other 8,914.0 8,914.0 Close pipe rams. Pressure well to 680 Primary psi. Held pressure for 20 min. Bleed off pressure. Blow down. 05:45 10:45 5.00 INTRMI CEMENT TRIP T Cement - Other 8,914.0 150.0 POH w/ setting tool. Check flow at Primary HWDP. OK. Latest BOP Test Data ` Page 1/2 Report Printed: 7/27/2007I Security Level: Development :ig: DOYON 19 Daily Drilling Report CD4-302 Report Number: 15 Report Date: 6/17/2007 10:45 12:15 1.50 INTRMI CEMENT PULD T Cement - Other 150.0 0.0 Stood back HWDP and laid down BHA. Primary Cleared floor. 12:15 14:45 2.50 INTRM1 CEMENT PERF T Cement - Other 0.0 0.0 Rigged up Schlumberger and RIH with 2' Primary 12 SPF Perf gun. PerFfed casing from 8,457' to 8,459'. POOH and rigged down. 14:45 16:15 1.50 INTRMI CEMENT CIRC T Cement - Other 0.0 0.0 CBU @ 4 BPM 430 psi. Primary 16:15 21:15 5.00 INTRMI CEMENT TRIP T Cement - Other 0.0 8,357.0 Made up Cement Retainer on DP and Primary RIH to 8,357'. 21:15 22:00 0.75 INTRM1 CEMENT OTHR T Cement - Other 8,357.0 8,357.0 Set Retainer @ 8,357'. Stung back in Primary with 35 K on retainer. Established circulation and worked up to 4 BPM 630 psi. 22:00 00:00 2.00 INTRMI CEMENT SQEZ T Cement - Other 8,357.0 8,357.0 PJSM. Circulating squeeze as follows: Primary Switched over to Dowell and tested lines to 3,000 psi. Pumped 20 Bbls of CW-100 @ 4 BPM 600 psi. Pumped 30 Bbls 10.5 PPG Mudpush @ 4BPM 550 psi. Followed with 130 Bbls. Lite Crete mixed at 11 PPG pumped @ 4 BPM 500 to 620 psi 3 Bbls water behind. Switched to Rig and displaced with 79.5 Bbls 9.6 PPG mud at 4.5 BPM 600 to 720 psi. CIP @ 2340 Hrs. Water 9,626.0 9.80 38 8.0 18.000 8.0 11.0 13.000 5.3 9.4 10.0 Based Mud Water 9,626.0 9.70 37 8.0 16.000 7.0 9.0 10.000 5.3 9.0 9.5 Based Mud W+~llbares ' ,,; „ • ,,, . ~...~. ~ ~ ~ ~ ~ ~ ~ ~,r. ~~ ~ ~~,.~.. . ~ ....:~. _ ~,,: :. ,,. , ~ ~~ x: z.. . ~~. ......_,,., ~ Wellbore Name Wellbore A PI/UWI CD4-302 501032054500 secticm Sae(m} ..= A~t3'zsp€~S}=...a~.~~,. ; ~..1~~3rn{it}4f3) . S~~Date :~ !. ~td:~~e , ~ ~ , ;;.; COND1 36 0.0 114.0 2/6/2007 2/7/2007 SURFAC 12 1/4 114.0 2,793.0 6/5/2007 6/7/2007 PROD1 8 3/4 2,793.0 9,287.0 6/9/2007 6/12/2007 Page 2/2 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-302 Report Number: 16 tig: DOYON 19 Report Date: 6/18/2007 ~ <: ~~~ ~ ,,.,,,. .. .... ., ~..: ,, ~~ w : ,, .... m ,, ~~~ ~ ~~ ~ ~.;' ,~~ ~,~-r~~~~. . ~~~ ~ ~5,. . ..~.: ..... .. .: . . ... .,. .: , ~ 10171479 5,168,091.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-302 Development NANUQ KUPARUK 6/4l2007 13.80 9,626.0 9,626.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Totat Cumulative Cost 11,358.33 375,956.93 163,858.33 3,603,072.93 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 9,615.4ftKB Ops and Depth ~ Morning Report 24hr Forecast POOH. POOH and run USIT log. If good cement RIH with bit and scraper. Last 24hr Summary Circulated and POOH. Made up cleanout BHA. RIH and drilled out cement and retainers to 9,569'. Pumped hi vis and circulated clean. POOH to 8597'. General Remarks Weather Head Count 35NE@8mph 49.0 > ::.. _ . SuperviStN ,,;" ~f , , , y . . . ,. , . .: :..: ~ ~E~i@ ; , i'~` '' ~fi 3; !r£,....:.. p ~~~~.,, . .~ . '.~~: .:..:.. ;.. ,,~,,, .: .~„ZC. ~ ;. . , s ,.. ,. :_':.. Donnie Lutrick, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor 00:00 00:15 0.25 INTRMI CEMENT TRIP T Cement - Other 8,357.0 8,043.0 Unsting from retainer. RD cement Primary equipment. LD one single. POH and std back 3 stds drill pipe. 00:15 00:45 0.50 INTRMI CEMENT CIRC T Cement - Other 8,043.0 8,043.0 Circulate from surface to surface at 10 Primary bpm at 1880 psi. Blow down lines. Pump dry job. 00:45 06:15 5.50 INTRM1 CEMENT TRIP T Cement - Other 8,043.0 0.0 POH w/ stinger. Check flow at HWDP. Primary OK. 06:15 07:45 1.50 INTRM1 CEMENT PULD T Cement - Other 0.0 245.0 MU junk mill and bit sub. PU and RIH 8- Primary 4 3/4" DCs. 07:45 12:00 4.25 INTRM1 CEMENT TRIP T Cement - Other 245.0 8,217.0 MU 1 std HWDP. Circulate through DC's Primary to clear rust. RIH to 8217'. Fill pipe every 20 stds. 12:00 12:30 0.50 INTRM1 CASING DHEQ T Cement - Other 8,217.0 8,217.0 Rigged up and tested casing to 3500 psi Primary for 10 Min. OK 12:30 14:30 2.00 INTRMI CEMENT DRLG T Cement - Other 8,217.0 8,460.0 Washed down from 8,217' to 8,356'. Primary Tagged Retainer. Drilled Retainer and cement to 8,460'. WOM 5/10 K 300 GPM 1430 psi 110 RPM. 14:30 17:00 2.50 INTRM1 CEMENT DRLG T Cement - Other 8,460.0 9,133.0 Washed down from 8,460' to 9,133'. Primary Tagged Retainer. 17:00 21:00 4.00 INTRM1 CEMENT DRLG T Cement - Other 9,133.0 9,569.0 Drilled Retainer and cement, cleaned out Primary to 9,569'. WOM 5/10 K 300 GPM 1820 psi 100 RPM. 21:00 22:30 1.50 INTRMI CEMENT CIRC T Cement - Other 9,569.0 9,569.0 Pumped sweep and circulated casing Primary clean. 300 GPM 110 RPM 1560 psi. 2230 00:00 1.50 INTRM1 CEMENT TRIP T Cement - Other 9,569.0 8,997.0 Flow check. Pumped dry job and POOH Primary on trip tank from 9,569' to 8,997'. Water 9,626.0 9.80 40 14.0 21.000 12.0 22.0 31.000 Based Mud Water 0.0 9.70 37 8.0 13.000 6.0 8.0 9.000 Based Mud Latest BOP 6.1 9.OI I 9•5 6/8/2007 250/3500/5000 si Page 1/2 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-302 Report Number: 16 Diesel Water Water Water Based Mud Water Based Mud UV~IIba'r~s .; - Wellbore Name tig: DOYON 19 45.0 44.~ 300.0 136.0 1455.0 11.0 CD4-302 501032054500 SecC~La9 , Size (in `. Acf';T9p {ftKR ; 1X~t~im {?IFt$) ~. ,,,- Sts~f i~ate - ~ ~; . Errd Date i,j-. ; COND1 36 0.0 114.0 2/6/2007 2/7/2007 SURFAC 12 1/4 114.0 2,793.0 6/5/2007 6/7/2007 PROD1 8 3/4 2,793.0 9,287.0 6/9/2007 6/12/2007 Page 2/2 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-302 Report Number: 17 tig: DOYON 19 Report Date: 6/19/2007 00:00 06:45 6.75 INTRM1 CEMENT TRIP T Cement - Other 8,597.0 798.0 Continue POOH on TT f/ 8597' to 798' - Primary Flow ck (static) 06:45 07:45 1.00 INTRM1 CEMENT PULD T Cement - Other 798.0 0.0 Std back HWDP - Jars - 2 stds SDC's - Primary LD 2 SDC's - bit sub & junk mill 07:45 08:00 0.25 INTRM1 CEMENT OTHR T Cement - Other 0.0 0.0 Monitor well on TT - perform house Primary keeping on rig floor - Prep for wireline work 08:00 12:00 4.00 INTRM1 EVALWB ELOG T Cement - Other 0.0 0.0 PJSM w/ rig crew & Schlumberger - RIH Primary w( USIT log 12:00 14:00 2.00 INTRMI EVALWB ELOG T Cement - Other 0.0 0.0 Finish USIT log. Log interval - 9540' to Primary 4000'. RD Schlumberger. 14:00 19:00 5.00 INTRMI DRILL TRIP P 0.0 8,356.0 MU and RIH with casing scraper BHA on 4" DP to 8356'. 19:00 20:30 1.50 INTRMI RIGMNT SVRG P 8,356.0 8,356.0 Slip and cut drilling line. Service top d rive. 20:30 21:00 0.50 INTRM1 DRILL TRIP P 8,356.0 9,498.0 R1H with 4" DP from 8356' to 9498'. 21:00 22:00 1.00 INTRMI DRILL CIRC P 9,498.0 9,569.0 Wash down from 9498' to 9569'. CBU at 300 gpm at 1660 psi. 22:00 23:00 1.00 INTRM1 DRILL CIRC P 9,569.0 9,569.0 PJSM. Displace well to 9.2 ppg brine. 23:00 00:00 1.00 INTRMI DRILL TRIP P 9,569.0 9,308.0 Flow check. Blow down. POH on trip tank from 9569' to 9308'. ~~~. . ~y.p~]~ , c~FRR ~~ y, ....; . : ..., , . ;. ,,, ~ ~~i~c., .: ... ~~~ :~~ . ~ :A .J~E,...i ;~h ,,,; , f /~~~ ;~~tic~ ~Y ; ` Pe ~~ C~~t f ! #>f ~i} .L~ris (#~f9 ' - at~: .~1'as ~~Fc~) PY ~[~ {ep) ~.C~ {IE~'l~~ 1C ~"" '~ ~I ~1{1Qs} ~~ l~I4#)t3ft*~ ~ff ~....: - {~6m} f~lpti') ~6i~~ ~1t trTj~, ". ~ ; Iv~#T .' 7 k ~1#+tb6t~~ .~ ~ P~iii ~x I~S[tYT~mp ~Ot~dB ~C+CN. ~tkr~in °~d : , : .. {°F~ : ~°1n} ,-; '' .. . ~ BRINE 9,616.0 9.20 i~i ,ta~E;~~t ,,ir ~ . . ,~~ ~d ` ..a' =' n.<~..~:~ ~ ,::, ,. :,- ; ~,~', ; . ~ y ~~ ~a -: r F1uid ,s; c,.~ ~ ".~r r:e \. -- Frmn Le~se (6b13... ;, € . ~..; i D~s#inatiort ;~~ x i~e ,,, ,a, Diesel 20.0 CD4-211 VVS11bi~res': ;. ~ r ~~ ,~,.;r.. ~~.:.,.. ~,:, .. ~ , „.~ ., ~ ,,,:,. : ~.. ,. x ~;~..... ..,: : ~ Wellbore Name Wellbore API/UWI CD4-302 501032054500 ~ , -€~n ~~, ize (in~ ~f~x ,..~: Ac~'.~c~p {ftK6)< "" Aet ~ttm {1,51~~ 'Start ~ate ;~;E~C1 L~at~ COND1 36 0.0 114.0 2/6/2007 2/7/2007 SURFAC 12 1/4 114.0 2,793.0 6/5/2007 6/7/2007 PROD1 8 3/4 2,793.0 9,287.0 6/9/2007 6/12/2007 Latest BOP Test Data ..._.,..... ... . _ . .... ....... . ... , ..... _ 6/8/2007 250/3500/5000 si Page 1/1 Report Printed: 7/27/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-302 Drilling Supervisor: Rig; Lutrick / Hill Doyon 19 Date: 6/18/2007 Pump used: cement unit I~ ~ P i d Volume Input ~rrels ,~ Pump Rate: ~ sbls/strk ~ 0.80I Bbl/min ~ Typ@ Of T@St: Annulus Leak Off Test for Disposal Adequacy ng ump own annulus. ~ ~ asin Test ressure In te rity es1 Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pumping Shut-in Pumpin Shut-in RKB-CHF: 34.2 Ft 2762.0 Ft-MD 2394.0 Ft-N 4740.0 Ft-MD 3749.0 Ft-ND Bbls psi Min psi Bbls si Min si Casina Size and Descriation: 9-5/8" ao#/~t ~-so sTC ~' 0 0 35 0.00 566 Enter outer casing shoe test results in comments Mua weignt: y.~ ppg ~ ~ zsu u.5u 555 Casing description references outei casing string Inner casing OD 7.0 In. 3 1.5 261 1.00 532 Hole Size is that drilled below outer casing. 4 2 331 1.50 522 Use estimated TOC for Hole Depth 5 2.5 405 2.00 518 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 444 2.50 512 Estimates for Test: 647 psi 0.3 bbls 7 3.5 519 3.00 511 ~ ~~' 8 4 582 3.50 506 ~ EMW = Leak-off Pressure + Mud Weight = 908 + 9 8 _ PIT 15 Second 9 4.5 647 4.00 505 0.052 x TVD 0.052 x 2394 Shut-in Pressure, s~ 10 5 680 4.50 508 EMW at 2762 Ft-MD (2394 Ft-TVD) = 17.1 564 15 5.s 735 s.oo 500 ioao , , ~ ~ ~ 20 6 770 5.50 498 w ~ ~ N 500 W OC a 0 o- ~ + + ~ ~ ~ o z a s a ,o ,z o s ,o ,s zo zs 30 ~ Volume Volume Volume Vol Barrels Shut-In time, Minutes ~~CASING TEST ~LEAK-OFF TEST O PIT Point PUf11 ed BI@d 68Ck PURI @d Bled . s s . s ;: casmg s oe = . ppc Back CD4-302 Annular LOT vtj Summary osi22io~ i ao~~iy C~'z.C c~0~ -p5"~ • ~~'~~~I~~~I~I~~~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # ~~~.~~,~ ~~.~~ "~. ~U~ ~ ~~ L~JI~! ni~ska ~il RR Caa~ ~;ons.!,;o~~>>,~i:~~;~ ,~, ,~~~c'r~cJr~g2 NO. 4380 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine co~or Log Description Date BL Prints CD CD4-306 11837479 PERF RECORD/SBHP SURVEY 07/28/07 1 CD4-306 11837479 SCMT 07/28/07 1 CD4-302 11837478 RSTI WFL 07/27/07 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ~ ~ • 30-Ju1-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-302 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.50' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 9,626.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 / ~ ~ Date 3 0~1 ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) p~,C~`2 - c~~ ~ ~ i i Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Thursday, August 23, 2007 9:47 AM To: Maunder, Thomas E (DOA) Subject: RE: Annular Disposai Applications CD4-16, CD4-302 and CD4-306 Attachments: CD4-302 Annular LOT vtj.pdf I just saw that also. Liz From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, August 23, 2007 9:42 AM To: Galiunas, Elizabeth C Subject: RE: Annular Disposal Applitations CD4-16, CD4-302 ~nd CD4-306 Page 1 of 2 Liz, Thanks for the proximity listings. 1 already have the CD4-16 pump-in. What is needed is the pump-in for CD4- 302. Look forward to your reply. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Thursday, August 23, 2007 7:09 AM To: Maunder, Thomas E (DOA) Subject: RE: Annular Disposal Applications CD4-16, CD4-302 and CD4-306 Here you go, Tom. Thanks for catching the missing information. I am not sure how the CD4-215 Annular LOT got in there. We will not need these permits for another 2 weeks, so there is no rush. Hope you are doing well, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (90"~-265-6247 Cell: (9Q7}-441-4~'11 From: Maunder, Thomas E (DOA) [maitto:tom.maunder@alaska.gov] Sent: Wednesday, August 22, 2007 12:34 PM To: Galiunas, Elizabeth C; Noel, Brian; Alvord, Chip; ]ohnson, Vern 8/29/2047 ~ ~ Page 2 of 2 Subject: Mnular Disposai Appiications CD4-16, CD4-302 and Cp4-306 All, I am working on these applications. One item missing is the spreadsheet ~that summ,arizes the well proximity information. I'd appreciate if someone would send rr~ the appropriate sheets. Call or message with any questions. Tom Maunder, PE AOGCC 8/29/2007 i ~ ~~~~~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ ~~~~01 ANNULAR DISPOSAL APPLICATION ,~,,~~ ~,, ~,, ~,~~ ~~~~ ~~~;~,s,,,~~ Zo aac z5.o$o ti ~~ ,; ...,,,. 1. Operator 3. Permit to ill Name: Number' 207-056 ConocoPhillips Alaska a. aPi mber: 50-103-20545-00 2. Address: 5. ell P.O. Box 100360, Anchorage, Alaska CD4-302 . Field: Colville River Field 7. Publicly recorded wells 8. Stratigraph' description: a) All wells within one-quarter mile: a) Interval posed to open annulus: CD4-2Q$, CQ4-249, CQ4-306 rok and Seabee formation, shale, siltstone and sandstone / b aste receiving zone: ~ b) water wells within one mile: and layers below the C30 marker in the Seabee formation None ~ Confinement: ~ he Sc rader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: f i U 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 160 None 11. Previous volume disposed in annulus and date: 2. Estimated slurry density: 13. Maximum anticipated pressure at shoe: ~ None densities range from diesel to 12#/gal 2253 14. Estimated volume to be disposed with this req 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- completion fluids diesel formation fluids associated with the contaminated drilling mud 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 20-Aug~~~ needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup ~ fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and ~I ~ any other fluids associated with drilling a well. 17. Attachments: ~ Well Schematic (Inclu MD and Tl/D) ^ FIT Records w/LO7 Graph Q Cement Bond Log (if required) ^ Surf. Casing Ceme ing Data ~ Other ~ previous authorization for new aroduct cleanup fluids for CD1 and CD2 18. I hereby certify that th foregoing is true and correct to the best of my knowledge. : ~! (r-~ Title: ~J'~4/ / /d!"*l~n~f ~''~f /ncG~ Signature: ~~t...,. . Printed \ ~- N ~ ~ ~ Phone / ~ N b ~~~~ ame: r W U• o Chip Alvord um er. 265-6120 Date: Commission Use Only Cond' ons of approval: LOT review and approval: ~, fi~'~ Subsequent form required: , ' Approval number: ~ ~ APPROVED BY Approved by: .. ._ .. COMMISSIONER THE COMMISSION Date: Form 10-403AD Rev. 6/2004 (~~~~~~~~'RUCTIONS ON REVERSE ~ Submit in Dupli ~~(~J - U ~„~ ~'/~-D`'/ ~ 1 • • ConocoPhillips Alaska, Inc. Post Office Box 100360 ~ ~ Anchorage, Alaska 99510-0360 ~~~~~~~~1' ~ Telephone 907-276-1215 ~~~r ~ ~~~ ~ August 1, 2007 ~~~ ~~' ~ ~ ~~~~ ~~I~~~~ ~i~ ~~ ~~~ ~~~~s. ~~m~m`s~~i~~~ Alaska Oil and Gas Conservation Commission 333 West 7`~ Avenue, Suite 100 ~~ ~~~'s'"~~`~ Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinE Waste on well CD4-302 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-302 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-302 approximately August 20, 2006. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within 1/4 mile radius at AOGCC: Wells attached with CD4-16 sundry 12. Copy of previous authorization (CD 1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (17.1 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.1 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. The intermediate section on CD4-302 was not cemented conventionally. With the casing on bottom, the rig could not circulate. Therefore, the casing was perforated above the shoe track. After perforating, circulation was still not possible. A second set of perforations were added above the Kuparuk C sand and a suicide squeeze attempted between the two sets of perforations. 6 bbls of Cement was squeezed away. To cover the Nanuq and Qannik horizons, another set of perforations was added below the Nanuq sand and cement was pumped with full returns to above the Qannik. A CBL was done and indicated good isolation between the horizons. On 7/27/2007, a water flow log was done indicating no channeling above the perforations (at 9398'-9413') into the Kuparuk C sand. These operations can be found in more detail in the attachments. • . ConocoPhillips Alaska, Inc. ~,/ Post Office Box 100360 ~"~~ Anchorage, Alaska 99510-0360 ~~~~~~~~' ~ ~ ~ ~~ Telephone 907-276-1215 If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Gal' as Drilling Engineer cc: CD4-302 Well File Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1530 • • Annulus Disposal Transmittal Form - Well CD4-302 AOGCC Reeulations. 20 AAC 25.080 (b) 1 Desi nation of the well or wells to receive drillin wastes: CD4-302 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water we11s within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maJCimum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2253 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOTlFIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-07, CD4-304, CD4-303 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: AIlsup-~rake, Sharon K [Sharon.K.Alisup-~rake@conocophiflips.com] Sent: Friday, August 10, 2007 8:18 AM To: Maunder, Thamas E (DOA) Cc: Galiunas, Elizabeth C; .fohnson, Vem Subject: RE: CD4-302 (207-056) the corrected copy will be coming over in this morning's courier. I'll put your name on the envelope. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, August 09, 2~7 3:44 PM To: Atisup-t7rake, Sharon K Cc: Stephen F Davies Subject: CD4-302 (207-056) Sharon, I tequesf that you send us a revised 407 for this well. The numbers entered in btocks 9~nd 1d are the same and they shauld not be. According to the a~rations ceports, the well was TDed at 9626' md and 71A4` tvd (16:QQ 6/12/07). This is the correct entry for biock 10. 7" casing was stuck with the shoe at 96'f6' md (07:3Q 6/'[4/07). The float coitar was tagged at 9568' md (00:30 6/16i07} and after ali the squeeze wcxk the well was cieaned out to 9569' md (21:00 6/18J07). 9569' md is the pfug back measured depth. No neecf to inetc~de any of the attachments, just page 1 of the 407. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 8/10/2007 ~~,~;~,~ v ~~ ~ STATE OF ALASKA • AtJG ~ 4 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION a Cans• Cor~-m~sx~o~ WELL COMPLETION OR RECOMPLETION REPOR~''~~at8"~`~,~e 1a. Well Status: Oil ~ Gas Plugged Abandoned Suspended ~ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG Q Other ^ No. of Completions: 1b. Well Class: Development ~ Exploratory ^ Service ^~ ` Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or,4band.: June 21, 2007 ~ 12. Permit to Drill Number: 207-056 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 5, 2007 ~ 13. API Number: 50-103-20545-00 4a. Location of Well (Governmental Section): Surface: 2887' FNL, 90' FEL, Sec. 24, T11N, R4E, UM ~ 7. Date TD Reached: June 12, 2007 14. Well Name and Number: CD4-302 Top of Productive Horizon: 1833' FSL, 848' FWL, Sec. 20, T11 N, RSE, UM 8. KB (ft above MSL): 50' AMSL Ground (ft MSL): 56' MSL 15. Field/Pool(s): Colville River Field Total Depth: 1 S15' FSL, 1006' FWL, Sec. 20, T11 N, R5E, UM 9. Plug Back Depth (MD + ND): ~ 9569' MD / 7062' ND ` Nanuq Kuparuk Oil Pool ° 4b. Location of Weil (State Base Plane Coordinates): Surface: x- 378155 ~ y- 5957521 : Zone- 4 10. Total Depth (MD + ND): 9626' MD / 7104' ND 16. Property Designation: ADL 384211,r380077 ' TPI: x- 384047 y- 5956869 Zone- 4 Total Depth: x- 384204 ~ - 5956849 Zone- 4 11. SSSV Depth (MD + TVD): landing nipple @ 2197' 17. Land Use Permit: LAS2112 18. Directional Survey: Yes Q No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1250' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res, Dens/Neu, USIT, CCL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETfING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 79 bbls 9-5/8" 40# L-80 37' 2763' 37' 2389' 12.25" 34o sx AS Lite, 234 sx Class G 7" 26# L-80 37' 9615' 37' 7096' 8.75" 218 sx LiteCRETE 23. Open to production or injection? Yes a No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 9238' 8377', 9164' 9398'-9413' MD 6 spf - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9369'-9371' MD 6 bbls cement 9410'-9415' MD see above 26. PRODUCTION TEST Date First Production July 5, 2007 Method of Operation (Flowing, gas lift, etc.) Seawater injector Date of Test 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 Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No ~/ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analyfical resutts per 20 AAC 25.071. G0INFLE7~{pN NONE ~ ~- ~- ~'~ GF~~! Form 10-407 Revised 2/2007 CONTINUED O s~~L A~~ ~~~DD7 ~5s(~ J~ ~~3~~ ORI~INAL ~ ~ ~ ~ ~r s Ct~rloCO~'h~ll~ps J u ly 27, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-302 (APD 207-056) Dear Commissioner: ~~~~f~~~ .1UL 3 i 2Q~7 ~laska Oi6 ~ Gas ~ar?.;. i:~~;~~r;~vl~~i t~~~E~~ar~~;a ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-302. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, 1:,-~-~._..,: ~. ~~ ~-~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells . G. C. Alvord Alpine Drilling Team Leader Drilling & Welis P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad • STATE OF ALASKA ~ °~ ~' ~~ 2OO I ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~,~,;~,~ ~~;_ ~:~ ~ ~Qns. C~mmiss~o WELL COMPLETION OR RECOMPLETION REPORT AND ~~,~ ;,.rsP~ 1a. Well Status: Oil ~ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG Q Other ^ No. of Completions: 1b. Well Class: Development ~ Exploratory ^ Service 0` Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: June 21, 2007 ~ 12. Permit to Drill Number: 207-056 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 5, 2007 ~ 13. API Number: 50-103-20545-00 4a. Location of Well (Governmental Section): Surface: 2887' FNL, 90' FEL, Sec. 24, T11N, R4E, UM ~ 7. Date TD Reached: June 12, 2007 ~ 14. Well Name and Number: CD4-302 Top of Productive Horizon: 1833' FSL, 848' FWL, Sec. 20, T11 N, R5E, UM 8. KB (ft above MSL): 50' AMSL Ground (ft MSL): 56' MSL ' 15. Field/Pool(s): ~ olville River Field Total Depth: 1815' FSL, 1006' FWL, Sea 20, T11 N, R5E, UM 9. Plug Back Depth (MD + ND): ' 9626' MD / 7104' TVD • Nanuq Kuparuk Oil Pool % 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378155 ~ y- 5957521 ' Zone- 4 10. Total Depth (MD + ND): , 9626' MD / 7104' TVD ~ 6. Property Designation: ~, ADL 384211, 380077 ' TPI: x- 384047 y- 5956869 Zone- 4 Total Depth: x- 384204 ° - 5956849 • Zone- 4 11. SSSV Depth (MD + TVD): landing nipple @ 2 17. Land Use Permit: LAS2112 18. Directional Survey: Yes ^~ No~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1250' ND ~- 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res, Dens/Neu, USIT, CCL 22. CASING, LINER AND CEME ING RECORD SETTING DEPTH MD SE G DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM T P BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 7s bbls 9-5/8" 40# L-80 37' 2763' 37' 2389' 12.25" 340 sx AS Lite, 234 sx Class G 7" 26# L-80 37' 9615 37' 7096' 8.75" 218 sx LiteCRETE 23. Open to production or injection? Yes ~ No ~ If Y, list each 24. TUBING RECORD Interval open (MD+~1/D of Top & Bottom; Perforation Size Nu er): SIZE DEPTH SET (MD) PACKER SET 4.5" 9238' 8377', 9164' 9398'-9413' MD 6 spf . /~ ~ ~• 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Q•\ v DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9369'-9371' MD 6 bbls cement ~ 9410'-9415' MD see above 26. PRODUCTION TEST Date First Production July 5, 2007 ~ Method of Operation (Flowing, gas lift, etc.) - Seawater injector Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OiL RaTlo 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 Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No / - If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. i ti:(1;~AP1.~7101~1 DATE NONE -~~' ~+~ VER @! Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE QR~GINAL ~ ~~~~ ~ ~ 28. GEOIOGIC MARKERS (List all formations and mar rs encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, Pemlaf~ost - Top surtace surface briefly summarizing test results. Attach separate sheets to this form, if PermBfrost - BOttOm 1249' 1250' needed, and submit detailed test information per 20 AAC 25.071. C-30 2785 2405' C-20 3345' 2787' K-3 4826' 3809' K-3 Base 5139' 4025' K-2 5193' 4062' K-2 Base 5342' 4164' ALB 97 7889' 5905' Nanuq 8270' 6165' H~ 8933' 6615' HRZ base 9233' 6824' N/A K-1 9284' 6859' Kuparuk D 9352' 6907' Kuparuk C 9398' 6939' Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. COntaCt: Liz Galiunas @ 265-6247 Printed Name Chiq Alvord ~ y Title: WNS Driliinq Team Lead ~ ~~3~/0 ~ Si nature /~ 77w~ Phone Date g ZG s ~`cj, 5, . INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Senrice wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposai, 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: TP! (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one intervai (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ ~ Cc~nc~cc~Ph~llips Time Log Summary LtielN7ew Web Reyorting Well Name: CD4-302 Job Type: DRILLING ORIGINAL 06/03/2007 12:01 00:01 12.00 MIRU MOVE MOB P Prep rig for move - Move motor & pit complexes - Jack floor to moving postion - Move rig & complexes to staging area on CD2 well row - Move ball mill & motor complex f/ CD2 to CD4 - Pit com lex in route to CD4 06/04/2007 00:00 12:00 12.00 MIRU MOVE MOB P Continue moving pits - pipe shed - rig mats & ri f/ CD2 to CD4 12:00 13:30 1.50 MIRU MOVE MOB P Finish moving rig to CD4 13:30 17:00 3.50 MIRU MOVE PSIT P Spot rig over well - set feet - Skid floor into drilling position - Move pit & motor complex into position - hook up service lines - Rig on high line power @ 1600 hrs. Acce t ri 1500 hrs 17:00 19:30 2.50 SURFA DRILL RURD P NU surface riser - flow line & drain lines 19:30 23:30 4.00 SURFA DRILL PULD P PU 5" Dp & HWDP f/ pipe shed & stand back in derrick 2330 00:00 0.50 SURFA RIGMN SVRG P Slip & cut drilling line - service TD 06/05/2007 00:00 01:00 1.00 0 0 SURFA RIGMN' SVRG P Slip and cut 60' of drilling line. 01:00 04:00 3.00 0 114 SURFA DRILL PULD P Picked up BHA. 04:00 04:45 0.75 114 114 SURFA DRILL SFTY P Pre Spud meeting. Filled hole and tested lines to 4000 si. 04:45 12:00 7.25 114 618 SURFA DRILL DDRL P Spud well @ 0445 hours. Drill 12 1/4" hole w/ motor f/114' to 618' MD 618' ND ADT 3.71 Hrs ART 3.06 Hrs AST .65 Hrs. WOB 10/15 k RPM 50 GPM 450 @ 1100 psi String wt. PU 105 SO 100 Rot 100 Torque on/off btm. - 6000/5000 ft/Ibs. 4 G ro surve s 12:00 00:00 12.00 618 1,905 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/618' to 1905' MD 1790' ND ADT 8.64 Hrs ART 5.25 Hrs AST 3.39 Hrs. WOB 20/30 k RPM 50 GPM 605 @ 2201 psi String wt. PU 130 SO 125 Rot 130 Torque on/off btm. - 7000/5500 ft/Ibs. ~ ~ 06/06/2007 00:00 12:00 12.00 1,905 2,550 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/1905' to 2550' MD 2250' ND ADT 8.6 Hrs ART 6.5 Hrs AST 2.1 Hrs. WOB 20/30 k RPM 50 GPM 650 @ 2450 psi String wt. PU 140 SO 125 Rot 135 Tor ue on/off btm. - 8000/6500 ft/Ibs. 12:00 14:45 2.75 2,550 2,773 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/2550' to 2773' MD 2397' ND ADT 2.41 Hrs ART 1.68 Hrs AST .73 Hrs. WOB 20/30 k RPM 50 GPM 650 @ 2680 psi String wt. PU 140 SO 130 Rot 135 Tor ue on/off btm. - 8500/7000 ft/Ibs. 14:45 15:30 0.75 2,773 2,773 SURFA DRILL CIRC P Circulated hole clean. 655 GPM 2500 si 80 RPM. 15:30 18:45 3.25 2,773 894 SURFA DRILL WPRT P POOH backreaming from 2,773' to 894' 600 m 60 r m. 18:45 19:30 0.75 894 2,773 SURFA DRILL WPRT P RIH from 894' to 2,773'. 19:30 20:15 0.75 2,773 2,773 SURFA DRILL CIRC P Circulated hole clean. 655 GPM 2500 si 80 RPM. 20:15 20:45 0.50 2,773 2,773 SURFA DRILL TRIP NP POOH on trip tank to 2,506' Hole fill not correct. RIH to 2,773'. 20:45 21:45 1.00 2,773 2,773 SURFA DRILL CIRC P Circulated hole clean. 655 GPM 2500 psi 80 RPM. No gas observed. lowered vis to 320. 21:45 00:00 225 2,773 1,461 SURFA DRILL TRIP P POOH with pump @ 3 BPM 5 stands. Continued POOH on trip tank to 1,461'. 06/07/2007 00:00 01:30 1.50 1,461 170 SURFA DRILL TRIP P POOH from 1461' to 170' - flow check well at 894', static 01:30 04:00 2.50 170 0 SURFA DRILL PULD P Stand back collars - plug in and check MWD calibrations - lay down bha components - clear tools from floor and clean u tri mess 04:00 05:45 1.75 0 0 SURFA CASIN RURD P Lay down drilling bails - pull riser sleeve - PU casing bails and fill up tool - RU 9 5/8" slips, elavators and casing ton s 05:45 06:00 0.25 0 0 SURFA CASIN SFTY P Held Prejob safety and opts meeting with crew 06:00 09:00 3.00 0 1,724 SURFA CASINC RNCS P Ran 9 5/8" 40 # L-80 BTC csg as follows: FS (Silver bullet) 2 jts. FC (Halliburton) 2 jts.( first 4 connections made up w/BakerLoc - filled pipe & checked floats) 41 jts. to 1724' (45 jts. total PUW 140K SOW 115K 09:00 09:30 0.50 1,724 1,724 SURFA CASIN( CIRC P Stage pumps up to 6 bpm - CBU - FCP=280 si PUW 135K SOW 124K 09:30 11:00 1.50 1,724 2,763 SURFA CASIN( RNCS P continue running 9 5/8", 40#, L-80 BTC csg from 1724' to 2723' (71 jts total) MU FMC fluted hanger and land cs w! FS 2,763' & FC 2,683' 11:00 11:30 0.50 2,763 2,763 SURFA CEME~ RURD P RD fill up tool - MU cement head and lines ~ ~ 06/07/2007 11:30 13:15 1.75 2,763 2,763 SURFA CASIN( CIRC P Establish circulation 4 bpm / 260 psi - stage pumps up to 8 bpm - circulate and condition mud for cementing - FCP=310 psi PUW 165K SOW 144K - Held Prejob safety and opts meeting with ri team 13:15 15:15 2.00 2,763 2,763 SURFA CEME~ DISP P Cemented 9 5/8" casing as follows: Rig pumped 40 bbls of viscosified water w/ nutplug marker - line up to Dowell - Pumped 5 bbls of fresh water - test lines to 3700 psi - Dropped btm plug - Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 5.7 BPM @ 195 psi - Mixed & pumped 10.7 ppg Lead slurry (ASL) @ 7.0 BPM / 206 - 266 psi - Observed nut plug marker @ shakers w! 285 bbls lead slurry pumped - (pumped down surge can 301 bbis total) Switched to tail slurry - Mixed & pumped 50 bbls 15.8 ppg tail slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 5.6 BPM @ 368 psi - Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 184 bbls 9.9 ppg mud @ 8.0 BPM / 380 to 550 psi slowed pump to 3.5 BPM / 430 psi (for the last 4 bbls of displacement) Bumped plug to 1020 psi - Check floats OK - CIP @ 1500 hrs. - Full circulation throughout job w/ 86 bbls 10.7 ppg cement returns to surface - reciprocated pipe while cementing until last 24 bbls of dis lacement 15:15 16:00 0.75 2,763 2,763 SURFA CASIN DHEQ P Tested casing to 3629 psi - holding 3568 psi after 30 minutes - Used Dowell um for test - bleed off lines 16:00 17:00 1.00 2,763 0 SURFA CEME~ RURD P Rig down cement head and lines. Lay down landin ~t. 17:00 18:00 1.00 0 0 SURFA CASINC NUND P Nippled down riser. 18:00 18:45 0.75 0 0 SURFA WELCT NUND P Installed and tested FMC Speed Head. 18:45 20:45 2.00 0 0 SURFA WELCT NUND P Nippled up BOP and changed solid 3 1/2" rams to VBR. 20:45 00:00 3.25 0 0 SURFA WELC BOPE P Set test plug and Tested BOPE 250/3500/5000 si. 06/08/2007 00:00 05:15 5.25 0 0 SURFA WELC BOPE P Continued testing BOPE. Greased and retested 1 valve. Retested manual choke (would not test low pressure). Top rams did not test with 5". Continued testing floor valves 250/5000 psi. Pulled test plug and installed wear rin . 05:15 06:00 0.75 0 0 ~SURFA DRILL RURD P Picked up bales and elevators for 4" ~ 06/08/2007 06:00 12:00 6.00 0 0 SURFA DRILL PULD P Picked up and stood back 4" DP. 12:00 15:45 3.75 0 0 SURFA DRILL PULD P Continued picking up and standing back 4 " DP. 15:45 16:45 1.00 0 0 SURFA WELC7 BOPE T Pulled wear ring and installed test plug on 5" DP. Attempted to test. No success. 16:45 18:15 1.50 0 0 SURFA WELC7 NUND T PJSM and changed VBR to solid 4" rams in to cavit . 18:15 19:30 1.25 0 0 SURFA WELC7 BOPE T Installed test plug on 4" DP and tested top rams to 250/5000 psi. Good test. Will not use 5" DP. Pulled test plug and installed wear rin . 19:30 00:00 4.50 0 326 SURFA DRILL PULD P Picked up BHA and uploaded MWD. Pulse tested tools. Loaded Nukes. RIH BHA. 06/09/2007 00:00 01:45 1.75 326 1,987 SURFA DRILL TRIP P RIH with HWDP to 750'. Changed dies in Iron Roughneck and continued RIH ickin u 4" DP to 1,987'. Filled i e. 01:45 02:15 0.50 1,987 2,617 SURFA DRILL TRIP P RIH with stands to 2,617'. 02:15 02:45 0.50 2,617 2,682 SURFA DRILL REAM P Precautionary wash to 2,682'. 02:45 04:00 1.25 2,682 2,763 SURFA CEME~ DRLG P Drilled plugs and shoetrack to 2,763'. 04:00 04:15 0.25 2,763 2,793 SURFA DRILL DDRL P Cleaned out rathole to 2,773' and drilled to 2,793'. 04:15 04:30 0.25 2,793 2,793 SURFA DRILL CIRC P CBU @ 600 GPM. 04:30 05:15 0.75 2,793 2,793 SURFA CEME~ FIT P Rigged up and did FIT to 18 PPG EMW. 05:15 12:00 6.75 2,793 3,517 INTRM1 DRILL DDRL P Drilied 8 3/4" hole w/ motor f/2,793" to 3,517' MD 2,913' ND ADT 3.77 Hrs ART 3.37 Hrs AST .4 Hrs. WOB 5/15 k RPM 100 GPM 650 @ 2,370 psi String wt. PU 147 SO 119 Rot 133 ECD 10.58 Tor ue on/off btm. - 8500/7500 ft/Ibs. 12:00 00:00 12.00 3,517 4,730 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/3,517" to 4,730' MD 3,742' ND ADT 7.46 Hrs ART 6..71 Hrs AST .75 Hrs. WOB 10/25 k RPM 100 GPM 650 @ 3,340 psi String wt. PU 160 SO 126 Rot 145 ECD 10.59 Tor ue on/off btm. - 9000/8000 ft/Ibs. 06/10/2007 00:00 12:00 12.00 4,730 6,088 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/4,730' to 6,088' MD 4,683' ND ADT 6.49 Hrs ART 5.17 Hrs AST 1.32 Hrs. WOB 10/25 k RPM 100 GPM 650 @ 2,750 psi String wt. PU 194 SO 135 Rot 160 ECD 10.61 Torque on/off btm. - 10,500/9,000 ft/Ibs. ~ 06/10/2007 12:00 14:15 2.25 6,088 6,359 INTRMI DRILL DDRL P Drilled 8 3/4" hole w/ motor f/6,088' to 6,359' MD 4,870' TVD ADT 1.53. Hrs ART .99 Hrs AST .54 Hrs. WOB 10/25 k RPM 100 GPM 650 @ 2,750 psi String wt. PU 194 SO 135 Rot 160 ECD 10.61 Torque on/off btm. -10,500/9,000 ft/Ibs. 14:15 00:00 9.75 6,359 7,025 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/6,359' to 7,025' MD 5,317' ND ADT 6.43 Hrs ART 5.2 Hrs AST 1.23 Hrs. WOB 8/15 k RPM 100 GPM 485 @ 1,870 psi String wt. PU 218 SO 140 Rot 170 ECD 10.4 Torque on/off btm. - 12,000/11,000 ft/Ibs. Drillin with one um . 06/11/2007 00:00 00:30 0.50 7,025 7,121 INTRM1 DRILL DDRL P Drill 8 3/4" hole from 7,025' to 7,121' MD 5,383' ND 00:30 00:45 0.25 7,121 7,121 INTRM1 DRILL OTHR NP Establish circulation with #2 pump - close IBOP and test pump and lines to 3500 si 00:45 01:30 0.75 7,121 7,121 INTRM1 DRILL CIRC P Pump high vis sweep - Circ and condition mud - 650 gpm / 2860 psi / 110 r m 01:30 04:00 2.50 7,121 7,333 INTRM1 DRILL DDRL P Drill 8 3/4" hole from 7,121' to 7,333' - observed washout in tool joint above rota table 04:00 04:15 0.25 7,333 7,333 INTRM1 DRILL DDRL T Change out stand. 04:15 12:00 7.75 7,333 7,883 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/7,333' to 7,883' MD 5,898' ND ADT 6.88 Hrs ART 3.69 Hrs AST 2.36 Hrs. WOB 10/25 k RPM 100 GPM 650 @ 3600 psi String wt. PU 193 SO 157 Rot 176 ECD 10.57 Torque on/off btm. - 12,000/10,000 12:00 00:00 12.00 7,883 8,929 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/7,883' to 8,929' MD 6,611' TVD ADT 6.52 Hrs ART 4.29 Hrs AST 2.23 Hrs. WOB 10/20 k RPM 100 GPM 650 @ 3870 psi String wt. PU 208 SO 167 Rot 188 ECD 10.56 Torque on/off btm. - 11,000/10,000 ~ 06/12/2007 00:00 04:00 4.00 8,929 9,249 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/8,929' to 9,249' MD 6,835' ND ADT 2.86 Hrs ART 1.56 Hrs AST 1.3 Hrs. WOB 10/20 k RPM 100 GPM 600 @ 3600 psi String wt. PU 208 SO 167 Rot 188 ECD 10.56 Torque on/off btm. - 11,000/10,000 ft/Ibs. 04:00 05:30 1.50 9,249 8,644 INTRM1 DRILL WPRT P POOH Backreaming from 9,249' to 8,644'. 550 GPM 70 RPM. 05:30 06:00 0.50 8,644 9,249 INTRM1 DRILL WPRT P RIH to 9,249' picked up 6 singles 06:00 07:30 1.50 9,249 8,834 INTRM1 DRILL CIRC P Pumped sweep and circulated hole clen Standing back 1 stand every 1/2 hour. 600 GPM 100 RPM. 07:30 08:30 1.00 8,834 8,834 INTRM1 RIGMN' RGRP T Noticed drop in pump pressure. Found mud line washed out in pump room. Re aired line and cleaned u mud. 08:30 09:30 1.00 8,834 8,834 INTRM1 DRILL CIRC P Circulated 600 GPM 100 RPM. 09:30 10:45 1.25 8,834 8,834 INTRM1 DRILL CIRC P Did 500 Bbl dilution to mud system with hole stren thin roducts. 10:45 11:15 0.50 8,834 9,249 INTRM1 DRILL REAM P RIH to 9,216' and washed to 9,249'. 11:15 12:00 0.75 9,249 9,287 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/9,249' to 9,287' MD 6,869' ND ADT 0.27 Hrs ART 0.27 Hrs AST 0.0 Hrs. WOB 10/20 k RPM 100 GPM 600 @ 3640 psi String wt. PU 218 SO 168 Rot 191 ECD 10.56 Torque on/off btm. - 11,000/10,000 ft/Ibs. 12:00 16:00 4.00 9,287 9,626 INTRM1 DRIIL DDRL P Drilled 8 3/4" hole w/ motor f/9,287' to 9 626' MD 7 104' ND ~ ADT 2.45 Hrs ART 2.45 Hrs AST 0.0 Hrs. WOB 10l20 k RPM 100 GPM 600 @ 3640 psi String wt. PU 230 SO 167 Rot 194 ECD 10.56 Torque on/off btm. -11,500/9,500 ft/Ibs. 16:00 17:15 1.25 9,626 9,216 INTRM1 DRILL TRIP P POOH Backreaming from 9,626' to 9,216'. 500 GPM 70 RPM. 17:15 19:45 2.50 9,216 8,740 INTRM1 DRILL CIRC P CBU X 3. 600 GPM 70 RPM. 3570 psi. Stand back one stand every 1/2 hour. 19:45 21:00 1.25 8,740 8,316 INTRM1 DRILL TRIP P POOH on trip tank from 8,740' to 8,316'. Over ull to 70 K. 21:00 22:30 1.50 8,316 7,883 INTRM1 DRILL TRIP P POOH Backreaming from 8,316'to 7,883'. 500 GPM 70 RPM. 22:30 00:00 1.50 7,883 7,407 INTRM1 DRILL TRIP P POOH on trip tank from 7,883' to 7,407'. 06/13/2007 00:00 07:00 7.00 7,407 750 ~ INTRM1 DRILL TRIP P POOH from 7,407' to 750'. ~ 06/13/2007 07:00 08:15 1.25 750 80 INTRM1 DRILL TRIP P Pulled and stood back HWDP and monels. 08:15 11:30 3.25 80 0 INTRM1 DRILL PULD P Removed nukes and downloaded MWD. Laid down BHA. 11:30 12:00 0.50 0 0 INTRM1 DRILL PULD P Cleared floor and changed elevators. Laid down stand of DP with wash out. 12:00 13:30 1.50 0 0 INTRM1 WELCT NUND P Changed top rams to 7" and tested. Pulled long wear bushing and installed thin bushin . 13:30 14:30 1.00 0 0 INTRM1 CASINC RURD P Rigged up to run casing and PJSM. 14:30 18:30 4.00 0 2,767 INTRM1 CASIN RNCS P Ran 65 jts 7" 26# L-80 BTCM casing to 2,767'. 18:30 19:00 0.50 2,767 2,767 INTRM1 CASIN CIRC P Circulated casing. Staged pumps up to 4 BPM. Circulated casing volume + 10 Bbis. 19:00 23:00 4.00 2,767 5,820 INTRM1 CASINC RNCS P Ran 72 jts 7" 26# L-80 BTCM casing to 5,820'. Installed Stage Collar between 'ts 91 and 92. 23:00 00:00 1.00 5,820 5,820 INTRM1 CASINC CIRC P Circulated casing. Staged pumps up to 4 BPM. CBU. 06/14/2007 00:00 00:15 0.25 5,820 5,820 INTRM1 CASINC CIRC P Continue to circ and condition mud at 4 b m at 540 si. 00:15 04:30 4.25 5,820 8,938 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 5828' to 8938'. 04:30 06:15 1.75 8,938 8,938 INTRM1 CASIN( CIRC P CBU. Stage pumps to 4 bpm at 430 si. 06:15 07:30 1.25 8,938 9,616 INTRM1 CASINC RNCS P RIH w/ 7" csg to 9579'. MU hanger and land csq at 9616'. No hole roblems. 07:30 08:00 0.50 9,616 9,616 INTRM1 CASIN( RURD P RD csg running equipment. Blow down to drive. RU cementin e ui ment. 08:00 09:15 1.25 9,616 9,616 INTRM1 CEME~ CIRC P Establish circ. Stage pumps to 5 bpm at 560 si. 09:15 12:00 2.75 9,616 9,616 INTRM1 CEME~ CIRC T Attempt to reciprocate pipe. Well packed off. Worked pipe. Re-established circ. Stage pumps to 2 b m. 12:00 18:30 6.50 9,616 9,616 INTRM1 CEME~ CIRC T Attempt to reciprocate pipe. Well packed off. Worked pipe. Re-established circ. Stage pumps to 2.5 bpm and hole packed off again. Attempted to work pipe, stuck. Regained circulation staged pumps to 4 bpm 17% flow and 380 psi. Hole packed off again. Continued working stuck pipe to 465,000 and pressuring up to 1500 psi without movement or returns. 1830 19:00 0.50 9,616 9,616 INTRM1 CEME RURD T Rigged down cement line and head. 19:00 19:30 0.50 9,616 9,616 INTRM1 RIGMN' SVRG P Serviced rig. 19:30 22:30 3.00 9,616 9,616 INTRMI CEME~ WOEQ T Rigged up pump in head and waited on Schlumber er and erf uns. 22:30 00:00 1.50 9,616 9,616 INTRM1 CEME~ RURD T Spotted up wireline unit and rigged up Schlumberaer e line. ~ 06/15/2007 00:00 01:45 1.75 0 0 INTRM1 CEME~ PERF T PJSM. Make 2 7!8" perf guns. 01:45 03:45 2.00 0 0 INTRM1 CEME PERF T RIH w perf guns to 20' below baffle plate. Pressure csg to 500 psi. Perf 7" csg with 6 spf from 9545' to 9547'. Pressure bled to 210 si. 03:45 05:15 1.50 0 0 INTRMI CEME~ PERF T POH w/ guns. RD Schlumberger. 05:15 05:30 0.25 0 0 INTRMI CEME~ RURD T Rig up circulating equimpment. 05:30 06:00 0.50 0 0 INTRM1 CEME~ CIRC T Establish circulation. Stage pumps to 3 b m at 420 si. 06:00 07:00 1.00 0 0 INTRM1 CEME~ CIRC T Annulus packed off. Pressure spiked to 3600 psi. Stage tool sheared open. Increase flow rate to 5 b m at 230 si. 07:00 10:30 3.50 0 0 INTRM1 CEME~ CIRC T Pwmp nut plug pill for fluid caliper to confirm stage collar was open. Screen out well bore stren thin material. 10:30 11:30 1.00 0 0 INTRM1 CASINC RURD P RD circulating equipment. LD landing 't. Pull thin wear bushin . 11:30 12:00 0.50 0 0 INTRM1 CASIN( NUND P Install pack off and test to 5000 psi. 12:00 14:00 2.00 0 0 INTRM1 CASINC NUND T Changed out top rams to 4" and tested. 14:00 15:30 1.50 0 561 INTRM1 CEME~ TRIP T Made up cleanout BHA RIH to 561'. 15:30 19:30 4.00 561 5,794 INTRM1 CEME~ TRIP T RIH from 561' to 5,600'. Closed Annular and estabilished circulation out the casing valve. Opened Hydril and continued RIH to 5,740'. Closed Stage Collar with 20 K down weight. Set 45 K down and pressured casing to 250 psi to confirm Collar clsed. Drilled out Sta e Collar. 19:30 20:00 0.50 5,794 5,794 INTRM1 CEME~ CIRC T CBU. 423 GPM 100 RPM 1680 psi. 20:00 21:30 1.50 5,794 5,794 INTRM1 RIGMN SVRG P Slipped and cut drilling line. 21:30 23:15 1.75 5,794 9,525 INTRM1 CEME~ TRIP T RIH to 9,508' Singled in 3 jts from pipe shed ta ed Baffle 9,5 25'. 23:15 00:00 0.75 9,525 9,526 INTRM1 CEME~ DRLG T Drilled Baffle. 423 GPM 100 RPM WOB 5/10 K. 2400 si. 06/16/2007 00:00 00:30 0.50 9,526 9,568 INTRM1 CEME~ DRLG T Finish drilling baffle at 9525'. Wash down and r at 9568'. 00:30 01:00 0.50 9,568 9,525 INTRMI CEME CIRC T Pull above baffle at 9525'. CBU at 424 m-2410 si-70r m 01:00 05:30 4.50 9,525 0 INTRM1 CEME~ TRIP T POH w/ bit. Check flow at HWDP. Static. 05:30 06:15 0.75 0 INTRM1 CEME~ RURD T Clear floor. RU Schlumberger eline. 06:15 08:30 2.25 INTRM1 CEME PERF T RIH w/ 2 7/8" guns. Perf at the bottom of the Kuparuk sands from 9410' to 9415' - 6 spf. POH. RD Schlumberqer. ~ ~ 06/16/2007 0830 10:00 1.50 INTRM1 CEME~ OTHR T Close blind rams. Open lower annulus to pits. Pressure annulus to 1100 psi in 200 psi stages. No fluid to surface. Pressure bled to 500 psi. Establish injection rate at 1 bpm at 750 psi. Pum 5 bbls. 10:00 10:30 0.50 INTRM1 CEME~ OTHR T Pressure bled to 220 psi in 10 min. Bled off pressure. Open well. Monitor well for 15 mins. Fluid loss - 4 b h. 10:30 11:30 1.00 INTRM1 CEME~ RURD T RU Schlumberger eline. 11:30 13:30 2.00 0 0 INTRM1 CEME~ PERF T RIH with Perf gun and Perforate casing from 9,369 to 9,371'. 2' gun 6 SPF. POOH. 13:30 16:00 2.50 0 0 INTRM1 CEME~ RURD T Rig down perf gun. Rigged up to run Cement Retainer. 16:00 20:00 4.00 0 0 INTRM1 CEME~ OTHR T RIH with Slumberger and set Baker Cement Retainer @ 9,390'. POOH with e line. RD Slumber er. 20:00 00:00 4.00 0 6,646 INTRM1 CEME~ TRIP T Made up Stinger and RIH to 6,646'. 06/17/2007 00:00 01:30 1.50 6,646 9,390 INTRM1 CEME~ TRIP T RIH and tag cement retainer at 9390'. 01:30 01:45 0.25 9,390 9,390 INTRM1 CEME~ CIRC T Sting into retainer. Establish circ through perfs at 1 bpm - 880 psi. Unsting. Circ at 10 bpm for 5 min. Check flow. OK. 01:45 02:15 0.50 9,390 9,390 INTRM1 CEME~ OTHR T Break out top drive. Space out DP w/ pup and TIW valve. MU head pin and cement hose. 02:15 02:30 0.25 9,390 9,390 INTRM1 CEME OTHR T Sting into retainer w/ 25k wt. Pump 1 bpm. Returns were intermittent. Pressure 410 psi to 950 psi. Stage pumps up to 2.5 bpm 1320 psi. Open lower annulus valve. No communication to surface. Pumped 35 bbls. 02:30 02:45 0.25 9,390 9,390 INTRM1 CEME~ OTHR T Shut down pumps. Monitor pressure. Pressure bled from 1300 psi to 130 psi in 10 min. 02:45 03:15 0.50 9,390 9,390 INTRM1 CEME CIRC T Unsting from retainer. Close bag. Circ through choke to fill gas buster. Test lines to 2500 si. 03:15 04:00 0.75 9,390 9,390 INTRMI CEME~ DISP T Mixed and displaced 15 Bbls 15.9 PPG cement to the stinger holding 200 psi backpressure on choke. Stabed into Retainer and displaced 6 Bbls of cement @ 1 BPM with returns. Unsting from Retainer dumping the remainin 9 Bbls on the retainer. 04:00 04:45 0.75 9,390 8,914 INTRM1 CEME~ TRIP T POH w/ 5 stds DP 04:45 05:15 0.50 8,914 8,914 INTRMI CEME~ CIRC T Circulate surface to surface at 10 bpm at 1940 si. 05:15 05:45 0.50 8,914 8,914 INTRM1 CEME~ OTHR T Close pipe rams. Pressure well to 680 ps+. Held pressure for 20 min. Bleed off pressure. Blow down. • 06/17/2007 05:45 10:45 5.00 8,914 150 INTRMI CEME~ TRIP T POH w/ setting tool. Check flow at HWDP. OK. 10:45 12:15 1.50 150 0 INTRM1 CEME~ PULD T Stood back HWDP and laid down BHA. Cleared floor. 12:15 14:45 2.50 0 0 INTRM1 CEME~ PERF T Rigged up Schlumberger and RIH with 2' 12 SPF Perf gun. Perffed casing from 8,457' to 8,459'. POOH and ri ed down. 14:45 16:15 1.50 0 0 INTRM1 CEME~ CIRC T CBU @ 4 BPM 430 psi. 16:15 21:15 5.00 0 8,357 INTRM1 CEME~ TRIP T Made up Cement Retainer on DP and RIH to 8,357'. 21:15 22:00 0.75 8,357 8,357 INTRM1 CEME~ OTHR T Set Retainer @ 8,357'. Stung back in with 35 K on retainer. Established circulation and worked up to 4 BPM 630 si. 22:00 00:00 2.00 8,357 8,357 INTRM1 CEME~ SQEZ T PJSM. Circulating squeeze as foliows: Switched over to Dowell and tested lines to 3,000 psi. Pumped 20 Bbls of CW-100 @ 4 BPM 600 psi. Pumped 30 Bbls 10.5 PPG Mudpush @ 46PM 550 psi. Followed with 130 Bbls. Lite Crete mixed at 11 PPG pumped @ 4 BPM 500 to 620 psi 3 Bbls water behind. Switched to Rig and displaced with 79.5 Bbls 9.6 PPG mud at 4.5 BPM 600 to 720 si. CIP 2340 Hrs. 06/18/2007 00:00 00:15 0.25 8,357 8,043 INTRM1 CEME~ TRIP T Unsting from retainer. RD cement equipment. LD one single. POH and std back 3 stds drill i e. 00:15 00:45 0.50 8,043 8,043 INTRM1 CEMEt~ CIRC T Circulate from surface to surface at 10 bpm at 1880 psi. Blow down lines. Pum d 'ob. 00:45 06:15 5.50 8,043 0 INTRM1 CEMEt~ TRIP T POH w/ stinger. Check flow at HWDP. OK. 06:15 07:45 1.50 0 245 INTRM1 CEMEf~ PULD T MU junk mill and bit sub. PU and RIH 8 - 4 3/4" DCs. 07:45 12:00 4.25 245 8,217 INTRM1 CEME~ TRIP T MU 1 std HWDP. Circulate through DC's to clear rust. RIH to 8217'. Fill i e eve 20 stds. 12:00 12:30 0.50 8,217 8,217 INTRM1 CASIN( DHEQ T Rigged up and tested casing to 3500 si for 10 Min. OK 12:30 14:30 2.00 8,217 8,460 INTRM1 CEME~ DRLG T Washed down from 8,217' to 8,356'. Tagged Retainer. Drilled Retainer and cement to 8,460'. WOM 5/10 K 300 GPM 1430 si 110 RPM. 14:30 17:00 2.50 8,460 9,133 INTRMI CEME~ DRLG T Washed down from 8,460'to 9,133'. Ta ed Retainer. 17:00 21:00 4.00 9,133 9,569 INTRM1 CEME~ DRLG T Drilled Retainer and cement, cleaned out to 9,569'. WOM 5/10 K 300 GPM 1820 si 100 RPM. 21:00 22:30 1.50 9,569 9,569 INTRM1 CEME CIRC T Pumped sweep and circulated casing clean. 300 GPM 110 RPM 1560 si. 22:30 00:00 1.50 9,569 8,997 INTRM1 CEME TRIP T Flow check. Pumped dry job and POOH on trip tank from 9,569' to 8.997'. . 06/19/2007 00:00 06:45 6.75 8,597 798 INTRM1 CEME 06:45 07:45 1.00 798 0 INTRM1 CEME 07:45 08:00 0.25 0 0 ~ INTRMI CEME 08:00 12:00 12:00 14:00 14:00 19:00 19:00 20:30 20:30 21:00 21:00 22:00 22:00 23:00 23:00 00:00 00:00 03:45 03:45 10:30 4.00 0 0 INTRM1 EVALW ELOG 2.00 0 0 INTRM1 EVALVI~ ELOG 5.00 8,356 INTRM1 DRILL TRIP 1.50 8,356 8,356 INTRM1 RIGMN SVRG 0.50 8,356 9,498 INTRM1 DRILL TRIP 1.00 9,498 9,569 INTRM1 DRILL CIRC 1.00 9,569 9,569 INTRM1 DRILL CIRC 1.00 9,569 9,308 INTRM1 DRILL TRIP 3.75 9,308 5,314 INTRM1 DRILL TRIP 6.75 5,314 0 ~ INTRM1 DRILL TRIP 10:30 I12:00 I 1.50 I 0 I 0 12:00 13:00 1.00 0 0 13:00 13:15 0.25 0 0 OTHR OTH R SFTY - ~ T Continue POOH on TT f! 8597' to 798' - Flow ck static T Std back HWDP - Jars - 2 stds SDC's - LD 2 SDC's - bit sub &'unk mill T Monitor well on TT - perform house keeping on rig floor - Prep for wireline work T PJSM w/ rig crew & Schlumberger - RIH w/ USIT lo T Finish USIT log. Log interval - 9540' to 4000'. RD Schlumber er. P MU and RIH with casing scraper BHA on 4" DP to 8356'. P Slip and cut drilling line. Service top drive. P RIH with 4" DP from 8356' to 9498'. P Wash down from 9498' to 9569'. CBU at 300 m at 1660 si. P PJSM. Displace well to 9.2 ppg brine. P Flow check. Blow down. POH on trip tank from 9569' to 9308'. P POOH on TT f/ 9308' to 5314' ( 48 stds & stand back in derrick) P Continue to POOH laying down 4" DP (141jts.) Flow ck - static - LD 12 jts. 4" HWDP - std back 2 stds HWDP w/ Jars - LD 6 SDC's - bit sub - boot baskets - csg scraper - mill- clear floor of tools P Drain stack - pull wear bushing - change top rams to 4 1/2" x 7" VBR & test to 250 & 5000 si P Pull test plug - RU to run 4 1/2" com letion P Held pre job meeting w/ crew on • 06/20/2007 13:15 23:00 9.75 0 9,237 COMPZ RPCO RCST P Run 4 1/2" completion as follows: WLEG - Pup jt 4 1/2" 12.6# L-80 IBTM - XN nipple - 1 jt 4 1/2" 12.6# L-80 IBTM tbg - Pup jt. 4 1/2" 12.6# L-80 IBTM - Baker Premier packer - Pup jt. 4 1/2" 12.6# L-80 I BTM - 19 jts 4 1/2" 12.6# L-80 IBTM tbg - Pup jt. 4 1/2" 12.6# L-80 IBTM - Baker Premier packer - Pup jt 4 1/2" 12.6# L-80 IBMT - 2 jts 4 1/2" 12.6# L-80 IBTM tbg - Pup jt. 4 1/2" 12.6# L-80 IBTM - Cmaco GLM - Pup jt. 4 1/2" 12.6# L-80 IBTM - 152 jts 4 1/2" 12.6# L-80 IBTM tbg - Camco DB nipple - 54 jts 4 1/2" 12.6# L-80 IBTM tbg - MU FMC hanger & land tbg w/ tail @ 9237.59' - XN nipple @ 9225.17' - Packer #1 @ 9164.17' - Packer #2 @ 8377.32' - GLM #1 @ 8272.33' - DB nipple @ 2197.11' 23:00 00:00 1.00 9,237 9,237 COMPZ RPCOh DHEQ P Change out landing jts. Install TWC. Test metal to metal hanger seals to 5000 si.OK 06/21/2007 00:00 01:15 1.25 9,237 9,237 COMPZ WELCT NUND P LD LJ "B". ND BOPE. 01:15 02:00 0.75 9,237 9,237 COMPZ RPCOh NUND P NU tree. 02:00 02:30 0.50 9,237 9,237 COMPZ RPCOh DHEQ P Test hanger seals and tree to 5000 si. OK. 02:30 03:45 1.25 9,237 9,237 COMPZ RPCOh OTHR P RU lubricator. Pull TWC. RD lubricator. 03:45 04:15 0.50 9,237 9,237 COMPZ RPCOh RURD P RU hardlines and manifold for dis lacement. 04:15 04:30 0.25 9,237 9,237 COMPZ RPCOh SFTY P PJSM on displacement. 04:30 06:30 2.00 9,237 9,237 COMPZ RPCO CIRC P Dowell test lines to 5000 psi. Displace well with 135 bbls 9.2 inhibited brine followed b 170 bbis diesel. 06:30 07:00 0.50 9,237 9,237 COMPZ RPCO PACK P RU doyon lubricator & drop packer settin rod/ball 07:00 07:45 0.75 9,237 9,237 COMPZ RPCOh PACK P Pressure up on tbg to 4800 psi to set both packers & test tbg for 30 mins. - Bleed down tb to 800 si 07:45 08:30 0.75 9,237 9,237 COMPZ RPCOh PACK P Pressure up on annulus to 3500 psi & test for 30 mins. - b{eed annulus to 0 si - Shut in well 08:30 09:30 1.00 9,237 9,237 COMPZ RPCOti OTHR P Flush hard lines & blown down - RD lines & s ueeze manifo-d 09:30 10:30 1.00 9,237 9,237 COMPZ RPCOh OTHR P RU FMC lubricator & Set BPV 10:30 12:00 1.50 9,237 9,237 COMPZ RPCOh OTHR P Secure well - Clean up cellar & rig floor for rig move - Release rig @ 1200 6/21 /2007 % / ~ • CD4-302 Well Events Summary DATE Summary 6/3/07 Move rig f/ CD2 to CD4-302 - Ball mill - motor complex on CD4 6/4/07 Finish rig move - RU @ CD4-302 - Spot rig - RU - NU riser - PU 5" DP - HWDP & std back - slip & cut DL 6/5/07 Finish S&C - MU BHA #1 - Held Pre Spud w/ crew - fill hole & ck for leaks - Test lines - Spud in @ 0445 hrs - Drill 12 1/4 " hole to 1905'. 6/6/07 Drilled to 2,773'. Circulated. Wiper trip. Circulated. POOH to 1,461'. 6/7/07 POOH and laid down BHA. Rigged up and ran 71 jts 9 5/8" casing. Circulated and cemented casing. Tested casing. Nippled down riser. Nippled up and tested BOP. 6/8/07 Finished testing BOP. Picked up and stood back 240 jts 4" DP. Changed and retested upper pipe rams. Picked up and RIH with BHA #2. 6/9/07 RIH and drilled shoetrack. Cleaned out rathole and drilled 20'. CBU. FIT to 18 PPG EMW. Drilled to 4,730'. 6/10/07 Drilled from 4,730' to 7,025'. 6/11/07 Drilled from 7,025 to 8,929'. 6/12/07 Drilled from 8,929' to 9,249'. Made wiper trip. Circulated and treated mud. Drilled from 9,249' to 9,626'. Circulated and POOH from 9,626 to 7,407'. 6/13/07 POOH and laid down BHA. Changed rams. Rigged up and ran 137 Jts 7" casing. CBU. 6/14/07 Ran 7" casing to 9616'. Landed casing and circulated. Hole packed off and casing stuck. Waited on and rigged up Slumberger e line. 6/14/07 PERFORATED A 2' INTERVAL FROM 9553.3' - 9555.3' INORDER TO ALLOW THE RIG TO CIRCULATE. SHOOTING INTERVAL WAS LOCATED IN THE 40' JOINT BETWEEN THE BAILER AT 9537' AND THE FLOAT COLLAR AT 9569'. WELL PRESSURED UP TO 500 PSI PRIOR TO FIRING INORDER TO CONFIRM CIRCULATION. 6/15/07 Schlumberger fired gun and POOH. RD wireline and established circulation. Hole packed off after 1/2 hour at 2 BPM. RD and set packoff. RIH with cleanout BHA and drilled out stage collar. Continue RIH and drilled baffle. 6/16/07 Cleaned casing out to float collar. CBU. POOH and laid down BHA. RU Schlumberger and made 2 Perf runs. Set Cement Retainer on e line above lower perfs. RIH with cement stinger on DP. 6/16/07 SHOT HOLES IN TUBING WITH 2 7/8" PJ GUN 6SPF FROM 9410'-9415' AND FROM 9369'-9371'. SET CEMENT RETAINER AT 9390'. 2 ELINE CREWS- WORKING 24 HOUR OPERATIONS 6/17/07 RIH and engaged retainer. Established circulation and did squeeze job. POOH 5 stands and CBU. POOH and laid down BHA. Rigged up e line and Perfed casing @ 8,457 - 59'. Made up Cement Retainer and RIH on DP. Set Retainer @ 8,357'. Circulated. Did 130 Bbl Circulating squeeze. 6/17/07 SHOT HOLES IN CASING FROM 8457'-8459' WITH 4.5" 12 SPF PF 4621 CHARGES. RIG CONDUCTED CEMENT JOB. RAN ULTRASONIC CEMENT BOND LOG FROM 2500' TO 9500'. 6/18/07 Circulated and POOH. Made up cleanout BHA. RIH and drilled out cement and retainers to 9,569'. Pumped hi vis and circulated clean. POOH to 8597'. 6/19/07 Finish POOH w/ mill - RU & Run USIT log - RIH w/ scraper -Displaced well to 9.2 brine. 6/20/07 POOH w/ scraper - Change & test top pipe rams - RU & run 4 1/2" completion. Test hanger seals. 6/20/07 Complete Maintenance on Alpine Eline Logging Truck 2145; Transport to Deadhore and continue job recovery and maintenance; Transport to Kuparuk. • r CD4-302 Well Events Summary 6/21/07 ND BOPE - NU & Test tree - Pump packer fluid & freeze protect - Set packers & test tbg & annulus - Set BPV - Release rig 6/22/07 STAGE UNIT ON CD-4, WAIT FOR BPV TO GET PULLED 6/23/07 FMC PULL BPV, MIT-IA, GOOD TEST, PULL BALL & ROD @ 9225' RKB, PULL RHC PLUG BODY @ SAME, TAG SOFT BOTTOM @ 9569' RKB JOB COMPLETE 6/23/07 Job Prep: Move to Alpine; pre job Logging Truck 2145 and gunstring to meet procedure specifications; Coordinate with SL regarding pulling RHC plug from XN nipple at 9225', and running drift to TD as per procedure. 6/24/07 PERFORATED FROM 9398`-9413' WITH 2.875" 6 SPF POWERJET OMEGA CHARGES. TOOK BOTTOMHOLE PRESSURE SURVEY AFTER SHOOTING AND FOUND PRESSURE AT 9406' TO BE 2502 PSI. PRESSURE AT 9350' IS 2481 PSI . • Halliburton Company Survey Report C~mpan~: C~r-acoPhtll~ps Alaska tnc pate 6f29f2(IQ7 Time fi1 f}412 k'ag~; . >i~~ld. Cotville F~r Unif r Cu=u~~te(~)Ref~rexice VVe[I ~GI~4-3C~2 ~[°rue ~l~ith ;~iEe AIpiC~1 CI~' ; , . Ycr~t~ca[(T"VJ1}~e~ret~~ ; C~€~2 56 '! ..~_ °_. , ~~~II: ' CC'f~-~f32 ' ~-.. ; S+~~un ~S} ~iefere~ce: ~~ ' 1N~(k (Q,4QN Q t~flE ~ ~8AZr} ~ ~ ~ ~ ~V€}Ipach: ~Q4~07 ' St~rvey ~~~C'ula~ian lYlet6od: ' Mirii~tl~ut~t Cu~'uaiure ~"',. Ilb~.: ~~Ee , Field: Colville River Unit North Slope Alaska United States Map System;US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Dstum: NAD27 (Clarke 1866) Coordinate System: Well Centre I Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: CD4-302 Slot Name: Well Position: +N/-S -5.20 ft Plorthing: 5957521.22 ft Latitude: 70 17 32.915 N i +E/-W -19.49 ft Easting : 3781 55.13 ft Longitude: 150 59 11.331 W Position Uncertainty: 0.00 ft ,~ Wellpath: CD4-302 Drilled From: Well Ref. Point ~ 501032054500 Tie-on Depth: 36.50 ft ~ Current Datum: CD4-302: Height 56.10 ft ~ Above System Datum: Mean Sea Level MagneticData: 6/1/2007 Declination: 22.59 deg Field Strength: 57552 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.50 0.00 0.00 95.38 ~ i Survey Program for Definitive Wellpath Date: 3/6/2007 Validated: No Version: 2 Actual From Ta Survey Toolcode Tool Name ft ft ~ ~ 81.00 356.00 CD4-302 gyro (81.00-356.00) CB-GYRO-SS Camera based gyro single shot 394.60 9558.35 CD4-302 (394.60-9558.35) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ° 14~1' ~n~l ' Az~m ~` ' ~fVD . : ; ~ys TYl3 N1S ~Y ' MaplY Map~ ' ,, ', Taot :. ' ~, de$ E ` ' (t ft ' , -ft ft , ',' ft fk° ' _„ , ;. 36.50 0.00 0.00 36.50 -19.60 0.00 0.00 5957521.22 - 378155.13 TIE LINE I 81.00 0.15 80.00 81.00 24.90 0.01 0.06 5957521.23 378155.19 CB-GYRO-SS 175.00 0.25 90.00 175.00 118.90 0.03 0.38 595752125 378155.51 CB-GYRO-SS 267.00 0.50 53.00 267.00 210.90 0.27 0.90 5957521.48 378156.04 CS-GYRO-SS 356.00 1.00 68.00 355.99 299.89 0.80 1.94 5957521.99 378157.08 CB-GYRO-SS 394.60 1.30 65.44 394.58 338.48 1.11 2.65 5957522.28 378157.79 ~ MWD+IFR-AK-CAZ-SC 479.89 1.95 81.04 479.84 423.74 1J3 4.96 5957522.87 378160.12 MWD+IFR-AK-CAZ-SC i 575.28 2.99 83.61 575.14 519.04 2.26 9.03 5957523.34 378164.20 MWD+IFR-AK-CAZ-SC 661.45 4.17 84.31 661.14 605.04 2.82 14.39 5957523.81 378169.56 I MWD+IFR-AK-CAZ-SC 752.34 6.42 95.21 751.64 695.54 2.69 22J4 5957523.54 378177.90 MWD+IFR-AK-CAZ-SC ~ 844.00 9.10 94.03 842.45 786.35 1.72 35.07 5957522.37 378190.22 MWD+~FR-AK-CAZ-SC 935.85 14.72 91.74 93229 876.19 0.85 54.00 5957521.19 378209.13 MWD+IFR-AK-CAZ-SC 1031.70 18.85 92.30 1024.03 967.93 -0.14 81.65 5957519.76 378236.76 MWD+IFR-AK-CAZ-SC 1128.07 19.07 93.29 1115.17 1059.07 -1.67 112.93 5957517.72 378268.00 MWD+IFR-AK-CAZ-SC I 1222.54 21.37 92.56 1203.82 1147J2 -3.32 145.53 5957515.54 378300.58 MWD+IFR-AK-CAZ-SC i 1319.07 24.68 97J5 1292.65 1236.55 -6.83 183.08 5957511.43 378338.06 MWD+IFR-AK-CAZ-SC ~~ ~ 1412.17 27.57 96.14 1376.23 1320,13 -11.76 223.77 5957505.84 378378.67 MWD+IFR-AK-CAZ-SC ; i 1506.42 29.72 95.96 1458.94 1402.84 -16.51 268.70 5957500.35 378423.51 MWD+IFR-AK-CAZ-SC ; 1601.86 30.33 96.61 1541.58 1485.48 -21.75 316.17 5957494.36 378470.88 MWD+IFR-AK-CAZ-SC i ~ 1696.90 33.19 94.99 1622.38 1566.28 -26.77 365.93 5957488.52 378520.55 MWD+IFR-AK-CAZ-SC i 1791.42 35.88 95.77 1700.23 1644.13 -31.81 419.27 5957482.62 378573.80 MWD+IFR-AK-CAZ-SC j 1886.75 37.42 96.97 1776J2 1720.62 -38.13 475.82 5957475.39 378630.23 MWD+IFR-AK-CAZ-SC ~ 1981.96 38.49 97.37 1851.79 1795.69 -45.44 533.92 5957467.13 378688.20 ~ MWD+IFR-AK-CAZ-SC 2077.47 42.37 97.50 1924.48 1868.38 -53.46 595.33 5957458.12 378749.46 MWD+IFR-AK-CAZ-SC ~i 2172.50 47.88 95.92 1991.50 1935.40 -61.28 662.19 5957449.22 378816.18 MWD+IFR-AK-CAZ-SC 2267.98 46.73 96.32 2056.25 2000.15 -68.76 731.96 5957440.61 378885.82 MWD+IFR-AK-CAZ-SC 2362.96 46.60 98.12 2121.43 2065.33 -77.44 800.49 5957430.82 378954.19 MWD+IFR-AK-CAZ-SC 2457.91 46.98 96.73 2186.44 2130.34 -86.38 869.11 5957420.77 379022.65 MWD+IFR-AK-CAZ-SC 2552.84 48.28 95.54 2250.42 2194.32 -93.87 938.84 5957412.16 379092.25 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report . Company: ConaeoPhNtipS Alaska InG, Date: 6f29i~007 -:: '_ Tim~: 11:{3412. ' 1'age:~ 'Z ,:..:,: Fi~id;" ' Cotvilte Ri~r llnif ' ` ' :: ; °'' ~o~-rdinace(~TE~R~f~rs~~e: . ; 4Ve1L'.;C[7~-3t12, True N~rth ; Site: Alpine CC]~. ~e~ica~('~"~'~~Reteraneg ~f,~4-~t~2 ~.1 ' ; ; . WeII: ~: ~UA--3if~2 =: ~ 5ectiun (V~R~f~sre~ #~1ela {t~.ISl~t~.41p~,95.~8/~~ ~ ~ ~'WeiT ath~ ~C~-3'02 p 5ur~vey Ca~at~n-1'~lathoYl ,- hAinm~uurn ~unratut`~ llb Ck'ac[~ Survey 1WID' - Itrcl . A~tm ° T'YD ', Srys T~1) • ~TfS ' E1i~ = 14^~apl~i %.. `., l~iap~ fiuul , ft' deg deg ft ft, ' ft ft 'ft ~` 2647.66 48.66 95.52 2313.28 2257.18 -100J1 1009.49 5957404.17 379162.78 MWD+IFR-AK-CAZ-SC ~ I 2723.80 47.70 97.02 2364.05 2307.95 -106.90 1065.89 5957397.07 379219.06 MWD+IFR-AK-CAZ-SC ~ 2772.11 47.36 95.42 2396.67 2340.57 -110.76 1101.32 5957392.63 379254.42 MWD+IFR-AK-CAZ-SC 2867.09 47.42 95.81 2460.98 2404.88 -117.60 1170.88 5957384.67 379323.86 MWD+IFR-AK-CAZ-SC 2962.23 47.43 95.71 2525.34 2469.24 -124.63 1240.59 5957376.51 379393.44 MWD+IFR-AK-CAZ-SC ~ 3057.53 46.64 94.75 2590.29 2534.19 -130.99 1310.04 5957369.02 379462.76 MWD+IFR-AK-CAZ-SC 3153.00 47.51 94.40 2655.31 2599.21 -136.57 1379.72 5957362.32 379532.34 MWD+IFR-AK-CAZ-SC 3247.51 46.65 93.95 2719.67 2663.57 -141.61 1448.75 5957356.16 379601.27 MWD+IFR-AK-CAZ-SC 3342.83 45.02 94.14 2786.08 2729.98 -146.43 1516.95 5957350.24 379669.38 MWD+IFR-AK-CAZ-SC 3438.24 44.95 94.39 2853.56 2797.46 -151.44 1584.21 5957344.13 379736.55 MWD+IFR-AK-CAZ-SC 3533.47 44.75 93.97 2921.08 2864.98 -156.34 1651.19 5957338.15 379803.43 MWD+IFR-AK-CAZ-SC 3628.68 44.53 93.87 2988.82 2932.72 -160.91 1717.94 5957332.50 379870.09 MWD+IFR-AK-CAZ-SC 3724.04 46.25 95.56 3055.79 2999.69 -166.51 1785.58 5957325.81 379937.63 MWD+IFR-AK-CAZ-SC 3819.04 46.73 96.04 3121.20 3065.10 -173.47 1854.13 5957317.74 380006.05 MWD+IFR-AK-CAZ-SC 3914.48 46.61 95.27 3186.69 3130.59 -180.31 1923.22 5957309.78 380075.01 MWD+IFR-AK-CAZ-SC 4009.11 46.97 94.59 3251.48 3195.38 -186.24 1991.93 5957302.74 380143.61 MWD+IFR-AK-CAZ-SC II 4104.36 47.27 94.11 3316.30 3260.20 -191.53 2061.53 5957296.32 380213.11 MWD+IFR-AK-CAZ-SC ~ i 4199.59 47.71 96.14 3380.65 3324.55 -197.81 2131.44 5957288.91 380282.90 MWD+IFR-AK-CAZ-SC i ~ 4295.02 48.40 95.82 3444.43 3388.33 -205.20 2202.03 5957280.37 380353.36 MWD+IFR-AK-CAZ-SC 4390.18 46.49 95.99 3508.79 3452.69 -212.41 2271.75 5957272.04 380422.95 MWD+IFR-AK-CAZ-SC 4485.24 46.49 96.44 3574.24 3518.14 -219.87 2340.29 5957263.46 380491.35 MWD+IFR-AK-CAZ-SC 4580.62 46.61 95.92 3639.83 3583.73 -227.33 2409.13 5957254.90 380560.06 MWD+IFR-AK-CAZ-SC 4675.48 46.89 95.21 3704.83 3648.73 -234.03 2477.90 5957247.08 380628.70 MWD+IFR-AK-CAZ-SC 4770.48 45.94 94.70 3770.32 3714.22 -239.97 2546.45 5957240.03 380697.15 MWD+IFR-AK-CAZ-SC 4865.45 45.94 94.62 3836.37 3780.27 -245.52 2614.47 5957233.38 380765.06 MWD+IFR-AK-CAZ-SC 4960.14 46.29 93.93 3902.01 3845.91 -250.60 2682.53 5957227.19 380833.02 MWD+IFR-AK-CAZ-SC , 5055.33 46.46 94.13 3967.68 3911.58 -255.45 2751.26 5957221.24 380901.66 MWD+IFR-AK-CAZ-SC ~ 5150.33 46.52 93.65 4033.09 3976.99 -260.12 2820.00 5957215.45 380970.31 MWD+IFR-AK-CAZ-SC ~ 5245.76 47.12 93.32 4098.39 4042.29 -264.35 2889.46 5957210.10 381039.69 MWD+IFR-AK-CAZ-SC ; 5340.45 47.20 94.83 4162.78 4106.68 -269.28 2958.72 5957204.04 381108.85 MWD+IFR-AK-CAZ-SC i ~ 5435.52 46.99 94.36 4227.50 4171.40 -274.86 3028.13 5957197.34 381178.15 MWD+IFR-AK-CAZ-SC ' ~ 5531.25 45.58 94.31 4293.65 4237.55 -280.09 3097.12 5957190.99 381247.05 MWD+IFR-AK-CAZ-SC I ~ I 5626.68 45.52 95.24 4360.48 4304.38 -285J6 3165.01 5957184.22 381314.83 MWD+IFR-AK-CAZ-SC 5721.85 45.44 96.36 4427.21 4371.11 -292.62 3232.51 5957176.27 381382.21 MWD+IFR-AK-CAZ-SC 5817.11 45.36 95.77 4494.10 4438.00 -299.79 3299.96 5957168.01 381449.52 MWD+IFR-AK-CAZ-SC 5911.83 45.63 95.06 4560.50 4504.40 -306.16 3367.21 5957160.55 381516.66 MWD+IFR-AK-CAZ-SC 6007.00 45.96 96.35 4626.85 4570.75 -312.94 3435.09 5957152.67 381584.41 MWD+IFR-AK-CAZ-SC 6102.46 46.03 95.16 4693.17 4637.07 -319.83 3503.41 5957144.68 381652.60 MWD+IFR-AK-CAZ-SC 6197.96 45.88 94.54 4759.57 4703.47 -325.63 3571.81 5957137.77 381720.89 MWD+IFR-AK-CAZ-SC 6293.55 46.83 95.85 4825.54 4769.44 -331.90 3640.69 5957130.38 381789.66 MWD+IFR-AK-CAZ-SC 6388.75 47.80 98.00 4890.09 4833.99 -340.35 3710.15 5957120.81 381858.97 MWD+IFR-AK-CAZ-SC 6484.34 47.73 97.52 4954.34 4898.24 -349.91 3780.28 5957110.12 381928.92 MWD+IFR-AK-CAZ-SC ~ 6579.73 47.15 98.01 5018.86 4962.76 -359.40 3849.89 5957099.50 381998.37 MWD+IFR-AK-CAZ-SC ~ ! 6674.75 46J1 97.53 5083J5 5027.65 -368.78 3918.67 5957089.01 382066.98 MWD+IFR-AK-CAZ-SC ~ 6769.80 47.43 95.85 5148.49 5092.39 -376.88 3987.78 5957079.79 382135.95 MWD+IFR-AK-CAZ-SC 6864.93 48.41 94.83 5212.24 5156.14 -383.45 4058.08 5957072.08 382206.13 MWD+IFR-AK-CAZ-SC 6959.85 48.39 94.56 5275.26 5219.16 -389.26 4128.82 5957065.13 382276.76 MWD+IFR-AK-CAZ-SC 7054.87 47.90 94.61 5338.66 5282.56 -394.92 4199.37 5957058.33 382347.20 MWD+IFR-AK-CAZ-SC 7150.45 47.52 94.93 5402.98 5346.88 -400.80 4269.83 5957051.31 382417.55 MWD+IFR-AK-CAZ-SC 7245.28 46.91 94.20 5467.39 5411.29 -406.34 4339.21 5957044.64 382486.82 MWD+IFR-AK-CAZ-SC 7340.61 46.95 93.01 5532.49 5476.39 -410.72 4408.71 5957039.14 382556.23 MWD+IFR-AK-CAZ-SC 7435.72 47.05 93.98 5597.36 5541.26 -414.96 4478.13 5957033.77 382625.58 MWD+IFR-AK-CAZ-SC ~ • ~ Halliburton Company Survey Report Gompany: GanOCQPhi(ltps A4aska 4nC. .": : Da#e, 61291~i~t17 TI~: 1~'.€}4:1~ F'~age: ~ ' ~1d:'. ~O~YI~~~ f~lU~f ~t~3~ ~~tli'II11ri~~iC(1~1~~ ~ti~f~l"aC1~CC :; ~2~~: G~-~~, ~1"S(8 ~fl!'f~t : S3te Alp~ne Cf~~. "4rertical ~"'~~ Fk~t'+~i-cnce ~[?4~Q2 ~ 9 : We1i: ' ~D4-30~ . ~ ' 5ectiv n (VS) I~e3`erei~e~ = . ~ ~~11(Q 00~ ~ ~~ 55 381~~ Wellpac6,: CQ4-302, ';-- ; Su~ey Cakul~u 1~I~thud: `. TvI~namu~rr ~urv~Eure ; ~b , .QTBG(e Survey ~tiIU' IncY Azim ' TYI) „` S s 1'~?B Y 1\/~ EfVV ' 1~3aplY ; MapE ;::.Tunl °: : . . :ft ' ~e~ ' deg ' ~t : . : . ~t , fE f~ . ,ft ft i , 7530.87 47.33 95.47 5662.02 5605.92 -420.71 4547.70 5957026.90 382695.03 MWD+IFR-AK-CAZ-SC 7626.16 46.93 94.59 5726.85 5670.75 -426.83 4617.26 5957019.65 382764.49 MWD+IFR-AK-CAZ-SC 7721.42 46.82 96.63 5791.97 5735.87 -433.63 4686.45 5957011.73 382833.55 MWD+IFR-AK-CAZ-SC 7817.19 47.82 96.87 5856.90 5800.80 -441.90 4756.37 5957002.32 382903.31 MWD+IFR-AK-CAZ-SC 7911.99 47.32 95.99 5920.86 5864.76 -449.74 4825.90 5956993.36 382972.70 MWD+IFR-AK-CAZ-SC 8007.75 47.06 95.32 5985.93 5929.83 -456.66 4895.81 5956985.31 383042.48 MWD+IFR-AK-CAZ-SC I 8102.70 46.40 94.24 6051.01 5994.91 -462.43 4964.70 5956978.43 383111.27 MWD+IFR-AK-CAZ-SC 8198.01 47.54 95.04 6116.05 6059.95 -468.07 5034.14 5956971.66 383180.60 MWD+IFR-AK-CAZ-SC I 8292.95 47.09 94.46 6180.42 6124.32 -473.85 5103.69 5956964.75 383250.04 MWD+IFR-AK-CAZ-SC ; I 8388.09 47.99 95.17 6244.64 6188.54 -479.74 5173.63 5956957.73 383319.87 MWD+IFR-AK-CAZ-SC 8482.67 47.82 96.31 6308.05 6251.95 -486.76 5243.45 5956949.58 383389.57 MWD+IFR-AK-CAZ-SC 8577.90 47.18 95.68 6372.39 6316.29 -494.10 5313.28 5956941.11 383459.26 MWD+IFR-AK-CAZ-SC 8673.15 46.60 96.03 6437.48 6381.38 -501.19 5382.45 5956932.90 383528.31 MWD+IFR-AK-CAZ-SC 8768.41 47.17 95.77 6502.59 6446.49 -508.34 5451.62 5956924.64 383597.35 MWD+IFR-AK-CAZ-SC 8863.47 46.64 94.67 6567.53 6511.43 -514.66 5520.75 5956917.20 383666.35 MWD+IFR-AK-CAZ-SC 8958.76 46.59 95.61 6632.99 6576.89 -520.86 5589.72 5956909.88 383735.21 MWD+IFR-AK-CAZ-SC 9054.22 45.43 95.30 6699.29 6643.19 -527.39 5658.09 5956902.24 383803.46 MWD+IFR-AK-CAZ-SC 9149.49 45.71 96.12 6765.98 6709.88 -534.16 5725.78 5956894.38 383871.03 MWD+IFR-AK-CAZ-SC 9245.04 46.45 97.93 6832.26 6776.16 -542.58 5794.08 5956884.85 383939.18 MWD+IFR-AK-CAZ-SC 9340.24 45.48 96.79 6898.43 6842.33 -551.36 5861.96 5956874.98 384006.89 MWD+IFR-AK-CAZ-SC 9435.28 44.85 96.88 6965.44 6909.34 -559.38 5928.87 5956865.87 384073.67 MWD+IFR-AK-CAZ-SC 9530.61 43.42 96.28 7033.86 6977.76 -566.99 5994.82 5956857.19 384139.47 MWD+IFR-AK-CAZ-SC 9558.35 42.80 96.16 7054.11 6998.01 -569.04 6013.66 5956854.84 384158.28 MWD+IFR-AK-CAZ-SC ~, 9626_00 42.80 96.16 7103.75 ~ 7047.65 -573.97 6059.36 5956849.16 . 384203.89 - PROJECTED t0 TD Message ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 01, 2007 2:Q9 PM To: 'Galiunas, Elizabeth C' Subject: RE: GD4-302 (~,.Q~} Water flow log update Hi Liz, This is good news. Do you know when the log will be submitted? I'd like to have a look at it when it gets in. A quick request, please include the permit number in messages. Makes it easy to file. Call or message with any questions. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Efizabeth.C.Galiunas@conocophiRips.cam] Sent: Wednesday, August Q1, 2007 2:05 PM To: Maunder, Thomas E (DOA) Subject: CD4-3Q2 Water flow log update Hi, Tom, I wanted to fifl you in on our recent water flow log performed on CL14-302. This is the wetf we had troubfe cireulating on and ended up squeezing cement and discussed the cement bond log with you. Befow is the summary from the water flow log that Efine did pn 7/27/07. Looks iike great news. RAN RST WATER FLOW LOG, FULLBORE SPINNER, AND TEMPERATURE LOG. RESULTS: 100% OF INJECTION INTO I~UPARUK "C" SAND FROM 9398-94I3'. NO UPFLOW DETECTED ON RST WATERFLOW STATIONS AT 9368, 9338, 9308, AND 9278'. N!3 INDICATION OF CHANNELING ABOVE PERFORATIONS WITH WARMBACK PASSES. LQGGED TEMPERATURE PASSES TO 9510'. DID NOT TAG PBTD. Let me know if you have any questions or would like more info. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (90'n-265-6247 Cell: (90'n-441-4871 8/1/2007 MEMORANDUM ~ To: Jim Regg ~ P.I. Supervisor ~~~ ~ 7f ~~~ ~ FROM: Bob Noble Petroleum Inspector State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-302 COLVILLE RIV NAAI-K CD4-302 Src: Inspector NnN-C'nNFIDENTIAL ~ ~~(~ ~~1 Reviewed Bi n P.I. Suprv ..,~ ~ Comm Well Name: COLVILLE RIV NAN-K CD4-302 API Well Number: 50-103-20545-00-00 Inspector Name: Bob Nobie mitRCN070718195858 Insp Num: Permit Number: 207-056-0 Inspection Date: ~~18/2007 Rel Insp Num: Packer Depth Pretest Initia! 15 Min. 30 Min. 45 Min. 60 Min. Well ~ cna-so2 !Type Inj i w~~~T~ '~ 6z3~ , IA ~ 3zo ~ 2200 ~ zzoo ~~ 220o i ~-- ~""0560 T eTest sPT ' Test si i P.T.llI - ~ YP , i P zzoo ! OA ~ aoo ~ aoo j ~ _+- aoo j aoo ~ - ~-- --~-- -j-- , - _ Interval ~iT~- P/F _° _ ,~ Tubing j isso I isso isso isso Notes: ~~,~~~,~5 AU G ~- 6 200~ Friday, July 20, 2007 Page 1 of I 06/28/07 • I ~ ~~~~~~~~~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # ~~~ ~~ Log Description Date BL NO. 4311 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Prints CD CD4-302 11665451 USIT 06N9/07 1 CD4-319 11665448 MAXTRAC IPROF 06/17/07 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. I~, Re: Update on CD4-302 7" casing cement • ~ Subject: Re: Update on CD4-302 7" casing cement From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Tue, 19 Jun 200~ 17:04:52 -0800 To: "Galiunas, Bliza.beth C" <Elizabeth.C.Galiunas@conocophillips.com> CC: "Noel, Brian" <Brian.Noel@conocophillips.com>, Robin Smyth ~~~ ~ ~~~ <rsmyth@anchorage.oilfield. slb.com> All, This reply confirms Brian and Robin's delivery of the USIT log and our examination of it. It appears that the TOC of the 2nd squeeze could be above the Qannik. The lower portion across the Nanuq looks to be well cemented. At the Kuparuk, there appears to be cement bonded across the sand. However, there does not appear to be much coverage above or below the logged top of the sand. It is proposed to run a straddle completion with the top packer above the Nanuq and the lower packer above the top Kuparuk squeeze perforations. The tubing tail will be about 100' above the top Kuparuk squeeze perforations. Placing the straddle and tubing ta.il as planned will isolate the Nanuq squeeze perforations from the high pressure injection water intended for the Kuparuk and leave room to perform remedial work if necessary above the top of the Kuparuk. Completing the well as planned should provide rnechanical isolation of the intervals. While there is cement indicated across the Kuparuk interval, after the well is in service either a temperature survey or water flow log should be conducted to assure water is being injected into the Kuparuk interval. The zones surrounding the Kuparuk are not permeable and the inability to circulate cement up the hole while squeezing is a sign that upward isolation does exist. Call or message with any questions. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 6/18I2007 2:15 PM: ' Tom - ' Here's an update on weekend operations to cement the 7" casing on CD4302 a Kuparuk sand injection well: ' 1) Ran in with bit and closed/drilled out the Qannik sand stage collar at 5740', drilled the baffle plate at ' 9525' and tagged the float collar at 9569'. 2) Pert'd base of the Kuparuk sands 9410' - 9415' at 6 spf but were unable to circulate backside of the 7" ' to surFace. PerPd 9369' - 9371' (25' above top of the sand) at 6 spf and set cement retainer between the ', perfs at 9390'. Stung into retainer to flush perfs, pumping 35 bbls mud with intermittent returns. Then ' pumped 6 bbl of 15.9 ppg class G at 1 bpm through lower perfs with returns, unstung and placed 9 bbls ' on top of retainer and attempted down squeeze holding pressure for 20 minutes. 3) Pert'd base of Nanuq sand 8457' - 8459' at 12 spf. Circulate backside of 7" casing at 4 bpm with full returns at surface. Set cement retainer at 8357' and circulated 130 bbls of 11 ppg Litecrete to cover both the Nanuq (top at 8271' md) and Qannik (top at 5193' md) sands. Planned TOC assuming 34% excess is 500' above the Qannik and had full returns while pumping the job. 4) Plan forward operations: clean out 7" to below Kuparuk, run cement bond log and pending log results run the completion. ' Attached are annotated log across the Kuparuk showing 7" casing, perFs and cement retainer depths and ; a reviseci completion with the Nanuq cementing perfs straddled by packers. And the schematic with 1 of 2 6/20/2007 7:34 AM Re: Update on CD4-302 7" casing cement ~ i ' actual depths, perforations, and proposed completion. L.et us know if more informa#ion is needed. Give us a call if you have any questions or comments. Liz and Brian , «CD4-302 Kuparuk squeeze.PDF» «CD4-302 actual schematic.pdf» 2 of 2 6/20/2007 734 AM ?c.Es Ls , g 3�t 9500 S 1nsp 9srs -gsyr F.c. yuq 9600 9GK 9G zG' BIRMIMINVIIEU X111111 i 1�1IIIIIN�IIIf�I LlI I tl p ll11 11�! L� � ' 1Ilpkp1Ng11ll11l1111l 6"61idl11 111111111111111 LUNE IMMO III1IIIII °IHflhIIII �� IIIIIIIIIIIIllhI 1I�II 111111111 R�111F IIflhIIIiIIII � pppll � l I11IIIIIIIIII IIiII �I!p�P�Nwllflllllll�l IilIIIIIIIIIIIIll 'I ME i 1 1 1 1 1 1 E / 4qf� 940 q1f 950 :. 600 • • CD4-302 Nanuq Kuparuk Injector Completion 16" Insulated Conductor to ~114' 4-'/i' 12.6 ppf L-80 IBT Mod. Tubing Updated 06-18-07 ECG with actual survevs 3.81" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2764' MD / 2389' ND Upper Completion: Top MD ND 1) Tubing Hanger 32' 32' 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 3.81" 2185' 2000' 4) 41/2", 12.6#/ft, IBT-Mod Tubing 5) Camco KBG-2 GLM 8940' 6617' 6) 41l2", 12.6#/ft, IBT-Mod Tubing 7) Baker Premier Packer 8400' 6252' S) 41/2", 12.6#/ft, IBT-Mod Tubing 7) Baker Premier Packer 9150' 6766' 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Estimated TOC: 9) HES "XN" (3.725") 9250' 6835' 4740' MD / 3749' '' ~~Qannik sand .~. 10) 41/2", 12.6#/ft, IBT-Mod Tubing (1) ' ' ~ +/- 5193' MD / 11) Wireline entry guide 9300 6870 ~~ ~ ;:. 4062' ND Stage collar at ~ 5740' MD, drilled ~ ~'~~~_.: out to close _,. _~ Lite Crete pumped 130 bbls. ~_:_~.;; ::. Perforations 2' 12 spf `:; ,~. 8457' - 8459' 2 sets perforations 9410' - 9415' 6 spf (bottom of KRU) Nanuq 8271' MD / 6165' ND ~~~~~ 9369' - 9371' 6 spf (25' above KRU) Pumped away 6 bbls, ~ „,,,, ,~ , 15.9 ppg Class G Cement Kuparuk C 9398' MD / 6939' TVD of 8'/:' hole 9626' MD! 7104' ND 7" 26 ppf L-80 BTC Mod Production Casing @+/-43° 9615' M D, 7096' ND Re: Doyon 19 CD4-302 7" casing cement • ~ Subject: Re: Doyon 19 CD4-302 7" casin~ ement ,, ~~~~~ From: T'homas Maunder <tom maunder dmin.state.ak.us> C~`- Date: Fri, 15 Jun 2007 15:30:08 -0800 To: "Noei, Brian" <BrianNoel@conocophillips.com> CC: Doyon 19 Company Man <doyonl @conocophillips.com>, "Alvord, Chip" <Chip.Alvord@conocophillips.com>, "Johnson, Vern" <Vem.Johnson@conocophillips.com>, "Galiunas, Elizabeth C" <Elizabeth.C.Galiunas@conocophillips.com> Brian, et al, I have received your message regarding your call this morning. I have advised Commissioner Seamount of the situation and that I concurred with your plan forward. Nothing further is needed at this time. Keep us advised of the operations. I will place a copy of this message in the file. Call or rnessage with any questions. Tom Maunder, PE AOGCC Noei, Brian wrote, On 6/15/2007 2:49 PM: Tom - As discussed this morning Doyon 19 is on CD4-302, a Kuparuk C sand low angle slant injection well. Drilling of the &3/4" production hole through the target is complete and 7" casing was run to 9615' and landed without problems. Formation tops (md): Qannik 5193' Nanuq 8271' Kuparuk 9398' TD 9626' ' After bringing pumps up to 5 bpm attempted to reciprocate pipe for the cement job, but the hole packed ' off. Multiple attempts were made to regain good circulation rates but eventually became unable to move ', the pipe or circulate. After pressuring up the casing to 1500 psi without circulation, suspected the shoe ' may be plugged and last night shot perfs above the float collar. Were able to establish good circulation ' rates again but the well eventually packed off. Unfortunately the last packoff pressure spike on the 7" ' casing opened the Weatherford Gemco stage collar run for the Qannik cement job. Since the pressures applied to the casing during the packoffs have exceeded the Kuparuk sand frac gradient, it's our belief the packoffs around the 7" casing are in the rat hole below the Kuparuk sand. But with the limited tD ' through the open stage tool, currently unable to continue options to place the primary cement job across ' the deeper Kuparuk and Nanuq intervals. ' Since the Kuparuk is the welPs objective, CPAI proposes to forgo the Qannik stage cement job and drill ' out the stage tool to provide fullbore access. This operation will close the stage tool permanently. Plan ' forward then is to shoot perfs at the base of the Kuparuk (9415' md), establish circulation with retums to surfiace and pump the primary job to isolate the Kuparuk and Nanuq intervals. If successful a completion ' without any squeeze perfs above the packer is still possible, providing optimum well integrity for injection & MIT's. ' Although the Qannik will not be covered with cement, the zone will be isolated from the deeper ' reservoirs. And as with the earlier drilled CD2 Alpine wells this annulus can be monitored for pressure anomalies as the Qannik interval is drilled and developed in 2008 and beyond. ' Attached are the planned completion with actual depths, annotated log across the Kuparuk showing 7" ' casing and perf intervals, and the Qannik log evaluation/structure map showing location of this well in relation to the CD2 Qannik development being planned. If wellbore conditions cause a change in plans, will keep you appnsed. Let me know if more information is needed. 1 of2 6/15/200'7 3:31 PM Doyon 19 CD4302 7" casing cement - - , • • Content-Description: CD4-302 Kuparuk log.PDF CD4-302 Kuparuk log.PDF Content-Type: application/octet-stream Content-Encoding: base64 __ _ _ Content-Description: CD4-302 schematic.PDF CD4-302 schematic.PDF Content-Type: application/octet-stream Content-Encoding: base64 __. _ 2 of 2 6/15/2007 3:22 PM CD4-302 Preliminary Log analysis: Qannik interval;realtime data ALCS.RHOM1~1 ' ,;_~'~~,.t~>Ht F~:r- ! ~:;~.ICS.~MIIR_t I SITE.RPD_FILL_ aa ~: ~a rhoqr~ir~ C.AL.GS.FHI_V~;L_ 1 CALCS.SW_t CALCS.BWV__ i ' ~ - LC~AELTA_F IP1. ITF,RP>_i~IWL`__ , ,., ~.rv s Oh.n REFER PdCE,~ DEPTH CALCS.VCLAY_1 CALCS.PHIT_1 ~ CALCS.PHIT_1 core.swir 1~ • V N • C CALCS.PERM_1 _) CALCS.PHIT_,~ . , NSITE.GR_FILI_ 5 'l1iiJ.1 ~~) oh.rm - h.rhr~t_ DIREC ONAL fF£1 ~,t•o7raphy. c~r_ ~ ~ ~ an~ _~a+ab Cr~: a~~- . ~ .. ~ - n ~tdG.ph 1~ ~ ~ J ~ , ,~re.• w_' nU ~p~,_~.~ tco ~ ~ ~ ~~ ~ ~ i ;- ~ u ~ ~ uc •. .. i_~aL~ ~~';:L».~r_ ~~~ ~-~ ~: 1A t. .. . 5 v~F vr r v~. 1 v~ . . - ...., ... __....,. r' 1 _°~ --- 5150 ~_~ ~ K_3_ BASAI 5 4 i ~ _ , - - y Top K2: 4007 S S ~ -- .m _ ... r ---- 5200 -- - i ' i I~~. ~ r~ I i ,~ 4 } i ~ f~' ~ ~-~__ ~...,. ~_....., ~~_ ~ ~ ~~~M__ •• 5250 ~ _~_ ! t ~ «~~~;? ~ " ~ K 7 _2 39 ~ r ~~ , ~ ~~., M f-. ~ { ~, ' I. ~ Net oil Pay; 13ft (prelim) ~ ~ Avg Perm: 6md ~' ~,~ Avg Sw: 35% ~ ~ ~. • • .~ K2 Structure ~ ~; \~ , ,~- ~ ~/~ ~ ~ ~" • C I : 10ft '~- - ~ ~:~. • r--~a~ ¢ :, ~ ~ ~ ~--,- ~ ` ~ - ~., ~~ t~;, ~ - ~ ~ ~ / ~'~d ~~ ~, i ~~; ; ~ ~ . ~ , ~ , ,~ ., ~ ~--. ~ ~-~ ° ~ 5970000 ~~1 ~ 3980; ~~ ~ ~...`-~-~_` i` 1 ~ d, J' \ , ~\.~~ ~ ~ ~ s I ~ ~~,\ ~ oa. J ~ '~~ - ~' ' / ~~~ , h j . ~ ~ , ~ a~, ~~/r~ `~ ~ -~..,, a:~> ., r ~ ~~•_ 5 r, ~ ~ ~ ~ ~lr._~,~ ~ `~~ ~ ~ti I ~ ssssooa ~' ~ ~~,~ ; ~ CD4-302 ~ ~`" I , ~, ; F~ 1 ~ Possible ~ K2 M ~ revision of ~ ~ ~ .,d , intersection: 1 4000' contour % ~ ' ,~ ~' 4007ft SS Southeast ~~--''~ .~`~ f o 0 corner of / ,.~ ~ ~ ~"""~ ~ Alpine CD2 ! ,' °°~°"~~ ,~ -.-.~ ~`"~, ,r , i' nine well ~ ~ ~ ~/ ~ ~ development ~ ~ ~' " ~ `` ~ `1 ~° t ~ ~'-~ ~i sssoooo ~' ~. 't n ~~ , f ~ ~I ~~ / . ~~ (`-~1 ~ ~' ~~ l / ~ l I ~ ~~... ``"-'~ ~.`\ } \ ! ~./ l ,.. ` ~t ~ ~ , ~ "_. ~ `~ 4 > >,t CD4-302 e:;' ~ `~- ~ ~ '~ ' , -• ~. ~ . ~ f ~ f ~ ~ ~ '~,` ~ ;" _( ~~ ,~" (.lli-3Uy ~~,, + "`~.~ ~ ~. ~ r ~ ~~ ,~ \ .~ ~ ~ ~ ~ ~ w , r ~ ~ w~~, ~,~, ~, ~ ~ ~ , ~,,-. 39~ ~ ~~ ~~... ~ ~ ~ ~~ ~ ~ ~ ~~ ~~' ~~~ ~ A ~, y ~ ~ ~ , `~ ~ r ,tiG ~ '`--~. 5955000 ~~ ~ ~{o~ ~ lwo ~ ws~ ~i',\ fipe ~ ~~~ ~~~t`tj ~ ~ f ~ .i---., 1 l 5 ,~ -,;;-~ ~.~t,~``,ti 1 ~ ~ ---~-~~``~_a__.~ . ~,,-~ '~~,~ L\ ~ 1 ~ ~ 1 %~'- `~ ~. _ ~~~., l ,~--~'~--`_`.~. ~° --__ _ .~ 1510000 1515U00 1520000 152500~ • • ~ ~.J~1 ~ a ~ t 7 C~`~-3~z.. • • t ;` ~ 9. CD4-302 Completion Schematic ~ ~ • • ConocoPhillips 16" Insulated Conductor to -194' 4%:" 12.6 ppf L-80 IBT Mod. Tubir~ 3.81" DB l..anding Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2755' MD ! 2400' ND U~dated 04-23-07 EC~ Upper Compietion: 1) Tubing Hanger ~`6~ ~ D Stage cementing too! +/- 5 ByMD, ND 57~~• Top AAiID ND Angle 32' 32' 0 2171' 2000' 44 8940' 661T 47 9040' 6685' 9140' 6753' 47 9152' 6761' 47 2} 41/2", 12.6#tft, IST-Mod Tubing 3) Camco DB nipple 3.81" SI'~ 3~ 4) 4-il2*. 12.6#/ft, IBT-Mod T~ing K2/Qa~nik sand 5) Camco KBG-2 GI.M with shear valve 1~y +/- ~`MD / 6) 41/2'. 12.6#/ft, IBT-Mad Tubing . . ' ~ 7) Baker 53 packer with Miilout extensian " ~- 8} 41/2 , 12.6#/ft, IBT-Mod Tubin9 (2) = ~ 9) HES "XN" {3.725") ~ 10) 11) 41/2", 12_6#!ft, IBT-Mod Tubin9 (1) Wireline entry guide Top of intem~ediate cement 500' above top of Planuq , 7776' MO / 5822' ND ~Z71 ~ Nanuq~6`'~MD /-~D Kuparuk C 9485` MD / 6~ `r'3~& ` ±/-15' perforations 7" 26 ppf L-80 BTC Mod Production Casing Q ±~?~ 1a6~"~MD. ~ABz^~F@~ y3~ ~S,S~ CD4-302 Page 13 of 14 Drilling Program Version 1.3 (6/4/20Q7) ~ . ~ ~ ~ ~ ~ ~~ '~ SARAH PALIN, GOVERNOR ~~~ ~~ ~`L ~ 333 W. 7thAVENUE, SUITE 100 COI~TSER'PA7'I011T CO1~IIrII5SIOI~T ANCHORAGE,ALASKA 99501-3539 PHONE (907} 279-1433 FAX (907) 276-7542 Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-302 ConocoPhillips Alaska, Inc. Permit No: 20?-056 Surface Location: 2887' FNL, 89' FEL, SEC. 24, T11N, R4E Bottomhole Location: 3454' FNL, 4346' FEL, SEC. 20, T11N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, i~~~~ Dan T. Seamount Commissioner DATED thi~ day of May, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ STATE OF ALASKA ~5f ALASKA OIL AND GAS CONSERVATION COMMISSION ~'~- PERMIT TO DRILL 20 AAC 25.005 ~EC~iv~~ APR 2 7 2C07 :;xa pii ~x Gas Cons. Cammission Anchorage 1 a. Type of Work: Driil Q° Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ~ Development Oil ~ Stratigraphic Test ^ Service ~^ ~ Development Gas ~ Multiple Zone^ Single Zone ~ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 , 11. Well Name and Number: CD4-302 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 95fl5` % TVD; 74{32' ~ 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): ` Surface: 2887 ~NL, 89 FEL, Sec. 24 , T 11 N R 4 E 7. Property Designation: ~ /, ADL 384211, 380077 Nanuq Kuparuk Oil Pool '' Top of Productive Horizon: 3449 FNL: 4395 FEL: Sec. 20 , T 11 N R 5 E 8. Land Use Permit: LAS2112 13. Approximate Spud Date: 5125/2Q(~7 Total Depth: 3454` FNL, 4348' FEL, SeC. 20 , T 11 N R 5 E~ 9. Acres in Property: 57~g 14. Distance to ~ L,~r'~.y (t, ~ ba=~ Nearest Property: 140' FEL of Nanu P~.~, 4b. Location of Well 'S ate Base Plane Coordinates): ~"~r,~ ; Sui'f2Ce Xr~~l~81 &5 .13 ~. ~c' `'' ~ y- 595752'I .2 ZOtle- 4 10. KB Elevation / ~fb } 4. /Lf~L ~Height above GL): 37' RKB feet t~ ~ 15. Distance to Nearest ` / Well within Pool: Nanuq 5: 8189' at 9350' MD140 16. Deviated wells: Kickoff depth: 400 ~ ft. Maximum Hole Angle: 47° deg 17. Maximum Anticipated Pressures in psig (see 2o AAC 25.035) t3ownhole; 3168 psig ~ Surface: 2468 psig ~ 18. Casing Program if ti S Setting Depth Quantity of Cement Size iCa ons peC Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage dataj "~" ~~" ~~.5# €~-4£~ ~`~I~lci~u 77 37 37 11~ 114' pre-installed 12_25'° 5-5>€" 4~# ~-~~ ~'=,"C 2718 37 37 275~ 24€10 479 sx AS Lite, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 94~8 37 37 95fl5 7402 329 sx G[ass G. 169 Sx class G far K2 4.5" 12.6# L-80 IBT 912U 32 32 9152 6761 tubir~g 19 PRESENT WE~L CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Totai Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Cond uctor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth Tl/D (ft): 20. Attachments: Filing Fee ~ BOP Sketch~ Drilling ProgramQ Time v. Depth Piot ~ Shallow Hazard Analysis Q 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 L, fi~8/iut]~S Printed Name C. Aivord Title WNS Drilling Team Lead Signature Phone ZGS G~2~ Date Gr u Z9Q ~ ~L. lins Commission Use Only Permit to Drill Number: ~',~ ~~ ~ ~ j ~j API Number: 50- ~~„~ ` ~~~~~' ~--~ ~ Permit Approval Date: , ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~ {`~,~`~s~' CS~MC~~,~~i~,~~~~ Samples req'd: Yes ^ No ~ Mud log req'd: Ye0 N~' Other. ~~~~` ~~~~M~~~~~ ~~ H2S measures: Yes ~ No [v~' Directional svy req'd: Yes []' No ^ ~~,~,~~~5 ~~.~ ~.~~~ ~~~ Rt~ a~ , ~~~-.-~ti~~.~ ~~o~~~~.~Qo~sc~.~C~ ~ f-~ APPR B HE COMMISSION ~ DATE: °. ~ I ~ , COMMISSIONER F~+1- J (.7 ~ ~~j~ ~I~~t~ ~~y//~ / Form 10-401 Revise 12/2005 ~~bmjt~ Du cate Y ~olv ..~ ~•.3~~-c~-7 ^ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 25, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-302 Dear Sir or Madam: • ~QI'lOCO ~"i1~~1 5 p ~~~+E~~~:~ ~~PR 2 7 70u~ °~Ia~k~ t~ii $~ Gas Cons. Cammissiuo Anchorage . ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this well is 5/25/2007. It is intended that Doyon Rig 19 be used to drill the well. ' ~ CD4-302 will be a low angle slant well, penetrating the Kuparuk C sand. After setting 7" intermediate casing the well will be completed and perforated as a WAG injector well supporting Kuparuk production wells. At the end of the rig program, the well will be perforated then flowed back to mitigate formation ,- damage. The well will then be closed in awaiting completion of facilities connection which wil! allow the well to begin injection. i It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. !t is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. There have been 12 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. ~ 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. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b), Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drifling fluids handfing system. 3. Diagram of diverter set up. ~ . If you have any questions or require further information, please contact Liz Galiunas at 265- 6247 or Chip Alvord at 265-6120. Sincerely, Liz Ga iu s Drilling Engineer Attachments cc: CD4-302 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation ~ ~ CD4-302 Drilling Hazards Summary (to be posted in Rig Floor poghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casina Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuousl durin interval. Well Collision Low G ro sin le shots, travelin c linder dia rams 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 Increased mud weight Surface Formations / >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casinq 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 praperties, 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 ~ Q ~~~~~AL ~ ~ Fiord : CD4-302 Procedure 1. Move on Doyon 19. i 2. Drill 12-'/<" hole to the surface casing point as per the directional plan. (Directional/MWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 3500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. / 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 10. Run 4-'h, 12.6#, L-80 tubing with DB profile, packer, GLM with shear out valve, XN profile and wireline entry guide. 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 rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 15. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly, GLV change out, running cement evaluation logs below the tubing tail, perforating the Kuparuk interval and setting an injection valve. ~~4~I~A~ ~ Well Proximitv Risks: ~ Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-208 is the nearest existing well to the CD4-302 plan with 121' well to well separation at 400' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ° Lost circulation: Faulting and low reservoir pressure within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with (ost circulation. Annular Pumpinp Operations: Incidental fluids developed from drilling operations on well CD4-302 will be injected into a permitted annulus, on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-302 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' ND. The significant hydrocarbon zones are the Nanuq, Kuparuk, and the Qannik reservoir. There will be 500' of cement fill above the top of the Nanuq and Qannik reservoirs. Upon completion of CD4-302 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 ND) + 1,500 psi _ (12.0 ppg) "` (0.052) " (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 -1086 = 1912 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 (ppf~ Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ~~'~~~~~~L ~ ~ DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12 '/4" Intermediate hole to 7" casing point - 8 3/<" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg PV 10 - 25 YP 20 - 60 15 - 25 Funnei Viscosity 900 - 200 Initial Gels 4 - 8 10 minute gels <18 API Filtrate NC -10 cc / 30 min 4-12 cc/30 min (drilling) HPHT Fluid Loss at 160 PH 8.5-9.0 9.0-10.0 KCL Surface Hole: ~ A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. ~~~~~~~~ i Completion Schematic ~ 16" Insulated Conductor to --114' 4-%Z" 12.6 ppf L-80 IBT Mod. Tubing 3.81" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2755' MD / 2400' ND Updated 04-23-07 ECG Upper Comptetion: Top MD ND Angie 1) Tubing Hanger 32' 32' 0 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 3.81" 2171' 2000' 44 TOC 4) 4-1l2", 12.6#/ft, IBT-Mod Tubing +/- 4689' MD / K2/Qannik sand 5) Camco KBG-2 GLM with shear valve 8940' 6617' 47 ' °+~- 5189' MD / 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3718 ND `: 4059' lVD ~) Baker S3 packer with Millout extension 9040' 6685' 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) 9) HES "XN" (3.725") 9140' 6753' 47 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) Stage cementing 11) Wireline entry guide 9152' 6761' 47 tool +/_ 5658' MD / 4379' TVD Top of intermediate cement 500' above top of Nanuq . 7776' MD / 5822' TVD Nanuq 8276' MD / 6164' ND Kuparuk C 9405' MD / 6933' TVD +/- 15' perforations 7" 26 ppf L-80 BTC Mod Production Casing @ +/-47° 9505' MD, 7002' ND ~~~~~~~L ~ CD4-302 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 si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2755 / 2400 14.5 1086 1571 7" / TD 9505 / 7002 16.0 3168 2468 NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 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 psi/ft 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 conductor casing (16") ASP =[(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53psi OR ASP = FPP - (0.1 x D) = 1086 -(0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP =[(FG x 0.052) - 0.1] D _[(14.5 x 0.052) - 0.1 ] x 2400 = 1570 psi OR ASP = FPP - (0.1 x D) = 3168 -(0.1 x 7002') = 2468 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3168 -(0.1 x 7002') = 2468 psi / ~~~~~I~~L L~ Cementin~ Pro~ram: i 9 5/8" Surface Casing run to 2755' MD / 2400' TVD. Cement from 2755' MD to 2255' (500' of fill) with Class G+ Adds @ 15.8 PPG, and from 2255' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1386' MD). Lead slurry: (2255'-1386') X 0.3132 ft3/ft X 1.5 (50% excess) = 408.2 ft3 below permafrost 1386' X 0.3132 ft3/ft X 4(300% excess) = 1736.3 ft3 above permafrost Total volume = 408.2 + 1736.3 = 2144.6 ft3 => 479 Sx @ 4.48 ft3/sk System: 479 Sx ArcticSet Lite 3@ 10.7 PPG yielding 4.45 ft3/sk, Class G+ 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin~ run to 9505' MD / 7002' TVD •,/' Cement from 9505' MD to 7776 +/-' MD (minimum 500' MD above top of Nanuq reservoir) with Class G+ adds @ 15.8 PPG. Assume 40°/a excess annular volume. Tail: (9505' -7776) X 0.1503 ft3/ft X 1.4 (40% excess) = 364 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 161 + 17.2 = 381 ft3 => 329 Sx @ 1.16 ft3/sk System: 329 Sx Class G+ 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a TAM port collar set 500' below the K2 interval to +/- 500' above the K2 interval with Class G+ additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5658'-4718') X 0.1503 ft3/ft X 1.4 (40% excess) = 197.8 ft3 annular vol. Total Volume = 197.8 ft3 => 169 Sk @ 1.17 ft3/sk System: 169 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additive~~V~l~e~~t~ ~ s ~ ~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Ina Date: 4/13/2007 Time: 15:11:44 Page: - 1 Field: Colville Rivet' Unit Co-ordinate(NE) Reference: Well: Plan: CD4-302, True North i Site: Alpine CD4 Vertical ('I'VD) Reference: Plan: CD4-302 55.9 ' Well: Plan: CD4-302 Section (VS) Reference: Well {O.OON,O.OOE,95.38Azi} , Wellpath: Plan: CD4-302 Survey Calculation Method: Minimum Gurvature r Db: Orade- Plan Section Information NID Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft degY100ft deg/100ft deg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 2280.60 47.02 95.38 2076.55 -68.36 726.04 2.50 2.50 0.00 0.00 9436.97 47.02 95.38 6955.80 -559.10 5938.10 0.00 0.00 0.00 0.00 9437.11 47.02 95.38 6955.90 -559.11 5938.20 3.50 3.45 0.81 9.72 CD4-302wp02 T1 9451.78 47.02 95.38 6965.90 -560.12 5948.89 0.00 0.00 0.00 0.00 9505.00 47.02 95.38 7002.18 -563.77 5987.65 0.00 0.00 0.00 0.00 Plan: CD4-302wp02 Date Composed: 3/6/2007 slant well Version: 2 Principal: Yes Tied-to: From Well Ref. Point Fieid: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD4 Site Positio~: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-302 Slot Name: Well Position: +N/-S -5.20 ft Northing: 5957521.22 ft~ Latitude: 70 17 32.915 N +E/-W -19.49 ft Easting : 378155.13 ft i Longitude: 150 59 11.331 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-302 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-302 Height 55.90 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 4/11/2007 Declination: 22.82 deg Field Strength: 57561 nT Mag Dip Angle: 80.68 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 95.38 Survey Program for Definitive Wellpath Date: 3/6/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft :, a' E~ ~~~~~~~ WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot Plan: CD4-302 -5.20 -19.49 595752122 378155.13 70°17'32.915N 150°59'11.331W N/A WELLPATH DETAILS Plan: CD4-302 Rig: Doyon 19 Ref Datum: Plan: CD4-302 55.90ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 9538° 0.00 0.00 3630 T M Azimuths to True North Magnetic North: 22.82° Magnetic Field Strength: 57561nT Dip Angle: 80.68° Date: 4/1 U2007 Model: bggm2006 SURVEYPROGRAM Depth Fm Depth To Swvey/Plan Tool 3630 1000.00 Planned: CD4-302wp02 V2 CB-GYRO-SS 1000.00 9505.00 Planned: CD4-302wp02 V2 MWD+IFR-AK-CAZ-SC ~ ~ ~ 0 ~ ~ > z F PLAN DETAILS CD4-302wp02 slant well Version 2 3/6/2007 Start Point MD Inc Azi T'VD +N/-S +E/-W 3630 0.00 0.00 3630 0.00 0.00 "'°'"'~"'RT°" __ Conoc Phillips ~rnr or~~nn~ servacss Alaska Vertical Section at 9538° [2000ft/in~ 400 I I , I 200 I I ' ~ ~ I ~ 0 0 i ( c°~_d o° o° o + a ~ ~ 0 ~ e ~ ,; CD4-302 02 5 ~ I I __ ! -200 I II I I I 0 2000 4000 6000 Weri(')/East(+) [2000ft1in] REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD4-302, True North Vertical (TVD) Reference: Plan: CD4-302 55.90 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: Plan: CD4-302 55.90 Calculation Method: Minimum Curvature , ~ ConocoPhillips • Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Ina Date: 4/13/2007 Time: 15:11:44 Page: 2 Field: Colville Rive r Unit Co-ordinate(NE) Reference: Well: Plan: CD4•302, True North Site: Alpine CD4 Vertica l (TVD) Reference: Plan: CD4-302'S5.9 Well: Plan: CD4-302 Section (VS} Reference: Well (O.OON,U.OOE~95.38Azi) Wellpath: Plan: CD4-302 Survey CalcuFation Niethod: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS ' Comme t R deg deg ft ft ft ft ft ft deg/1OOft ft 36.30 0.00 0.00 36.30 -19.60 0.00 0.00 5957521.22 i 378155.13 - 0.00 0.00 100.00 0.00 0.00 100.00 44.10 0.00 0.00 5957521.22 378155.13 0.00 0.00 200.00 0.00 0.00 200.00 144.10 0.00 0.00 5957521.22 378155.13 0.00 0.00 300.00 0.00 0.00 300.00 244.10 0.00 0.00 5957521.22 378155.13 0.00 0.00 400.00 0.00 0.00 400.00 344.10 0.00 0.00 5957521.22 378155.13 0.00 0.00 KOP; 2.5 DLS, 0 T 500.00 2.50 95.38 499.97 444.07 -0.20 2.17 5957520.98 378157.30 2.50 2.18 600.00 5.00 95.38 599.75 543.85 -0.82 8.68 5957520.26 378163.80 2.50 8.72 700.00 7.50 95.38 699.14 643.24 -1.84 19.52 5957519.07 378174.62 2.50 19.61 800.00 10.00 95.38 797.97 742.07 -3.26 34.66 5957517.40 378189.73 2.50 34.82 900.00 12.50 95.38 896.04 840.14 -5.09 54.09 5957515.25 378209.12 2.50 54.33 1000.00 15.00 95.38 993.17 937.27 -7.32 77.75 5957512.64 378232.74 2.50 78.09 1100.00 17.50 95.38 1089.17 1033.27 -9.94 105.61 5957509.57 378260.55 2.50 106.07 1200.00 20.00 95.38 1183.85 1127.95 -12.96 137.61 5957506.04 378292.50 2.50 138.21 1300.00 22.50 95.38 1277.05 1221.15 -16.35 173.69 5957502.05 378328.51 2.50 174.46 1400.00 25.00 95.38 1368.57 1312.67 -20.13 213.78 5957497.63 378368.54 2.50 214.73 1500.00 27.50 95.38 1458.25 1402.35 -24.27 257.81 5957492.77 378412.49 2.50 258.95 1600.00 30.00 95.38 1545.92 1490.02 -28.78 305.70 5957487.49 378460.29 2.50 307.05 1700.00 32.50 95.38 1631.40 1575.50 -33.65 357.34 5957481.79 378511.85 2.50 358.92 1800.00 35.00 95.38 1714.54 1658.64 -38.85 412.65 5957475.69 378567.06 2.50 414.47 1900.00 37.50 95.38 1795.18 1739.28 -44.40 471.51 5957469.19 378625.82 2.50 473.60 2000.00 40.00 95.38 1873.16 1817.26 -50.26 533.83 5957462.32 378688.03 2.50 536.19 2100.00 42.50 95.38 1948.34 1892.44 -56.44 599.46 5957455.07 378753.55 2.50 602.12 2200.00 45.00 95.38 2020.57 1964.67 -62.92 668.31 5957447.48 378822.27 2.50 671.26 2280.60 47.02 95.38 2076.55 2020.65 -68.36 726.04 5957441.11 378879.90 2.50 729.25 Sail; 47° for 715 ' 2300.00 47.02 95.38 2089.78 2033.88 -69.69 740.16 5957439.55 378894.00 0.00 743.44 2400.00 47.02 95.38 2157.96 2102.06 -76.55 812.99 5957431.51 378966.71 0.00 816.59 2500.00 47.02 95.38 2226.14 2170.24 -83.41 885.83 5957423.48 379039.41 0.00 889.74 2600.00 47.02 95.38 2294.32 2238.42 -90.26 958.66 5957415.44 379112.12 0.00 962.90 2700.00 47.02 95.38 2362.50 2306.60 -97.12 1031.49 5957407.40 379184.82 0.00 1036.05 2755.00 47.02 95.38 2400.00 2344.10 -100.89 1071.55 5957402.98 379224.81 0.00 1076.29 9 5/8" 2760.72 47.02 95.38 2403.90 2348.00 -101.28 1075.71 5957402.52 379228.97 0.00 1080.47 C-30 2800.00 47.02 95.38 2430.68 2374.78 -103.98 1104.32 5957399.37 379257.53 0.00 1109.20 2900.00 47.02 95.38 2498.86 2442.96 -110.83 1177.15 5957391.33 379330.23 0.00 1182.36 3000.00 47.02 95.38 2567.04 2511.14 -117.69 1249.98 5957383.29 379402.94 0.00 1255.51 3100.00 47.02 95.38 2635.22 2579.32 -124.55 1322.81 5957375.26 379475.64 0.00 1328.66 3200.00 47.02 95.38 2703.40 2647.50 -131.41 1395.64 5957367.22 379548.34 0.00 1401.82 3300.00 47.02 95.38 2771.58 2715.68 -138.26 1468.47 5957359.19 379621.05 0.00 1474.97 3318.07 47.02 95.38 2783.90 2728.00 -139.50 1481.63 5957357.73 379634.18 0.00 1488.19 C-20 3400.00 47.02 95,38 2839.76 2783.86 -145.12 1541.31 5957351.15 379693.75 0.00 1548.12 3500.00 47.02 95.38 2907.94 2852.04 -151.98 1614.14 5957343.11 379766.46 0.00 1621.28 3600.00 47.02 95.38 2976.12 2920.22 -158.84 1686.97 5957335.08 379839.16 0.00 1694.43 3700.00 47.02 95.38 3044.30 2988.40 -165.69 1759.80 5957327.04 379911.87 0.00 1767.58 3800.00 47.02 95.38 3112.48 3056.58 -172.55 1832.63 5957319.00 379984.57 0.00 1840.74 3900.00 47.02 95.38 3180.67 3124.77 -179.41 1905.46 5957310.97 380057.28 0.00 1913.89 4000.00 47.02 95.38 3248.85 3192.95 -186.27 1978.29 5957302.93 380129.98 0.00 1987.04 4100.00 47.02 95.38 3317.03 3261.13 -193.12 2051.12 5957294.89 380202.68 0.00 2060.20 4200.00 47.02 95.38 3385.21 3329.31 -199.98 2123.96 5957286.86 380275.39 0.00 2133.35 4300.00 47.02 95.38 3453.39 3397.49 -206.84 2196.79 5957278.82 380348.09 0.00 2206.50 4400.00 47.02 95.38 3521.57 3465.67 -213.70 2269.62 5957270.79 380420.80 0.00 2279.66 4500.00 47.02 95.38 3589.75 3533.85 -220.55 2342.45 5957262.75 380493.50 0.00 2352.81 4600.00 47.02 95.38 3657.93 3602.03 -227.41 2415.28 5957254.71 380566.21 0.00 2425.96 4700.00 47.02 95.38 3726.11 3670.21 -234.27 2488.11 5957246.68 380638.91 0.00 2499.12 4800.00 47.02 95.38 3794.29 3738.39 -241.13 2560.94 5957238.64 380711.62 0.00 2572.27 =0 ~ ~~~~~~~~~~ . ~ onocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 4/13/2007 Time: 15:11:44 Page: 3 Field: Colvilie River Unit Co-ordinate(NE) Reference: Well: Plan: CD4~2, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan: CD4-302 55,9 We1L• Plan: CD4-302 Section (VS) Reference: WeII (O.OON;O:OOE,95.3$Azi) Wellpath: Plan: CD4-302 Survey Calculation Method: Minimum Curvatuce Db: Oracle Survey MD ft 4830.23 4900.00 5000.00 5100.00 5139.70 5189.57 5200.00 5300.00 5343.57 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7882.42 7900.00 8000.00 8100.00 8200.00 8275.49 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 8997.10 9000.00 9100.00 9195.11 9200.00 Incl deg 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 47.02 Azim TVD Sys TVD N/S E/W deg ft ft ft R 95.38 3814.90 3759.00 -243.20 2582.96 95.38 3862.47 3806.57 -247.98 2633.77 95.38 3930.65 3874.75 -254.84 2706.60 95.38 3998.83 3942.93 -261.70 2779.44 95.38 4025.90 3970.00 -264.42 2808.35 95.38 4059.90 4004.00 -267.84 2844.67 95.38 4067.01 4011.11 -268.56 2852.27 95.38 4135.19 4079.29 -275.41 2925.10 95.38 4164.90 4109.00 -278.40 2956.83 95.38 4203.37 4147.47 -282.27 2997.93 95.38 4271.55 4215.65 -289.13 3070.76 95.38 4339.74 4283.84 -295.99 3143.59 95.38 4407.92 4352.02 -302.84 3216.42 95.38 4476.10 4420.20 -309.70 3289.25 95.38 4544.28 4488.38 -316.56 3362.09 95.38 4612.46 4556.56 -323.42 3434.92 95.38 4680.64 4624.74 -330.27 3507.75 95.38 4748.82 4692.92 -337.13 3580.58 95.38 4817.00 4761.10 -343.99 3653.41 95.38 4885.18 4829.28 -350.85 3726.24 95.38 4953.36 4897.46 -357.70 3799.07 95.38 5021.54 4965.64 -364.56 3871.90 95.38 5089.72 5033.82 -371.42 3944.73 95.38 5157.90 5102.00 -378.28 4017.57 95.38 5226.08 5170.18 -385.13 4090.40 95.38 5294.26 5238.36 -391.99 4163.23 95.38 5362.44 5306.54 -398.85 4236.06 95.38 5430.63 5374.73 -405.70 4308.89 95.38 5498.81 5442.91 -412.56 4381.72 95.38 5566.99 5511.09 -419.42 4454.55 95.38 5635.17 5579.27 -426.28 4527.38 95.38 5703.35 5647.45 -433.13 4600.22 95.38 5771.53 5715.63 -439.99 4673.05 95.38 5839.71 5783.81 -446.85 4745.88 95.38 5895.90 5840.00 -452.50 4805.90 95.38 5907.89 5851.99 -453.71 4818.71 95.38 5976.07 5920.17 -460.56 4891.54 95.38 6044.25 5988.35 -467.42 4964.37 95.38 6112.43 6056.53 -474.28 5037.20 95.38 6163.90 6108.00 -479.46 5092.18 95.38 6180.61 6124.71 -481.14 5110.03 95.38 6248.79 6192.89 -487.99 5182.86 95.38 6316.97 6261.07 -494.85 5255.70 95.38 6385.15 6329.25 -501.71 5328.53 95.38 6453.33 6397.43 -508.57 5401.36 95.38 6521.51 6465.61 -515.42 5474.19 95.38 6589.70 6533.80 -522.28 5547.02 95.38 6655.90 6600.00 -528.94 5617.74 95.38 6657.88 6601.98 -529.14 5619.85 95.38 6726.06 6670.16 -536.00 5692.68 95.38 6790.90 6735.00 -542.52 5761.95 95.38 6794.24 6738.34 -542.85 5765.51 MapN MapE DLS VS G ft ft deg/100it' ft 5957236 .21 380733 .59 0.00 2594. 38 K-3 5957230 .60 380784 .32 0.00 2645. 42 5957222 .57 380857 .02 0.00 2718. 58 5957214 .53 380929 .73 0.00 2791. 73 5957211 .34 380958 .59 0.00 2820. 77 Basal K-3 5957207 .33 380994 .85 0.00 2857. 25 K-2 5957206 .49 381002 .43 0.00 2864. 88 5957198 .46 381075 .14 0.00 2938. 04 5957194 .96 381106 .81 0.00 2969. 91 Base K-2 5957190 .42 381147 .84 0.00 3011. 19 5957182 .39 381220 .55 0.00 3084. 34 5957174 .35 381293 .25 0.00 3157. 50 5957166 .31 381365 .95 0.00 3230. 65 5957158 .28 381438 .66 0.00 3303. 80 5957150 .24 381511 .36 0.00 3376. 96 5957142 .20 381584 .07 0.00 3450. 11 5957134 .17 381656 .77 0.00 3523. 26 5957126 .13 381729 .48 0.00 3596. 42 5957118 .09 381802 .18 0.00 3669. 57 5957110 .06 381874 .89 0.00 3742. 72 5957102 .02 381947 .59 0.00 3815. 88 5957093 .99 382020 .29 0.00 3889. 03 5957085 .95 382093 .00 0.00 3962. 18 5957077 .91 382165 .70 0.00 4035. 33 5957069 .88 382238 .41 0.00 4108. 49 5957061 .84 382311 .11 0.00 4181. 64 5957053. 80 382383 .82 0.00 4254. 79 5957045 .77 382456 .52 0.00 4327. 95 5957037. 73 382529 .23 0.00 4401. 10 5957029. 69 382601 .93 0.00 4474. 25 5957021. 66 382674 .63 0.00 4547. 41 5957013. 62 382747 .34 0.00 4620. 56 5957005. 59 382820 .04 0.00 4693. 71 5956997. 55 382892 .75 0.00 4766. 87 5956990. 93 382952 .67 0.00 4827. 16 Albian 97 5956989. 51 382965 .45 0.00 4840. 02 5956981. 48 383038 .16 0.00 4913. 17 5956973. 44 383110 .86 0.00 4986. 33 5956965. 40 383183 .57 0.00 5059. 48 5956959. 34 383238 .45 0.00 5114. 70 Albian 96 ( 5956957. 37 383256 .27 0.00 5132. 63 5956949. 33 383328 .97 0.00 5205. 79 5956941. 29 383401 .68 0.00 5278. 94 5956933. 26 383474 .38 0.00 5352. 09 5956925. 22 383547 .09 0.00 5425. 25 5956917. 19 383619 .79 0.00 5498. 40 5956909. 15 383692 .50 0.00 5571. 55 5956901. 35 383763 .09 0.00 5642. 59 Top HRZ 5956901. 11 383765 .20 0.00 5644. 71 5956893. 08 383837 .90 0.00 5717. 86 5956885. 43 383907 .05 0.00 5787. 43 Base HRZ 5956885. 04 383910 .61 0.00 5791. 01 -~~~~~~~~~~ ~ ~.~ y ~onocoPhilli s Alaska In• P ~ CPAI Report Company: ConocoPhillips Aiaska InC. Date: 4/13/2007 Time: 15:11:44 Page: 4 Ftield: COIviIIe RiverUnlt Caordinate(NE) Reference: Well: Plan: CD4=3fl2, True North Site: Afpine CD4 Vertical (TVD) Reference: P~an: CD4-302 ~a.9` We1L• Plan: CD4-302 Section (VS) Reference: Well (O.OON,O.OOE,95.38Azi) Welipath: Plan: CD4-302 Survey Calculation Met6od: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme ft deg deg ft ft ft ft ft ft deg/1DOft ft 9290.44 47.02 95.38 6855.90 6800.00 -549.06 5831.38 5956877.77 383976.36 0.00 5857.17 K-1 9300.00 47.02 95.38 6862.42 6806.52 -549.71 5838.35 5956877.00 383983.31 0.00 5864.17 9350.57 47.02 95.38 6896.90 6841.00 -553.18 5875.18 5956872.94 384020.08 0.00 5901.16 Kuparuk D 9400.00 47.02 95.38 6930.60 6874.70 -556.57 5911.18 5956868.97 384056.02 0.00 5937.32 9404.84 47.02 95.38 6933.90 6878.00 -556.90 5914.70 5956868.58 384059.54 0.00 5940.86 Kuparuk C 9436.97 47.02 95.38 6955.80 6899.90 -559.10 5938.10 5956866.00 384082.89 0.00 5964.36 9437.11 47.02 95.38 6955.90 6900.00 -559.11 5938.20 5956865.98 384083.00 3.50 5964.47 CD4-302wp02 T 9451.78 47.02 95.38 6965.90 6910.00 -560.12 5948.89 5956864.81 384093.66 0.00 5975.20 9500.00 47.02 95.38 6998.78 6942.88 -563.43 5984.01 5956860.93 384128.73 0.00 6010.48 9505.00 ~ 47.02 95.38 7002.18 -6946.28 -563.77 5987.65 5956860.53 384132.36 0.00 6014.14 7" Targets Map Map <---- Latitude ----> <-_ Longitude --> Name Descripfion TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Mia Sec Dip. Dir. ft ft ft ft ft CD4-302wp02 T1 6955.90 -559.11 5938.20 5956865.98 384083.00 70 17 27.393 N 150 56 18.291 W -Plan hit target Annotation MD TVD ft ft 400.00 400.00 KOP; 2.5 DLS, 0 TFO 2280.60 2076.55 Sail; 47° for 7156' 2755.00 2400.00 Surt csg; 2400' TVD 9437.11 6955.90 T1; 6955 ND 9505.00 7002.18 TD; 9505' MD Casing Points MD TVD Diameter Hole Size Name ' ft ft in in 2755.00 2400.00 9.625 12.250 9 5/8" 9505.00 7002.18 7.000 8.750 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 2760.72 2403.90 C-30 0.00 0.00 3318.07 2783.90 C-20 0.00 0.00 4830.23 3814.90 K-3 0.00 0.00 5139.70 4025.90 Basal K-3 0.00 0.00 5189.57 4059.90 K-2 0.00 0.00 5343.57 4164.90 Base K-2 0.00 0.00 7882.42 5895.90 Albian 97 0.00 0.00 8275.49 6163.90 Albian 96 (Nanuq) 0.00 0.00 8997.10 6655.90 Top HRZ 0.00 0.00 9195.11 6790.90 Base HRZ 0.00 0.00 9290.44 6855.90 K-1 0.00 0.00 9350.57 6896.90 Kuparuk D 0.00 0.00 9404.84 6933.90 Kuparuk C 0.00 0.00 ~ ~ ~!-~/f~ ~,~ ~ ti:,..: ~. . ~-w~ a ~. 5 t~ ~ .,.. ~onocoPhilli s Alaska In~ P ~ Anticollision Report Company: ConoCOPhillips Alaska Inc. Date: 4l13/2007 Time: 15:25:32 Page:, 1 Field: Colvilie River Unit Reference Site: Alpine CD4 Co-ordinate(NE) Reference: -~1VelI: Plan: CD4-302, True North Reference WeIL• Plan: CD4-302 Vertical (TVD) Reference: Plan: CD4-302 55.9 Reference Wellpath: Plan: CD4-302 Db: OraGe GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-302wp02 & NOT PLANNED P Interpolation Method: MD IntervaL• 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 9505.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1146.87 ft Error Surface: Ellipse + Casing Casing Points NID TVD Diameter Hole Size Name ft ft in in 2755.00 2400.00 9.625 12.250 9 5/8" 9505.00 7002.18 7.000 8.750 7" Plan: CD4-302wp02 Date Composed: 3/6/2007 slant well Version: 2 Principal: Yes Tied-to: From Well Ref. Point Summary ~--------------------- Offset Wellpath -------°----------> Site Well Wellpath Alpine CD4 CD4-208 CD4-208 V7 Alpine CD4 CD4-208 CD4-208PB1 V6 Alpine CD4 CD4-209 CD4-209 V4 Alpine CD4 CD4-210 CD4-210 V3 Alpine CD4 CD4-211 CD4-211 V2 Alpine CD4 CD4-213 CD4-213 V4 Alpine CD4 CD4-214 CD4-214 V3 Alpine CD4 Nanuq 5 Nanuq 5 V1 Alpine CD4 Nanuq 5 Plan: CD4-212 V0 Plan: Alpine CD4 Plan: CD4-203 Plan: CD4-203 V1 Plan: Alpine CD4 Plan: CD4-204 Plan: C04-204 V1 Plan: Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: Alpine CD4 Plan: CD4-207 Plan: CD4-207 V3 Plan: Alpine CD4 Plan: CD4-302 Prelim: CD4-302ST1 V3 Alpine CD4 Slot 1 open for futu Slot 1 open for future Reference NID ft 400.70 400.70 399.46 440.97 469.17 399.15 298.97 472.36 472.36 549.56 572.50 449.57 400.71 447.93 7200.00 36.90 Offset Ctr-Ctr No-Go MD Distance Area ft ft ft 400.00 120.99 7.32 400.00 120.99 7.21 400.00 144.36 7.87 425.00 160.61 8.17 475.00 180.95 9.11 400.00 218.81 7.82 300.00 241.25 6.08 475.00 194.96 7.85 475.00 194.96 7.85 550.00 20.37 10.35 575.00 33.57 11.40 450.00 60.35 9.36 400.00 80.99 8.49 450.00 100.35 9.34 7200.00 0.00 T 50.56 0.00 20.17 Allowable Deviation Warning ft 113.68 Pass: Major Risk 113.78 Pass: Major Risk 136.49 Pass: Major Risk 152.45 Pass: Major Risk 171.84 Pass: Major Risk 210.99 Pass: Major Risk 235.17 Pass: Major Risk 187.11 Pass: Major Risk 187.11 Pass: Major Risk 10.03 Pass: Major Risk 22.17 Pass: Major Risk 50.99 Pass: Major Risk 72.50 Pass: Major Risk 91.01 Pass: Major Risk -150.56 FAIL: Major Risk No Offset Stations ~ 4~ " i t ~~~~~~,~~~ AEfERENCEINiORMATION ~ CeorEinale (N/E) 0.elereMe: We1 CeMrc~. %an: C0430Z, Trve Norl~ Ve~kal (IVD) fteferer~ce: %an: G~b302 55.90 Section (VS) Relermce: Sbl- (O.OON O.OOE) Mea~weA Oepth Rekr<rice: Plan CDb302 55.90 Gkula~bnMMotl~. MinimumGUnaNre - _ - - _ _ - .~....a,.,,.... ,. Plan: CD4-204 (Plan: CD4 ~(Plan: (Plan: 11 (CD~4-211 l3 50 COMPANYDETALLS ConocoPhilhps Alaskalnc. F.nemeenn¢ Culculation Me~hod Mi~wnum Curva~ure eROrsrri~. ~scwsa ScanMelhod. Tn~C~'IindcrNorlh ErtorSurlace~ Lliipliwl+Casing WamingMcthod Rulc.[~a.d ,` '~~~ ANTI-COLLISION SETTINGS Interpolation Method:MD Interval: 25.00 Depth Range From: 36.30 To: 9505.00 Maximum Range: 1146.87 Reference: Plan: CD4-302wp0: From Colour To N1D 36 250 25U 5~~ 500 750 750 ~~-~- 1000 1~~~ ~25~ 1250 1500 204) 0 1500 1750 1750 2000 2000 \ 2500 2500 3000 ~~ ~ 3000 3500 S 3500 4000 ~- 000 4500 - ~l. 0 5000 ~ _S00 6000 6000 ~ 7000 Q000 8000 8 00 9000 ~90 0 ~ 10000 ~ • , ~0 12000 ~ /~ `.1200 14000 ~% :~-~-' 14000 =~;, a ~ 16Q ° ° ;~ ; t6000 18U 180001 20U i 25C ~ ~'. ~ % Plan: C~)~4-2 ( - ,o Plan: ( 0 0 0 Cylinder Azimuth (TFO+AZI) ~deg~ vs Cenire to Cenire Separation ~100fUin~ Plan: SORVEI'PROGR~M11 pth Fm Depth To Survey/Plan Tool 3.30 1000.00 Planned: CD3-302wp02 V2 C&GYRO-SS 1 0.00 9505.00 Planned: CD4302wp02 V2 MWD+IFR-AK-CAZ-SC <r.cr~o~ ur: rnn s se~ na~ m< n~~ rw +Ni-s +ti-w~ ~~~~ ~ra~e vs« ~rar~~i I 36.30 0 00 0 nU z aoa oo n nn o no 3 328U.G0 47~)2 JSiN a ~aar, e~ a~oz es ~x 5 9a37.11 J7. )2 95 iR 5 )A51 7k 47U2 95 iN ~ 95050i1 J70' 951R 3630 ano 00 2V /6 55 r,~o an 6')S~ vl1 G')G~.`)fl 711~? I N 0 00 0 00 ; R 36 _ ~,~, -' 9 11 -~uiz SGi77 000 0~ a~ ~~~ oou on~ oi~n oiro 72fi.M 2 50 0 f10 729 25 c93s.m o00 ow s~>aaia 5~i~xza iso 9~i sva~4~ cu4-3nzwpnzii s~~ax.xo ouu o~w snszo 598"lI5 Of10 0110 GOIaIJ 0 Travelling Cylinder Azimuth (TFO+pZ1) [deg] vs Centre to Centre Separation [20R/in] • "ro ] 250 ~00 750 l00 l25 l50 175 1 ~ ~ 1 I ~ I I I I I I ,, C D4-208 CD4- 208 ' 4000 CD 4-208 CD4-20 8PB 1 , , , I ~ CD4-210 ~ CD4-210 I ~ , ,, I I I ,, I ~ 2000 I ~ ~ I i , I ~ ~ ' , ~ I ~ , ~ , 0 ~ ~ ' ~ ~ ' ' ~ ' , ' CD4-302w 02 , ~ , I _ °o I I o u -2000 , , ,~-, , , ~ + C D4-213 CD4- 213 I ~ ,--. , I , I ~ I ~ I , ~ I ~ ..., ~ -4000 , ' o v~ , , , ' ~ I ' I , ' ..-~`.~ ,_ , I ~~ -6000 ~ . ~~ . ~ ~ ~ CD4- 2ll CD4-211 ' ~ , , I , , , , ' ' --- CD4-20 9 CD4-209 -8000 _~ Nanu 5 anu 5 , ' ~ CD4-214 C D4-214 -10000 ' -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 West(-)/East(+) [2000ft/in] Closest in POOL ~ Closest Approac h: Reference Well: CD4-302wp02 Plan Offset Well: Nanuq 5 Coords. - Coords. - ASP ASP 3-D ctr-ctr 'r Meas. Ind. Subsea N(+)/S(-) View VS Meas. Ind. Subsea N(+)/S(-) View VS Distance. Depth Angle TRUE Azi. TVD E(+~/W~-~ (95.38°) Comments Depth Angle TRUE Azi. ND E(+~/W~-~ (95.38°) Comments POOL Min Distance POOL Min Distance (8188.91 ft) in POOL (8188.91 ft) in POOL (6839 - 6945.71 ` (6839 - 6945.71 TVDss) to CD4- TVDss) to Nanuq 5 302wp02 Plan (6839 - 8188.91 838~.':> ~ ~. 9?_292 9350 47.02 95.38 6840.042 5956873 384020.8 5901.378 (6839 - 6950 T1/Dss) 11282 57.21 161.22 6832.25 5949504 380447.4 3347.51 6950 TVDss) ~ ~ ~«~9 J +n~...nr~ ~- .r~ ^~ ~ ~ CD4-302wp02 POOLSummary.xls 4/13/2007 4:00 PM • ~ CD4-302wn02 Surface Location: E Fiom: _,. __ __~:__ ~~ _.~. _ ~ ~~ ~_ Ta _: _ _ _ _ __~ _.~_ _ _ .._~ I , Dakum: NAD27 .~ R~9~n: alaska . DatWm: ~qD27~ . ~ Regian. alaska .~ ~ - ~~ ~ ~ ~~ ~ f ~`' L~kitudell.ongitud~ pecimal Degrees ~ ~~` Lakitudelk,angikuds . pecimal ~egrees ~~ i ~~ ~ ~~ ~ , ~ f UTM Zone: r S~th t~~" UTM Zone: True ~` South ~ ~ • ~ ; , ~ t~' Skate Pfane Zr~e: 4 ~ Urrits: us•ft . ~ ~"' State Plarie Zorie: 4 ~ Units: us-fk . j ~ i ` I ~ ~"" ~_~~~Csn~cr~~ti:~°~x#u~.i~~~'~~~~~ ! ~ t~ Legal~escripkian(ht,4D27on~}~ ~ ~ ~~ ~ . ' . ~ i ~ . ~ ~ . k~afartit7g Co~nrdinates:- ----------- ~ Leg~ Qescription i ~: 378155.13 ' ~ ~ ~ ~ ~ ~ ~ fiownship:' 011 N. Range: 004 E. ~'= 5957521.22 I ~ ~ ~ I ~ Meridian: ~ ~ Sectiarr: ~q L_ _~ _ _ _ .__.°_ __ ' ~ ~ ~ FNL ~ 2887.76d7 FEL ~ 89.591351 ; % I ~ ' ~..~,~ .~_ ___ _ I' CD4-302wb02 Tar~et 1: :-~~a~,~ ~ ~ ~ ~___. ~ ~~~+m: NA~27 . ~'~9~~: alaska • ; ~'"' L~titudeltangitude pecimal Degrees ~~~ ' ~'"° UTM Zorie: ~ ~" ~outh !~ Skake Plane Zpr~e: 4 ~ Elnita: us-ft + r i 3~ L .'"'iu~ i,~C~ s~~. ,t .,1 ~, #. ,i Fs~f ~~ ;C~~~~ . . . ~ I .-~ . ~~.~ ' ~`.. .-.- ~- r o: ~..~. ~ ~ , ~ ; Datu[n: NAD27 ~ ~~9~~: alaska T j ~ 1 ~~;~~ € ~ tlr` LaGitudelLQngitude Decimal Degrees ~ ' ' i 3'" IJTM Zorre: True 9" South ~ ~ ~'' State Plane Zone: 4 * Units: us-ft . I I ' C: Legal DescripGan ~NAC~2~ ar~lyj ~ y ua~an~y..,~va.r~uu~.c~. . ... .. { ~ s ~8 : 6SCFI~IOt'i ; : - E ~ ~ ~~ 384083.00 I ~~ ~ Tvwnshi~, Oll ~~ N ,r ~~9e~ 005 E ~+ ~ ~. ~~ ~ , Y: 5956866.00 ? ; ~~ hqeridian: ~ ~ ~ ~ 5eetian: ~p ~ '~~ a I. ~ ~~~~ ~ i FNL .:~ 3d49.2Q46 ~ FEL . ~A395.5831 ~ ~~ € i _~_._u__~~__._.~~ ~.~._ ~~ ~ ~ ~~°'' ~~~~7~~q:~ ~ ~ i 1 ~ ~«.~ ~ ~ ~~ a'~ ~i ~ ~ CD4-302wv02 Toe: ~ _. __. _fiw. _..~._ _~.t__. ~_, ~ ~rom: _~~___ _ _ v _____ _._~ _. ~.. # a Ta: ~ __ ._.. . _._ __ . _._..~. : _ ~ ~.. _ ~ Qatum; NAD27~ •. Fiegion: alaska ~T ~ i Datum; NAp27 .~ R~gion: alaska •r ~~ i ~ ` Lakikude,~L ' ~~ t"` LakitutlelLa ~ £ cw~gitude pecimal Degrees . i' ngitude ' pecimal Degrees ~. ~ ~ . , .W ~ ~ , ; , = t` UTM Z~ne: ~"-` ~ South ~ i t"` UTM ~ane:', True Tr South ~ i ~ , 1 _ ~ i~ j i+ Stake Plane ~or~: 4 ~ ~, Urri~s: us-ft ~~ ~ ; ~' Stafe Plane ~one: 4 .~ #Jniks: us-ft . ~ ~ ! ~ ~ ; ~ ~~ ` ~ ' ~"` E~~ i~ ,,.r,~,r,' ~ " ; ~,~,E:F= ~~ ~ {~' LegalDescrq~tion{Iy~D2~fmly~ ~ ' s a~; ~ 3_ ~w ~ ~tarfingi~notdinatss: -----s ; Legal Description ~~ , ---~-- { £ , ; ~ 384132.36 ~ . ¢ ~ ; ~ ~ovanship; 011 N .• ~a~~ 005 E ~ ? € ,. ~ ~ ~~ I ~ ; ~ Y: ~5956560.53 ; t~leridi~: u ~ Sectiore 20 ~ f+ V..~ ~ ~ ~ ~ Z . ~ FNL + 3453.9233 FEL . 4346.1570 j; ~ !.._.~.__ .~~ ' ~~~ ~~~~~ ~ ~ ~ • TRANSMIT~'AL LE~'1"ER CHECKLIST VVELL ~ANIE ~ ~ ~-~~ ~,. PTD# ~_-.~-%'~-- !~~ ~ Developmeat ~Service Eatptvcatory• Stratigrap6ic ~'est YoQ-Conventional Welt Circte 4ppropriate Letter / Paragraphs to be Included in Transmittal Letter ~ CffECK i ADD-OAIS ' TEXT FOR APPROVAL LETTER ; WE1AT ~ (OPTIONS) ! ~ , APPLIES ~ ~ ; ( MLiLTI LATEfZAL ~ ~ The perrnit is for a new wepbore segment of existing ~ ; well ~(If last two digits in I Pe~it No. , AP[ No. ~0- ~ AP[ number are ; ' - ; between 60-69) ~ Production ~houtd continue to be reported as a function of the ~ ~ ~ ortginal 4PI number stated above. ; i PILOT EfOGE i[n accordance with 20 A.AC 25.00~(~, a!I records, data and lo~s ; j ~ acquited for the pilot hole must be c[early differantiated in both ~ ~ ; weil name ( PI~ and API number ~ ; ~ I'(~~- - -_} from records, data and logs ~ f acquired for we(1 ' . ~ SPACING The permit is approved subject to full complianca with 20 AAC ! EXCEPTION ~ 2~.0~~. Approval to pecforate and praduce / inj;~ct is contingent I ~ ~ I upon issuance of a conservarioa ocder approving a spacing j I exception ' ~ . assumes the i liability of any protest to the spacing exception that may occur. ( ~ DRY DCI'CH f A![ dry ditch samp(e sets subrrtitted to tt~e-Eommission must be in , i SA!~rIPLE I no greatcr than 30' sample intervals from below che pecma&ost or ;' ~ I from where samples are frst caught and 10' samp(e intervals ; ~ ~ through target zones. ; ~ 1 j Non-Conventionai ~ Please note the following, specia! condition of this permit: ~ ~ Pr~uctioa or productioa testing of coa( bed methane is not allowed i i~~« ~ Poc Lname of wetlZ until after Corn N e has designed and ! i ~ imp(emented a water wel[ testing program to provide baseline data ~ ; on water qua;lity and quantity. (Compa.nv Name must contact the I I ~ Commission to obtain advance approval of such water we(i testing ; c ~ P osxram I Rev: ( ~2jr06 C:' jody~[ransrreittal_checklist ~~~ . ,,, , ,r . ._. ~~ ~„>>> r ~~ r „~~ ',' ' . . _ ~ ~ ~ Field & Pool _COLVILIE RIVER, NANUQ-KUPK OIL • 120185 Well Name: COLVILLE RIV NAN-K CD4-302 __ Program SER __~ Weli bore seg ^ PTD#:2070560 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER / WAGIN__GeoArea 890 Unit 50360 OnlOff Shore On Annular Disposai ^ Administration 1 Permitfee attached. - - - Yes - - - 2 Leasenumberapproqriate________ _____________ Yes. _.______________.. 3 Unique well_ name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ $urf_ace locatior~ in AD 380077; top produc#ive.interyal & TD in ADL 384211... _ . . . _ _ . . _ -- - -- 4 Well located in_a_defined_pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _ Colyille_River Field, Colville River Unit, Nanug-Kuparuk Oil Pool, govemed by Con_servation Order No. 563., _ _ _ , 5 Well located p[oper distance from drilling unit_bounda_ry_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ . . . ConsQrvation Order No. 563 9on#ains n9 spacing restrictions with [eSpectto dcilling unit boundaries. _ , _ _ _ _ _ _ _ 6 Well Iqcated proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conseryation Orde[ No. 563 has_no interwell_spacing rest[ictions, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . . . _ . _ . . . 7 Sufficient acreage ayailable in_drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ _ . _ , _ Conseryation OCder No. 563 has_no interwell_s acin rest[ictions, Wellbore,will be_more than 500' from _ - ~ g 8 if deyiated, is_wellbore plat.included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . . _ _ _ _ . e~ernal pr_operty line whe[e_ owne[ship o[ landownership_ changes._ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 9 Operatot only aff_ected party - - - Yes I 10 _ Operatothas.appropriatebondinforqe ____ --- - - --~ Yes_ ..._____ _..__ _.__. ____ ____ _____ __________ - ---- - -- i 11 Permitcanbeissuedwithoutconservationorder___._ _____ _ Yes_ _____ _____ ________________...__ ___..__,. - Appr Date 12 Permit_canbeissued_w_ithoutadminist[ative_approyal____________________ ___ Yes_ __.__.,___________..____________ SFD 413012007 ~3 Can permit be approved before 15-daywait Yes I 14 Well located within area and_strata a~thprizQd by Injection Orde[ #(put 10# in.comments~ (For Ye~ _ __.___ Colville_River Field, Golville Rive[ Unit, Nanuq,Kuparuk Oil Pool, gQVemed by A[ea Injeckion_Order 27 ___ ____ I 15 All wells_within_114_mile area_of [eyiew identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ None_ _ _ _ _ _ _ _ _ _ _ _ _ - -- --~ -- - -- -- -- . - ---- -- -- 16 Pre-produced injector; dur_a#ion_of pr_e-production less than 3 months (For service well only) _ _ No_ _ _ _ _ _ . _ Well will be flowed back fqr limited_time_for_clean-up_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 Nonconven,gasconfor_mstoAS31,05,030(~.1_.A),(~.2.A-Dj---_--------- NA-- ------ -- ---_----_---.-------------_-.-.----_----- --------_.--- --- Engineering 18 Conduclor~tring_p_rovided---------------------- Yes- ----- -- ---------.--------------- - ----------------- ------ --.--- 19 Surface caging protects all_known USDWS _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ N_A_ _ _ _ _ . _ _ No aquifers,_per A10_18A conclu~ion 3._ _ , _ . _ _ _ - - 20 CMT_v_ol atleguate.to ci[culate.on conductor & surf_csg _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . 21 CMT_vol atleguate_to tie-in long string to su _rf csg _ . _ _ _ _ _ _ _ NA_ _ _ _ _ _ . _ All hydrocarbons will be cov_ered, Annular disposal_may be propos_ed__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2Z CMT_will coyer_all known_productiye horizon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _ _ _ _ 23 CasingdesignsadequateforC,T,6&_permaf[o5t--------- -_------ Yes- -_------ ------------------------ --- --- ------------------------------- 24 Adequate.tan_kage_or reserye pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ . _ Rig is equipped with steel_pits. _ No reserve_pitplanned, All waste to_approved annulus_or disposal well(s), _ _ _ _ _ ~ 25 If a_ re-drill, has a 1_0-403 for abandonmenl been approved _ _ _ _ . _ . _ NA_ _ _ _ _ _ _ _ _ _ _ 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ . Proximity analysis performed, Trayeling cylinder path calculated, Gyros possible in surface hole, _ _ _ _ _ _ _ _ _ _ 27 If_dive[ter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ . _ _ _ _ _ Diyerter waiver [equesled, No histo_ry_of problems in_12 welis. Approval recommended, 20 AAC 25;035(h){2). . _ Appr Date 28 Drilling fluid_ program schematic_& equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ , , _ _ _ Maximum expsCt~d fo[mation pressu[e 8.7_ EMW._ PI_anned MW up to.9.8 ppg, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ TEM 5/2/2007 29 BOPEs,dotheymeetregulation------__--.--- . Yes- ---- ---------------- --------------- ,-_-_ ..--- 30 BO_PE_presS rating appropriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ _ _ _ MA$P calculated_at 2468 psi, 3500_psi.appropriafe. _CPA_I usually_tests to 5000. psi. _ _ _ _ _ _ _ _ _ _ _ ~ 31 Choke_manifoldcomplieswlAPl_RP-53(May84)--------------------- --- -- Yes- -----------------------------. ------------- -----.,------ ---.-- 32 Work will occ_uC without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ . _ 33 IspresenceofH2Sgas.prpbable._ ______________ ________________ No_. ______H2Shasnotbeen[eportedatGD4.__________.__ 34 Mechanical_condition of wells within AOR venfied (For service well only) _ _ _ . _ _ Yes _ _ _ _ _ _ . No wells ptoxim_ate_in zone__ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Permitcan be issued w/o hydrogen_sulfide measu[es_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ H2S not enco~ntered in offset well_s, However, Cig will be equipped with_operational_sensors. _ _ _ _ 36 Data.presented on potential oyerpressuCe zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ . _ _ Expected reservoir_pre_ssure is 8,7_ppg EMW; will be drilled with 9.6-9,8.ppg mud._ . _ _ _ _ _ _ _ _ _ _ Appr Date 37 Seismic analysis of shallQw gas.zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ . _ _ _ _ _ Multiple w~lis drilled from this pad._ Hydrates or shallow gas are_ unlikely; mitigation measures discussed, _ _ _ _ _ SFD 4130/2007 38 Seabed condition suryey_(if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ - 39 Contact namelphone for weekly_progtess repo[ts [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ . _ _ _ _ . _ Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ~~~~ s -3-a ~ ~ ~ ~I Well History File APPENDIX InioRnation of detailed nature that is not ~ pa~ticula~iy germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulaled at the end of the file under APPENDIX. No special efiforl has been made to chronologically organize this category of information. , • • cd4-302.txt Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Fri Dec 28 15:56:04 2007 Reel Header Service name .............LISTPE Date . ...................07/12/28 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation ~umber......01 Previous Reel Name.......UNKNOWN Comments .................STS ~IS writing ~ibrary. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/12/28 Origin ...................sTs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS ~I5 writing ~ibrary. scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 Mw-000503086 E. QUAM D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD CD4-302 501032054500 ConocoPhillips ,4laska Inc. Sperry Sun 28-DEC-07 24 11N 4E 2887 89 .00 56.10 19.60 Page 1 UZ C~b'~- -pS~ ~ t S`~ 3~ • , 15T STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: cd4-302.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 2763.0 l. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (ND). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1,2 REPRESENT WELL CD4-302 WITH API#: 50-103-20545-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9626~MD/7103'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (L.OW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: Page 2 ~ . cd4-302.txt HOLE SIZE: ACAL-DERIVED (8.75~~ BIT) MUD WEIGHT: 9.65 - 9.85 PPG MUD SALINITY: 350 - 800 PPM CHLORIDES FORMATION WATER SALINITY: 23000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curv es; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2737.0 9589.5 PEF 2753.0 9544.0 DRHO 2758.0 9544.0 RHOB 2758.0 9544.0 NCNT 2758.0 9530.5 FCNT 2758.0 9530.5 NPHI 2758.0 9530.5 RPD 2758.0 9582.0 RPM 2758.0 9582.0 RP5 2758.0 9582.0 RPx 2758.0 9582.0 FET 2763.0 9582.0 ROP 2773.5 9626.0 $ # 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 wD 2 2737.0 9626.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Page 3 • ~ cd4-302.txt Absent value .... ..................-999.25 Depth Units. . .. .. ..... Datum specificat ion Block sub-type...0 Name serv ice order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 $ 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-5 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Serv ice Unit Min Max Mean Nsam Reading Reading DEPT FT 2737 9626 6181.5 13779 2737 9626 ROP MwD FT/H 0 481.24 192.013 13706 2773.5 9626 GR MwD API 50.8 465.61 125.817 13706 2737 9589.5 RPx MwD OHMM 0.62 1207.66 5.55081 13649 2758 9582 RPS MwD OHMM 0.45 2000 5.74269 13649 2758 9582 RPM MwD OHMM 0.34 2000 5.75722 13649 2758 9582 RPD MwD OHMM 0.3 2000 7.01082 13649 2758 9582 FET Mw~ HOUR 0.14 62.75 0.65085 13639 2763 9582 NPHI MwD Pu-S 16.14 54.01 31.5341 13546 2758 9530.5 FCNT MWD CNTS 492.9 2113.8 967.716 13546 2758 9530.5 NCNT MWD CNTS 97363.4 157241 124177 13546 2758 9530.5 RHOB MwD G/CM 0.017 3.244 2.41985 13573 2758 9544 DRHO MWD G/CM -2.911 0.31 0.0531138 13573 2758 9544 PEF MwD BARN 1.9 13.99 3.20657 13583 2753 9544 First Reading For Entire File..........2737 ~ast Reading For Entire File...........9626 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/28 Maximum Physical Record..65535 File TyL~ e ................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.......07/12/28 Maximum Physical Record..65535 Page 4 • • cd4-302.txt File Type. ............LO Previous File Name.......STSLIB.0 01 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for ea ch bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2737.0 9589.5 PEF 2753.0 9544.0 DRHO 2758.0 9544.0 RHOB 2758.0 9544.0 NCNT 2758.0 9530.5 FCNT 2758.0 9530.5 NPHI 2758.0 9530.5 RPD 2758.0 9582.0 RPM 2758.0 9582.0 RPS 2758.0 9582.0 RPx 2758.0 9582.0 FET 2763.0 9582.0 ROP 2773.5 9626.0 $ # LOG HEADER DATA DATE LOGGED: 12-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9626.0 TOP LOG INTERVAL (FT): 2737.0 BOTTOM LOG INTERVAL (FT): 9626.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.8 MAXIMUM ANGLE: 48.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 10505932 CTN COMP THERMAL NEUTRON 185457 ALD AZIMUTHAL LITHO-DEN 222954 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2763.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 35.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.300 72.0 Page 5 ~ • cd4-302.txt MUD AT MAX CIRCULATING TERMPERATURE: .689 141.8 MUD FILTRATE AT MT: 1.200 72.0 MUD CAKE AT MT: 1.700 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # ~ata Format specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999.25 Depth Units. . .. .. ..... ~atum Specification alock sub-type...0 Name service order units size -vsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2737 9626 6181.5 13779 2737 9626 ROP MwD020 FT/H 0 481.24 192.013 13706 2773.5 9626 GR MWD020 API 50.8 465.61 125.817 13706 2737 9589.5 RPx MWD020 OHMM 0.62 1207.66 5.55081 13649 2758 9582 RPS MwD020 OHMM 0.45 2000 5.74269 13649 2758 9582 RPM Mw~020 OHMM 0.34 2000 5.75722 13649 2758 9582 RPD Mw~020 OHMM 0.3 2000 7.01082 13649 2758 9582 FET MwD020 HOUR 0.14 62.75 0.65085 13639 2763 9582 NPHI Mw~020 Pu-S 16.14 54.01 31.5341 13546 2758 9530.5 FCNT MWD020 CNTS 492.9 2113.8 967.716 13546 2758 9530.5 NCNT MWD020 CNTS 97363.4 157241 124177 13546 2758 9530.5 RHOB MWD020 G/CM 0.017 3.244 2.41985 13573 2758 9544 DRHO MWD020 G/CM -2.911 0.31 0.0531138 13573 2758 9544 PEF MwD020 BARN 1.9 13.99 3.20657 13583 2753 9544 Page 6 . . ~ cd4-302.txt First Reading For Entire File..........2737 ~ast Reading For Entire File...........9626 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/28 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/12/28 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date . ...................07/12/28 Ori in ...................5T5 Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File • Scientific Technical services scientific Technical services Page 7