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207-101
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:10-426 form for CD4-pad SI non-witnessed MIT-IA 6-17-25 Date:Wednesday, June 18, 2025 8:25:00 AM Attachments:image001.png MIT CRU CD4 PAD SI TESTS 06-17-25.xlsx Morning, Please see the attached 10-426 form from the CD4-pad SI non-witnessed MIT-IA that was performed on 6-17-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061180 Type Inj N Tubing 1900 2265 2305 2310 Type Test P Packer TVD 7130 BBL Pump 3.2 IA 510 3300 3235 3230 Interval V Test psi 3000 BBL Return 3.2 OA 1 5 5 5 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2071010 Type Inj N Tubing 320 3280 3235 3225 Type Test P Packer TVD 7161 BBL Pump 7.2 IA 325 3300 3245 3240 Interval V Test psi 3000 BBL Return 7.2 OA 1 3 3 3 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD4 PAD Non-witnessed Van Camp 06/17/25 Notes:MITIA to maximum anticipated injection pressure per AIO 18C.003 AMENDED Notes: Notes: Notes: CD4-17 CD4-322 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 18C.005. LTSI: Tubing has open pocket, CMIT T x IA to 3000 psi to prove integrity. Notes: Notes: Form 10-426 (Revised 01/2017)2025-0617_MIT_CRU_CD4-322 9 9 9 9 9 9 99 999 99 9 9 9 -5HJJ CD4-322 AIO 18C.005 LTSI: CMIT T x IA to 3000 psi 1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Tuesday, June 13, 2023 7:37 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Integrity Subject:CPAI 10-426 form for Non-witnessed shut in tests on CD4-213, 306, 322 and 594 on 6/13/23 Attachments:MIT CRU CD4-213,306,322 & 594 SI TESTS 06-13-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA’s that were performed at CD4 pad on 6/13/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CRU CD4-322PTD 2071010 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2120050 Type Inj N Tubing 3 330 320 315 Type Test P Packer TVD 7291 BBL Pump 3.8 IA 3 3320 3260 3245 Interval 4 Test psi 1823 BBL Return 3.8 OA 89 98 98 98 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2070940 Type Inj N Tubing 295 400 410 405 Type Test P Packer TVD 6898 BBL Pump 2.7 IA 90 3300 3200 3180 Interval 4 Test psi 1725 BBL Return 2.7 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2071010 Type Inj N Tubing 280 575 605 605 Type Test P Packer TVD 7161 BBL Pump 4.5 IA 295 3300 3260 3255 Interval V Test psi 3000 BBL Return 4.4 OA 42 68 68 68 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2191150 Type Inj N Tubing 300 335 305 300 Type Test P Packer TVD 4007 BBL Pump 3.6 IA 365 2020 1950 1930 Interval 4 Test psi 1500 BBL Return 3.5 OA 291 314 314 313 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD4 PAD Miller 06/13/23 Notes:Tubing plug set at 11,931' MD. Notes: CD4-213B CD4-306 CD4-594 Notes: CD4-322 Notes:MITIA to maximum anticipated injection pressure per AIO 18C.005 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2023-0613_MIT_CRU_CD4-pad_4wells jbr • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: 71m Regg 6 21 DATE: Monday,June 19,2017 P.I.Supervisor Q1-14 ' ' 7 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-322 FROM: Bob Noble COLVILLE RIV NAN-K CD4-322 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-322 API Well Number 50-103-20551-00-00 Inspector Name: Bob Noble Permit Number: 207-101-0 Inspection Date: 6/9/2017 Insp Num: mitRCN170612074349 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-322 Type Inj N ✓ TVD 7161 - Tubing 1000 1090 - 1000 _ 1000 - PTD 2071010 Type Test SPT Test psi 3000 IA 450 3300 - 3280 _ 3280 - BBL Pumped: 4.3 - BBL Returned: 4.3 - OA 32 54 54 54 Interval REQVAR P/F P Notes: MITIA per AIO 18C.005 to max anticapated injection pressure of 3000' SCANNED AUG 2 22017, Monday,June 19,2017 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, June 25, 2015 3:20 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Alpine WAG injector CD4-322 (PTD 207-101) Report of OA x Atmosphere communication Attachments: image001.png; CD4-322 wellbore.pdf; CD4-322 90 day TIO 6-25-15.JPG Chris, Alpine WAG injector CD4-322 (PTD 207-101) was discovered to have OA x Atmosphere communication today. The well has been shut in since 8/20/14. CPAI intends to perform diagnostics to locate the leak point and determine potential repair options. Upon conclusion of the diagnostics a follow up email with the plan forward along with any required paperwork will be provided. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor 2Q� ConocoPhillips Alaska, Inc. SHED JUL 0 1 5 Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 44,WELLS TEAM ConocoPhitlips 1 u _ _ I 1 • o�c a N = w � � W UU v a O co) N W = Q. O � Q u u W m N t M r 17.N W o 0 v_ N Q N N J M M v v ud c U U 0 0 0 0 0 o 0 r N 0 0 0 0 a a t ! 1 I 1 I 1 1 $ r Y. I C I/ 1 , T 7 O Ql R 70 V Q O Q U R N Cil � C Z C v. N sL ` O Cl 1/l (NA O O 1,.1 CV O N O 1T tr.)N N j in _ 0 0 0 0 0 0 0 Ili _ A A Vl O Li O V. O ^. U, a. 0 4 0 4 0 0 0 0 IL Z Q O V M /•'. fV i, N Q Odle war a ' pd s N D W MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,June 16,2015 P.I.Supervisor (1 (417115- '` 1 7 Its SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-322 FROM: Johnnie Hill COLVILLE RIV NAN-K CD4-322 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 7 _ NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-322 API Well Number 50-103-20551-00-00 Inspector Name: Johnnie Hill Permit Number: 207-101-0 Inspection Date: 6/12/2015 Insp Num: mitJWH150613214706 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-322 .—Type Inj N-TVD r 7161 - Tubing 150 150- 150 150 . PTD 2071010 Type Test SPT Test psi 1790 - IA 634 2511 - 2477 - 2469 • Interval 'WRIST — per, P V OA o 1 1. 1 - NOtes: 2.7bbls diesel , ---- i Ui SCA14413 Tuesday,June 16,2015 Page 1 of 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ Q L Well History File Identifier ~rganlZing (done) .,,.o.den iiiuiuiuuiiiiii ae=~~~eeaea iuumiAiimiii RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: DIG TAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~ - ~ - /s/ ~ Project Proofing II I II ~I II ((III I I III BY: Maria Date: ~ ~ D V /s/ Scanning Preparation __~ x 30 = a + _ r =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: f ~--- Q ' lsl `~ ~ ~ - - Production Scanning III II'lll IIII II III Stage 7 Page Count from- Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ' ~. ' ~J O ~ /s/ Stage 7 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 it II I (III IIIII ReScanned BY: Maria Dater /s/ Comments about this file: a , ~~ea iuiuuuiiimi 10/6/2005 Well History Fife 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 -101 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -322 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ 111 WDSPL ❑ 50 -103- 20551 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 312 -214 6/18/2012 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 ®� 20� fluids, formation fluids and SCANNED APR any necessary water added Previous 30447 0 385* 30832 ** 0 totals (bbls): 2012 /2nd 0 0 4.1* 4.1 0 2012 / 3rd 0 0 0 0 0 2012 /4th 0 0 0 0 0 2013 / 1st 2013 / 2nd • Total Ending Report is due on the 20th Volume 30447 0 389.1 30836.1 (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. 12. Remarks and Approved Substances Description(s): *injectivity test **previously previously reported volumes on another sundry (307 -293) I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: '. Date: f(/5 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 IN 6. Permit to Drill Number: 207 -101 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -322 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ El WDSPL ❑ 50 -103- 20551 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal 0 or Continuation ❑ or Final ❑ 312 -214 6/18/2012 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: III cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and � 1' 8 2°1a any necessary water s ', JUL. added Previous 30447 0 385* 30832 ** 0 totals (bbls): 2012/2nd 0 0 4.1* 4.1 0 2012 / 3rd 2012 / 4th 2013 /1st 2013 / 2nd Total Ending Report is due on the 20th Volume 30447 0 389.1 30836.1 (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. 12. Remarks and Approved Substances Description(s): *injectivity test * *previously reported volumes on another sundry (307 -293) I hereby certify that the foregoing is true and correct to the best of my knowledge. / Signature: A ,e.__ 0-4.._ Date: 7(6 (20 lZ Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265 -6120 Submit in Du plicate Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE p F } ` • • �� P r 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 Zi Re: Colville River Field, CD4 -322 Sundry Number: 312 -214 Dear Mr. Alvord: � NED JUN `� 9 ?01 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, , i ,... 4.14,3 ( Cathy ". Foerster Chair DATED this iv day of June, 2012 Encl. } , • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 June 7th, 2012 RECEIVED Alaska Oil and Gas Conservation Commission JUN 1 1 2012 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 -3539 AOGCC Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4 -322 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD4 -322 (sundry permit # 307- 293) 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 -322 is a strong candidate for increasing the allowable injection volume. r It is not possible to haul the drilling wastes to the Alpine disposal well at this time. Injection pressure has typically been significantly below our original surface casing shoe test pressure. CD4 -322 was last used for annular disposal on January 10` 2008 after injecting 30,832 bbls. Increasing the allowable disposal volume for CD4 -322 will allow for time to complete drilling CD4 -213B which encountered hole condition issue within 1200 ft of reaching TD. For further details please reference the original annular disposal permit for CD4 -322, approved on October 25th, 2007. Attached is an updated plot showing all the wells within quarter mile of the surface shoe on CD4 -322. All the information for these wells has previously been submitted to the AOGCC. Also attached is the updated annular disposal transmittal form. If you have any questions or require further information, please contact Scott Brunswick ( Scott. A. Brunswick(ciconocophillips.com) at 263 -4249; Chip Alvord can also be reached by calling 265 -6120. Sincerely, Scott Brunswick Drilling Engineer cc: CD4 -322 Well File Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 • `41 • ConocoPhillips Alaska, Inc. (D IPPV Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 12012 ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 AOGCC 1. Operator Name: 3. Permit to Drill No: 207 -101 Conocophillips Alaska 4. API Number: 50- 103 - 20551 -00 2. Address: 5. Well Name: CD4322 PO Box 100360, Anchorage, Alaska 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) Interval exposed to Torok & Seabee formation, Shale, Siltstone, a) All wells within one- open annulus: Sandstone quarter mile: CD4 -16, CD4 -17, CD4 -321, Nanuq3, CD4 -07 b) Waste receiving Sand layers below the C30 marker in the Seabe zone: Formation b) water wells within one mile: None c) Confinement: The schrader Bluff formation provides an uppe . barrier and marine shales and claystones of th Albian Torok formation provide lower barrier. 9. Depth to base of 10. Hydrocarbon zones permafrost: Approximately 1650' MD / 1600' TVD above waste receiving None zone: 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 30,832 bbls - 10/25/2007 . densities range from diesel to 12 ppg 2233 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: Types of waste may be drilling mud, drilling cuttings, reserve pit flu ids, (/{' 70,000 bbls (! V1rV1 v /g 1 / k • 7 L e * 1 , ��� cement contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate 16. Estimated start date: pumping of drilling cuttings, and other substances that the commisioner determines on application are wastes associated with the act of drilling 6/13/2012 a well permitted under20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) Q Cement Bond Log (if required) ❑ FIT Records w/ LOT Graph 0 ' Previous authprization for new product cleanup fluids for CD 1 and CD2 Surf. Casing Cementing Data 0 Other 0 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature : . £ � �( Title: Alaska Drilling Manager Printed Phone Col It (la f 2 Name: Chip Alvord Number: 265 -6120 Date: Commission Use Only Conditions of approval: LOT review and Co /-vl p )/ 4 hC t w07h ?c2 pprovaI: Subsequent form � �j Approval j L I required: G " 4-23 number: , 2, 1 Approved a APPROVED BY by: ( /I COMMISSIONER THE COMMISSION Date: /rllz ORI . v • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 Annulus Disposal Transmittal Form - Well CD4 -322 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD4 -322 2 The depth to the base of freshwater aquifers and permafrost, if There are no US DW 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 cl aystones of the Al bian 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. 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 CDI &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 2233 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 Previously submitted: cementing reports, LOT / FIT reports base of any freshwater aquifer and permafrost, if present, and 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 Previously submitted: 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 Upon request containment of drilling waste. • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) version 1.0 -tm'05 Well CD4 -322 Assumptions Date 6/6/2012 Maximum injection pressure of 900 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 or = Maximum Fluid Density to avoid Burst of Surface Casing Pburst85% = PHydrostatic + PApplied - PFormation 4,888 = ( 2,385 * 0.052 * MWmax ) + 900 - ( 0.4337 * 2,385 ) N MWmax = 40.5 ppg 2,385 TVD Surface Casing String Size 9.625 in Weight 40 ppf 44 . 44 Grade L 80 oc rburst100 %" 5,750 psi P burst85 /o o 4,888 psi Depth of Shoe 2,385 ft FIT /LOT @ Shoe 18 ppg or 2,233 psi FIT/LOT for Annulus 14.5 ppg Max Surf. Pressure 900 psi r TOC Est. @ 8,390' MD TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,599 = ( 3,961 * 0.052 * MWmax ) + 900 - ( 0.0700 * 3,961 ) - 1,000 Z Z MWmax = 24.2 ppg 4.5 "Tubing 2nd Casing String Size 7 in ,1 7,728 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 3,961 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 900 psi Header Press 1,000 psi Maximum Anticipated Pressure at Depth of Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,385 * .052 * 18 ) Pmax allowable = 2,233 psi This is the value for the Injection Pen "Maximum Anticipated Pressure at Shoe ". PRESSURE INTEGRITY TEST - CONOCOPHILLIPS Alaska, Inc. Well Name: CD4 -322 I Rig: _ittle Red Servic 'Date: 1 I Volume Input Pump Rate: Drilling Supervisor: 1 IPun vrsed: Other - See Comments ■ Barrels V 1.0000 Bbls /strk V 0.50 Bbl /min Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. V Casing Test Pressure Integrity Test Hole Size: 9 v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I "4 I Ft 3580.0lFt -MDI 2385.0IFt -TVD 1 8400 ' IFt -MD 1 IFt -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC " I 0 0 375 0.00 1050 Changes for Annular Adequacy Tes Pressure IntegrityTesl 1 1 900 0.25 1000 Enter outer casing shoe test results in comments Mud Weight: ppg 2 2 950 0.50 1000 Casing description references outer casing string Inner casing OD In. 3 3 975 1.00 990 • Hole Size is that drilled below outer casing. 4 4 1 L 1.50 990 Use estimated TOC for Hole Depth 5 5 1000 2.00 9P Enter inner casing OD at right. Desired PIT EMW: ppg 6 6 1000 2.50 98u Estimates for Test: 905 psi 1.2 bbls 7 7 1010 3.00 980 . 8 8 1025 3.50 975 EMW = Leak -off Pressure + Mud Weight = 900 + 7.2 PIT 15 Second 9 1040 4.00 975 0.052 x TVD 0.052 x 2385 Shut -in Pressure, psi 10 i u 1040 4.50 975 EMW at 3580 Ft -MD (2385 Ft -TVD) = 14.5 1000 15 11 1050 5.00 960 1500 - - - - -- - - 20 12 1050 5.50 960 25 13 1050 6.00 950 30 .14 1050 6.50 950 15 1060 7.00 950 16 1060 7.50 950 r o0o Z 17 1070 8.00 950 w 18 10 8.50 950 ce 19 10; 9.00 950 - 20 1080 9.50 9C 21 1080 10.00 950 . a 22 1090 soo 23 1090 24 1090 , , o0 I a 1 i i 0 5 10 Barrels 15 20 25 30 0 Shut -In time, Minutes 5 10 Volume Volume Volume Volume CASING TEST -U-LEAK -OFF TEST O PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls IBbls _ 25.0 Bbls IBbls Comments: The 7.2 ppg MW Is calculated based on assumed diesel freeze protect down to 1700r TV id the remaining 685' TVD wate 5/8" casing shoe PIT = 18.0 ppc not exceed max surface pump pressure of 1175 ps copy of CD4-322 Annular LOT Pumped 6- 5- I 2_reviseca.xrs Summary , . 0 • Conoco Phillips Alaska, Inc. Post Office Box 100360 i • gi • Anchoraue Alaska 99510-0360 ConocoP Telephone 907-276-1215 '47 .27 ;'. ■0 EE —, i t w ''' Z ,..,.. s g a; . .E 1 ..•' ."' ...„ .:-. ,.. 1: "7 i i -- (5 i 1 il V t I 1 t+ i =. t+ 1 4 4 e 3., ., ..■ ..7 .„7 g 7i TO' O = 0 : c 8 c. -., t... 1.2 •-,, . •-, e ." ... , P.L• gP *P-V. .2 1.- ' cc ., ,x .c .c .c - .e di di 2D tE T , " - : . .2. ',.."' 'e ':' ".: ..: . . . _ . . ._ _. . _ . . . . . . • _ . . .. g: 4 IT ,.. 7 -' F4 7S Ti P-.1 '' '' '' r: SC F.'s F.', RI rti , i 1 „4 0 :1 ..... ...7 1 .r ; . 3, :Of. 5\ : • - T ; ,. '.:" 7- '7' . . . _ - % 7E' .., tH : 7. "- --- zl1 1. ! g , ',..- ,„. t3 4 : IA - 4 7, i Si ■LZ. k•7" — . ,": , 3 o ..t. we A, el }:: r.Y .7E ...: i: 1 :: .i".... :,; .,_ F! $5 .-!.. - C-: c2. c"..3 F! c ■., c-C C: :14 . ,. -4 - 3 " . ?:::' ii " 3", 7 ' .. j '4 : 4 l' : ` -' r. '7 g ;7; 1 l', ;.■ i7''' Fi i4 ,,..' - ',::: :., :::: ''.;,: ''.:, :..;-. :=- PI 7.1. i! , . 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Al i ll -aS \^ ':'.. 1 4RM i / N / , . a �► . i ti / 1 Eral 1 \ II N '..\ -;,..,*) Li / , R.,,,, , ,,,„, 71 k aiii N :—.., ,,, ,diPAN 1 Iitib...16, . 1 , ,, . ,..\, c, ,,,t 0 ,ipp. N, : . ,N, I .■ f lr ,D!' „ aid I% i 1w� N i 0 , / A . \ (V t -1 I Alli 0 N t , N 0 i 1 ---"------ I L \ / • , 0 Fr 0 co 1/4.0 t , 7414 1 ca i iiim , . . , „ 1 ... i U ,..0 , , j 1 t :.„, / t U 1' r ??.. * O O O 4 Q r= ® p 0 4 0 an o cn in o T f (ui,14 00S) ( +)4ioNI(-)41noS • • ConocoPhillips Alaska, Inc. Post Office Box 100360 �I Anchorage, Alaska 99510 -0360 ConocoPh l I' ps Telephone 907 - 276 -1215 ConocoPhillips Casing Detail Well: CD4 - 322 9 5/8" Surface Casing Date: 7/30/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.20 FMC Gen V Hanger 2.18 36.20 Jts 3 to 92 90 Jts 9 -5/8" 40# L-80 BTC Csg 3461.08 38.38 Halliburton Float Collar 1.26 3499.46 Jts 1 to 2 2 Jts 9 -5/8" 40# L-80 BTC Csg 77.58 3500.72 Ray Oil Tools "Silver Bullet" Float Shoe 2.20 3578.30 3580.50 TD 12 1/4" Surface Hole 3590.24 12 1/4" hole - 3590' MD 2388.6' TVD 9 5/8" csg shoe - 3580.24' MD 2385.2'TVD TOTAL BOWSPRING CENTRALIZERS - 53 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, 69,71 ,73,75,77,79,81,83,85,87,89,90 98 joints in the pipe shed. 92 jts to run - Last 6 jts out Use Best - o 2000 pipe dope All joints drifted - 8.781" MU torque - 8600 ft /Ibs Remarks: Up Wt - 200 k DnWt- 125 k Block Wt- 75k Supervisor: D. Mickey/ N. Woods • • ConocoPhillips Alaska, Inc. IIIV Post Office Box 100360 • Anchorage, Alaska 99510 -0360 ConocoPh i l l s s Telephone 907 - 276 -1215 Conoco Phillips 1 CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-322 RIG: Doyon 19 CASING DESCRIPTION: 9 5/8 ", 40# L-80 BTC DATE: 07/30/07 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 39.79 26 37.05 51 37.41 76 37.00 101 126 151 176 2 37.79 27 36.22 52 38.69 77 37.34 102 127 152 177 3 39.44 28 38.99 53 39.10 78 37.81 103 128 153 178 4 38.50 29 38.94 54 39.11 79 39.16 104 129 154 179 5 38.44 30 36.84 55 37.24 80 38.13 105 130 155 180 6 38.93 31 39.08 56 39.40 81 38.66 106 131 156 181 7 38.59 32 38.42 57 38.69 82 38.56 107 132 157 182 8 39.23 33 38.33 58 38.65 83 38.35 108 133 158 183 9 38.97 34 42.81 59 38.05 84 38.63 109 134 159 184 10 36.80 35 41.67 60 38.60 85 38.67 110 135 160 185 11 38.34 36 37.68 61 39.22 86 38.60 111 136 161 186 12 37.63 37 38.84 62 39.21 87 39.28 112 137 162 187 13 38.33 38 38.69 63 38.69 88 38.60 113 138 163 188 14 38.16 39 40.24 64 38.11 89 36.71 114 139 164 189 15 38.31 40 37.81 65 39.30 90 38.74 115 140 165 190 16 39.26 41 37.95 66 38.63 91 39.10 116 141 166 191 17 37.93 42 36.76 67 39.25 92 39.03 117 142 167 192 18 38.34 43 37.63 68 38.29 93 37.60 118 143 168 193 19 36.64 44 36.15 69 38.67 94 38.58 119 144 169 194 20 38.28 45 37.94 70 38.99 95 38.67 120 145 170 195 21 38.94 46 38.66 71 38.30 96 38.64 _121 146 171 196 22 37.23 47 37.32 72 38.70 97 38.59 122 147 172 197 23 38.43 48 38.63 73 37.74 98 38.48 123 148 173 198 24 39.09 49 38.57 74 39.92 99 124 149 174 199 25 37.68 50 39.37 75 38.67 100 125 150 175 200 Tot 959.07 Tot 960.59 Tot 966.63 Tot 882.93 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3769.22 DIRECTIONS: TOTAL JOINTS THIS PAGE = 98 FLOAT SHOE 2.2 FLOAT COLLAR 126 HANGER 2.18 RKB 35.94 • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 Casing Detail Well: CD4 -322 Conoco Phillips Date: 08/12/07 Alaska. Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.15 FMC GenV Hanger 2.34 34.15 Jts 235 to 452 218 Jts 7" 26# L -80 BTCM Csg 9362.03 36.49 Tam Port Collar 2.12 9398.52 Jts 3 to 234 232 Jts 7" 26# L -80 BTCM Csg 9947.22 9400.64 Halliburton Float Collar 1 .04 19347.86 Jts 1 to 2 2 Jts 7" 26# L -80 BTCM Csg 85.44 19348.90 Ray Oil Tools " Silver Bullet " Float Shoe 2.21 19434.34 7" Shoe @ 19436.55 8 3/4" hole @ 19,4F 8 -3/4" Hole TD @ 19,452' MD / 7,739 TVD 7" Shoe @ 19,436.55 ' MD / 7,728 ' TVD Total Centralizers: 68 Straight blade centralizer one perjt on jts # 1 -14 Straight blade centralizer one perjt on jts.233 to 236 Straight blade cent one per jt. on joint #'s 241 - 247 Straight blade cent one per jt. on joint #'s 368,369,370 Straight blade centone on every other jt.# 372 to 450 490 joints in shed - 452 total jts. to run Last 38 jts. Out Use Run & Seal pipe dope Average make up torque 8000 ft/Ibs Supervisor: Lutrick /Hill • • ConocoPhillips Alaska, Inc. NI NIV Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 ConocoPhillips Alaska, Inc. CASING TALLY PAGE: 1 of 3 WELL NUMBER: CD4 -322 RIG: Doyon 19 TUBING DESCRIPTION: 3 -1/2 ", 9.3#, L -80, EUE Tubing DATE: 08/12/07 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 42.08 26 42.90 51 43.45 76 42.93 101 43.47 126 42.93 151 43.46 176 42.10 2 43.36 27 43.31 52 43.44 77 43.37 102 43.34 127 42.54 152 43.02 177 43.65 ` 3 43.44 28 41.67 53 42.95 78 43.27 103 43.05 128 43.79 153 42.93 178 43.38 4 43.30 29 43.45 54 42.31 79 42.68 104 43.38 129 43.10 154 42.99 179 43.37 5 43.03 30 41.62 55 42.11 80 43.60 105 42.63 130 43.79 155 42.55 180 43.48 6 42.03 31 43.01 56 43.05 81 43.24 106 43.55 131 43.13 156 43.41 181 43.47 7 43.02 32 43.34 57 43.13 82 43.31 107 43.43 132 43.48 157 42.35 182 42.96 8 43.44 33 43.56 58 43.47 83 43.03 108 43.44 133 39.94 158 43.42 183 43.39 9 43.46 34 43.51 59 43.63 84 40.56 109 42.94 134 43.11 159 43.36 184 42.94 10 43.24 35 43.01 60 42.75 85 43.44 110 43.46 135 41.73 160 43.37 185 44.15 11 42.96 36 43.12 61 43.46 86 42.43 111 42.96 136 43.21 161 40.55 186 43.08 12 40.09 37 43.27 62 43.44 87 41.61 112 43.55 137 43.10 162 39.16 187 43.43 13 43.56 38 39.95 63 43.14 88 43.46 113 41.14 138 43.09 163 43.38 188 41.38 14 43.03 39 43.45 64 43.47 89 42.89 114 43.40 139 41.94 164 41.87 189 42.43 15 42.10 40 43.54 65 43.37 90 42.32 115 43.42 140 37.52 165 43.46 190 43.49 16 37.94 41 42.79 66 42.94 91 42.68 116 43.44 141 43.34 166 43.48 191 42.17 17 43.13 42 42.74 67 43.41 92 43.55 117 43.11 142 42.79 167 43.38 192 41.61 18 42.91 43 43.18 68 42.88 93 43.48 118 41.94 143 43.55 168 43.37 193 43.28 19 42.94 44 43.94 69 42.87 94 43.46 119 43.57 144 43.46 169 41.87 194 42.71 20 39.20 45 42.59 70 41.31 95 43.44 120 42.13 145 41.65 170 43.41 195 43.41 21 43.44 46 43.44 71 43.47 96 43.61 121 43.07 146 36.49 171 42.90 196 43.43 22 42.40 47 43.48 72 43.32 97 41.44 122 41.34 147 41.79 172 43.03 197 43.37 23 42.99 48 42.04 73 43.37 98 43.38 123 43.00 148 43.02 173 43.45 198 43.42 24 40.35 49 42.82 74 41.55 99 43.21 124 43.45 149 43.38 174 43.33 199 43.05 25 42.93 50 42.99 75 41.99 100 43.45 125 43.44 150 43.44 175 43.49 200 41.34 Tot 1060.37 Tot 1072.72 Tot 1074.28 Tot 1073.84 Tot 1075.65 Tot 1059.31 Tot 1070.99 Tot 1074.49 TOTAL LENGTH THIS PAGE = 8561.65 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 HANGER RKB • • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhi 1lips Telephone 907 - 276 -1215 ConocoPhillips Alaska, Inc. CASING TALLY PAGE: 2 of 3 WELL NUMBER: CD4 -322 RIG: Doyon 19 TUBING DESCRIPTION: 3 -112 ", 9.3#, L -80, EUE Tubing DATE: 08/12107 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 43.43 226 43.32 251 43.19 276 43.50 301 43.50 326 43.49 351 42.81 376 42.94 202 43.45 227 43.19 252 4321 277 41.99 302 43.42 327 43.44 352 42.96 377 43.97 203 43.40 228 42.35 253 41.99 278 42.89 303 43.49 328 41.67 353 42.12 378 43.38 204 43.48 229 43.47 254 41.98 279 43.48 304 4322 329 42.29 354 43.51 379 43.51 205 43.38 230 43.43 255 43.03 280 43.40 305 43.40 330 43.44 355 43.39 380 43.25 206 43.29 231 43.71 256 43.26 281 41.79 306 43.43 331 42.81 356 43.46 381 43.44 207 43.16 232 42.40 257 42.66 282 43.47 307 42.96 332 43.54 357 43.47 382 41.38 208 43.39 233 43.56 258 40.12 283 42.87 308 42.80 333 41.89 358 43.83 383 38.84 209 43.40 234 42.98 259 43.19 284 43.29 309 41.53 334 42.81 359 43.17 384 43.47 210 43.36 235 43.46 260 42.03 285 42.80 310 43.65 335 42.69 360 43.11 385 42.88 211 43.38 236 43.02 261 43.44 286 43.44 311 43.45 336 42.54 361 43.43 386 41.26 212 43.41 237 43.43 262 42.81 287 41.77 312 43.44 337 43.05 362 42.96 387 41.42 213 43.44 238 42.41 263 43.46 288 43.46 313 43.49 338 42.81 363 43.51 388 42.33 214 43.43 239 43.02 264 43.49 289 42.35 314 43.40 339 43.76 364 42.50 389 42.86 215 42.77 240 41.46 265 42.78 290 41.88 315 43.48 340 43.83 365 43.38 390 40.39 216 42.91 241 42.05 266 43.42 291 43.42 316 43.32 341 42.64 366 43.47 391 43.39 217 43.45 242 43.04 267 41.56 292 42.82 317 4324 342 43.52 367 42.83 392 43.42 218 42.92 243 43.36 268 43.37 293 43.42 318 43.88 343 43.25 368 43.38 393 38.97 219 43.24 244 43.07 269 42.08 294 43.48 319 43.39 344 43.73 369 43.15 394 42.61 220 43.38 245 43.81 270 42.87 295 43.49 320 43.00 345 41.51 370 42.10 395 43.42 221 43.41 246 41.93 271 42.43 296 42.08 321 43.09 346 43.48 371 43.42 396 42.35 222 43.44 247 43.39 272 42.82 297 43.44 322 43.47 347 43.50 372 42.12 397 43.40 223 43.47 248 43.24 273 43.47 298 43.40 323 43.40 348 43.49 373 41.50 398 43.06 224 43.21 249 41.45 274 4329 299 43.33 324 43.47 349 43.38 374 42.83 399 43.47 225 43.00 250 43.60 275 43.37 300 43.32 325 43.38 350 42.59 375 43.52 400 43.40 Tot 1082.60 Tot 1074.15 Tot 1069.32 Tot 1074.58 Tot 1082.30 Tot 1075.15 Tot 1075.93 Tot 1062.81 TOTAL LENGTH THIS PAGE = 8596.84 TOTAL LENGTH = 1 71 58.49 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200.00 TOTAL JOINTS = 397.00 AVERAGE JT = 43.22 • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i I I i ps Telephone 907 - 276 -1215 ConocoPhillips Alaska, Inc. CASING TALLY PAGE: 3 of 3 WELL NUMBER: CD4 -322 RIG: Doyon 19 TUBING DESCRIPTION: 3 -1/2 ", 9.3#, L -80, EUE Tubing DATE: 08/12/07 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 401 42.88 426 42.64 451 43.29 476 43.46 501 526 551 576 402 38.35 427 43.45 452 43.45 477 41.77 502 527 552 577 403 43.18 428 43.30 453 43.33 478 43.54 503 528 553 578 404 43.41 429 42.75 454 43.35 479 43.34 504 529 554 579 405 42.83 430 43.44 455 39.06 480 43.39 505 530 555 580 406 43.40 431 42.37 456 43.27 481 43.35 506 531 556 581 407 43.43 432 43.25 457 43.35 482 43.37 507 532 557 582 408 43.42 433 43.50 458 43.48 483 43.44 508 533 558 583 409 43.26 434 42.89 459 43.46 484 43.55 509 534 559 584 410 41.10 435 43.47 460 41.93 485 43.14 510 535 560 585 411 43.48 436 43.46 461 43.47 486 43.32 511 536 561 586 412 43.96 437 42.97 462 43.36 487 43.39 512 537 562 587 413 42.43 438 38.22 463 43.41 488 42.83 513 538 563 588 414 42.47 439 43.40 464 43.22 489 43.66 514 539 564 589 415 43.21 440 43.43 465 43.33 490 42.82 515 540 565 590 416 43.48 441 43.40 466 42.50 491 516 541 566 591 417 43.28 442 43.38 467 43.11 492 517 542 567 592 418 43.47 443 43.47 468 43.44 493 518 543 568 593 419 43.51 444 43.44 469 43.46 494 519 544 569 594 420 43.50 445 43.51 470 43.38 495 520 545 570 595 421 43.70 446 42.31 471 43.46 496 521 546 571 596 422 43.27 447 43.43 472 42.84 497 522 547 572 597 423 43.42 448 43.28 473 42.80 498 523 548 573 598 424 43.46 449 43.24 474 43.35 499 524 549 574 599 425 43.39 450 42.17 475 43.51 500 525 550 575 600 Tot 1075.29 Tot 1074.17 Tot 1076.61 Tot 648.37 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3874.44 TOTAL LENGTH = 21032.93 DIRECTIONS: TOTAL JOINTS THIS PAGE = 90.00 TOTAL JOINTS = 490.00 AVERAGE JT = 42.92 • . ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 :onocoPh • I I • ps Telephone 907 - 276 -1215 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) VeTao, 11) - km 05 Well CD4 -322 Assumptions Date 6/6/2012 Maximum injection pressure of 1,178 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 cr Maximum Fluid Density to avoid Burst of Surface Casing P burst85 % = PHydrostatic + PApplied - PFormation 4 ,888 = ( 2,385 * 0.052 * MW MWmax = 38.2 ppg )+ 1178 - ( 0.4337 * 2,385 ) If, N c� (L ilh 2,385 TVD ' Surface Casing String Size 9.625 in Weight 40 ppf Grade L 80 ti. rburst100" /0 5,750 psi Pburst85% 4,888 psi tt `.) Depth of Shoe 2,385 ft FIT /LOT @ Shoe 18 ppg or 2,233 psi FIT /LOT for Annulus 16.7 ppg CZ Max Surf. Pressure 1,178 psi TOC Est. @ 8,390' MD� 3,961' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - 'Header 4,599 = ( 3,961 * 0.052 * MW )+ 1,178 - ( 0.0700 * 3,961 ) - 1,000 X X MWmax = 22.8 ppg 4.5 "Tubing 2nd Casing String Size 7 in G 7,728 TVD Weight 26 ppf Grade L 80 f'collapse100% 5,410 Psi Pcollapse85% 4,599 Psi Top of Cement 3,961 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,178 psi Header Press 1,000 psi Maximum Anticipated Pressure at Depth of Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,385 * .052 * 18 ) Pmax allowable = 2,233 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". • • Conoco Phillips Alaska, Inc. 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L - Lij • • Note to File CRU CD4 -322 (PTD 2071010) Revised: September 13, 2010 Second Revision: June 12, 2012 Re: ConocoPhillips' Application for Sundry Approval for Increasing the Volume Limit for Annular Disposal of Drilling Wastes within Well CD4 -322 Request ConocoPhillips requests approval to increase the volume limit to 70,000 barrels for disposal of waste fluids generated through drilling operations by injection into the annulus of well CD4 -322. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at - 2,330' true vertical depth subsea', near the base of a 35 -foot thick shale and claystone interval that persists throughout the area. This interval provides confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandstone open to the annulus of this well 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 are 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 about 210' from the wellbore. Discussion To date, CPAI has injected 30,832 barrels of waste into the annulus of CRU CD4 -322 (CD4 -322). CPAI is requesting an increase in maximum allowable injected volume from 35,000 barrels to 70,000 barrels. The AOGCC reviewed CPAI's application along with records from nearby wells Nanuk 2, CD4 -321, CD4 -16, Nanuq 3, and CD4 -306. The discussion that follows is based on well logs and mud logs from these wells. Figures 1 and 2, below, present index maps for the affected area. The proposed injection interval is the open annulus of CD4 -322, which lies in the Seabee formation within Sections 23 and 24, T11N, R5E, UM and in Section 24, T11N, R4E, UM, and is 2 to 3 miles from the current boundary of the CRU. The 9 -5/8" surface casing shoe of the well lies at - 2,330', near the base of a 35 -foot thick claystone and shale interval that is continuous throughout the area. This impermeable interval will provide upper confinement for disposed fluids. 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 lie at about - 3,900'. The most likely portion of the open annulus that will accept injected waste (most likely disposal interval) is a 50 -foot 1 Unless otherwise noted, all depths presented herein are expressed as negative integers, which represent feet, true vertical depth below sea level (mean low, low water). All thicknesses are expressed as positive integers, which represent true vertical feet. All horizontal distances are expressed as positive integers, which represent feet. • • • CD4 -322 Increased Volume Application June 12, 2012 Note to File Page 2 of 5 ■ 4 I : UL . { Ls i � , L' Area of vRev tew ci files 1. ,� (1/4 mile radius) ''Y "r S\irfacc i, CD4 -32� + soemarkr • ° Aria A 96.11 A n � � o � o A 9 ! ° ` , Nanuq 3 _ : ' ® ° CD4 -322 Open , ,. a. .=, Annulus \ n , Nanuk 2 t Most Likely , i Disposal ' Interval 0' 2.000' - - — _ - Figure 1. CD4 -322 Index Map (All depths shown are true vertical feet below sea level. The magenta - colored line depicts the path of the cross - section displayed in Figure 3.) thick interval containing several 1- to 4 -foot thick beds of silty sandstone and sandstone that lie just below the surface casing shoe between about - 2,415' and - 2,465' (see Figure 3, below). The aggregate thickness of these silty sandstone and sandstone beds is about 9', and they are interlayered with thin beds of shale and claystone. A continuous, 70 -foot thick interval of shale, claystone and tuff that that ranges from about - 2,575' and - 2,645' will provide lower confinement for the injected waste materials. Additional lower confinement will be provided by numerous shale and claystone layers that lie between - 2,680' and - 3,875'. In the CD4 -Pad area, the base of permafrost occurs at about - 1,450', which is about 850' above the top of the proposed injection interval. The shallow geologic section in the area surrounding CD4 -Pad contains methane gas. Records from the Nanuk 2 and Nanuq 3 exploratory wells indicate that traces of methane were first measured between -70' and -340, respectively. The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were - 2,170' and - 1,535', respectively. Both wells were drilled through this geologic section using somewhat similar drilling mud weights (10 to 10.4 pounds per gallon). • • • CD4 -322 Increased Volume Application June 12, 2012 Note to File Page 3 of 5 _ _ k , CD421\ \ - C D 4 70 00 1\ - - - - ,. �\ X 650\, , -5 0 ° 0 Area of \Review circle \ C 2 7 \ _ \ -aso /4 mile radius) �0 \CD236 . - _ .00 300 -f oot radius cir e) N "-- -0000 , -4500 _ ,.,,�.� —.� - \, / \ -6000 \ \ -3500 \ Surface casing' _,h 410.6500 , \ \ �� - 3500 \ shoe marker -4002 D2 -60 �. -3000 -, �� � \ i - 1 .-3560 s�o• CD4 - 304 ° 3000 A —550 • 500 _ -.. 5000 . iS50 \.. -2500 '111-25 0 2500 , -- , . % -3000 �� 20 0 CD4- 1 6 1 � -_ __ 200' A - - b.. _ - - 350• r.0, .a 'M..; " ti3- � -'r7:::- CD4 -322 39 • ---4. ' , - • .. , Open _6500 , i I U Q 3 • •_ -- s00a Annulus • " a ---�'' � , 45 0 2Epo6 - " "— � Nanuq 3 � --,...-5.. � �DD- 9 l "t ii- a R r "r a 2 5 0 5 0 30 00 8 ° �oee CD2 s 1'I � � 1 �s 0 0 5 + bso0 v I , i � O. �.. 4600 ' 1 o -55 0A 6 0 y � „i i ' " ,�. . n X7 ' o.: "" -- ---- aSDO � , y Most b oo " y _ Likely '`P ° - 1S°A _ -3 _ _ a. Disposal i o , � - 4 , 500 � ' �_ 3s60` 000 -5500 % Interval f -3000 _ "F"_ 0 00 W% DDO / 3g00 _ 0' 1 000' �/ �Dl- C 213 ; 3 ' /� / -4500 ,-4-66"0 0 3 5 � j -4500 ... . � 1 �" ; 45Nn / -3500 000 ,, Figure 2. Enlarged CD1 -15 Index Map (All depths shown are true vertical feet below sea level. The magenta - colored line depicts the path of the cross - section displayed in Figure 3.) Supporting documentation submitted by ConocoPhillips 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, states 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 2 and Nanuq 3 occur at - 3,765' and - 3,940', respectively. The mud - logging geologists rated these shows as being fair to good in quality. However, these oil shows occur more than 1,300' below the most likely disposal interval. The chart displayed in Figure 4 provides an estimate of the affected areas surrounding the CD4 -322 wellbore. Well logs indicate that about 9' of net sandstone and silty sandstone are present in the most likely disposal interval. Inspection of neutron and density porosity logs suggests an average porosity of 32% at this depth for the sandstone and silty sandstone beds within the injection interval. Based on these values, the area most strongly impacted by the proposed annular injection of an additional 35,000 barrels of waste fluids will be limited to a radius of less than 210' from the wellbore, assuming the injected fluids displace native formation fluids in a uniform, radial, piston -like manner. 2 The count of net feet of sandstone and silty sandstone is based on a gamma -ray curve cut -off value of 80. • • • CD4 -322 Increased Volume Application June 12, 2012 Note to File Page 4 of 5 2070940 2071010 2010260 2061420 501032055000 501032055100 501032036500 501032053600 4 1676' I 4 967' ► / 920' CONOCOPHILLIPSALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPSALASK COLVILLE RIV UNIT CD4 -306 COLVILLE RIV UNIT CD4 -322 NANUQ 3 COLVILLE RIV UNIT CD4 -321 2907 FNL 167 FEL 2987 FNL 477 FEL 2268 FSL 574 FEL 2982 FNL, 458 FEL 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: 4 E - Sec. 24 - w i -500'. ro _ . -1000' f „b Y t ,.A �,W i Base of .�, Isoo' -,- -- Permafrost ,- .. '1!x!1,,, _ Surface - Casing .p m .. / Shoes Upper 4- 2000' . Confining - �' m Interval n: ,�__ Mos a x Likely _c ,, ,_ I,._-).- ,. Disposal .. 1 _ zsoo' Interval m 4 - t 1 - -, t 1 —■ gz _ -3000 Lower - - Open "• nnulu - - Confining Beds C --■ ',.,,, fr— .., i z a TD =10346 TD =19452 ,m TD ?r . , i i t Joao 9112 .m TD =19337 4000' Figure 3. CD4 -322 Area: Stratigraphic Cross - section (Depth scale represents true vertical feet below sea level; separation distance between wells is measured between the surface casing shoes) • . CD4 -322 Increased Volume Application June 12, 2012 Note to File Page 5 of 5 Injected Fluid vs Affected Radial Distance CD4 -322 Wellbore (Assumes 9' aggregate injection zone thickness and 32% porosity 250 200 150 m , 0 100 — — —— a i w 50 I 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 Amount of Injected Fluid (barrels) Figure 4. CD4 -322 Area Likely Affected by Annular Injection The open annuli of 11 wells lie within the 1/4 -mile area of review (or more properly, within the 1 4-mile radius cylinder of review) surrounding the open annulus of CD4 -322: Nanuq 3, CRU CD4 -05, CRU CD4 -07, CRU CD4 -16, CRU CD4 -17, CRU CD4 -208, CRU CD4 -215, CRU CD4 -304, CRU CD4 -306, and CRU CD4 -321. Of these, only three wells pass within about 300' of the most likely disposal interval within CD4 -322; they are Nanuq 3, CD4 -16, and CD4 -304, and the open annuli of each of these wells lies at least 800' deeper than that of CD4 -322 as they pass through the cylinder of review, making direct communication with waste injected into CD4 -322 highly unlikely. However, if injected wastes reach these nearby wells, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the approved disposal interval. Summary The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath about 1,450' 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 are not a concern. It is unlikely that injected wastes will reach the open annuli of nearby wells; but if they do, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the disposal strata. I recommend approval of the increase in volume limit for this annular disposal operation. Steve avies J (On60r, 4 0 - 2/ Seni etroleum Geologist �. /2• /z- • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission '.-D DATE: Tuesday, July 05, 2011 TO: Jim Regg �(l4' /t P.I. Supervisor C SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -322 FROM: Matt Herrera COLVILLE RIV NAN -K CD4 -322 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry e - NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN -K CD4 -322 API Well Number: 50- 103 - 20551 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH1 1 070 1 090046 Permit Number: 207 -101 -0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. CD 4 -322 T 7161 - I 150 3100 3060 A 00 3060 7 Well Type Inj. W �TVD , P.T.D1 2071010 'ITYpeTest 1 SPT T est psi 1 790 OA 100 87 —�- — 87 87 Interval 4YRTST p/F P . Tubing 2338 2318 2317 2318 I Notes: IA tested to 3050 psi 4.8 BBL's L 2,P Tuesday, July 05, 2011 Page 1 of 1 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AP 1 e 7 Z(J1' April 01, 2011 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 0-7 Anchorage, AK 99501 r 30 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, / 17 // 1 ; 76----/ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD4 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD4 -07 50103205530000 2071180 6" n/a 16" n/a 3.8 3/13/2011 CD4 -12 50103204140100 2100910 13" n/a 36" n/a 11.9 3/13/2011 CD4 -23 50103206210000 2100670 28" n/a 28" n/a 8.5 3/13/2011 CD4 -24 50103206020000 2090970 16" n/a 16" n/a 4.3 3/13/2011 CD4 -26 50103206000000 2090490 26" n/a 26" n/a 8.5 3/13/2011 CD4 -209 50103205320000 2060650 SF n/a 16" n/a 4.2 3/13/2011 CD4 -213 50103205400000 2061730 13" n/a 18" n/a 4.3 3/13/2011 CD4 -322 50103205510000 2071010 SF n/a 16" n/a 4.7 3/13/2011 • ~- ~: ~ " L` ;~ ~ . ~,. ~ _, , u b 8 s ~ ss~rt ~~ ~~" mow. r ~' *c"~ m irc~ ~ s ' k.. ~ . t ~ ~rr ~ t p ,uk- MICROFILMED. 6/3012010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CONDUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. John Tonello Alpine Production Engineer ConocoPhillips Alaska-, Inc. P.O. Box 100360 a07- Anchorage, Alaska 99510~ Re: Colville River Field, Alpine Oil Pool, CD4-322 Sundry Number: 309-393 &JO&D D IE L "1 8 2009 Dear Mr. Tonello: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). 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, rman Co sio nerrt DATED this 3q day of November, 2009 Encl. • STATE OF ALASKA RECEIVED 11 ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 1 9 2009 APPLICATION FOR SUNDRY APPROVAL Oil & Gas Cons. Connission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate E Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 207 - 101 • 3. Address: Stratigraphic ❑ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20551 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ❑ No CD4 -322 9. Property Pas ignation (Lease Number): 10. Field/ Pool(s): �� �; ' y ADL 380077, 387208, ASRCNPRA02 ` Colville River Field / Nan WE* Oil Pool ' A //, 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 19452' • 7739' • 19221' 7586' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16" 114' 114' SURFACE 3543' 9 -5/8" 3580' 2385' PRODUCTION 19399' 7" 19436' 7728' i I I I Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 18538'- 18558' 7263' -7270' 4.5" L -80 18299' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker Premier pkr @ 18226' MD / 7161' TVD Camco DB nipple @ 2289' MD / 1952' TVD 12. Attachments: Description Summary of Proposal ❑� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 4, 2009 Oil ❑ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 2 Abandoned❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Tonello @ 265 -6371 Printed Name AJh Tonello Title: Alpine Production Engineer �— Signature Phone 265 -6371 Date Commission Use Onl Sundry Numbe Conditions of approval: Notify Commission so that a representative may witness 0 ? Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: r APPROVED BY ve O MISSIONER THE COMMISSION Date: " V r 0 3 l • Submit in Duplicate 1-N I CD4 -322 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. Colville River Field Well CD4 -322 (PTD207 -101) Sundry Notice 10 -403 Request Stimulate Nanuq Kuparuk Interval November 17, 2009 Purpose This sundry notice is to notify the AOGCC of ConocoPhillips Alaska Inc, intent to stimulate the Kuparuk interval (part of the Na / aruk Oil Pool) in the CD4 -322 well. f�,( / �f/ 1 !� �5 c'-c? �n- -v�.a -t, a U'rl t2c`rs 1 (✓' �' �� ✓ � 7 ��� Additional Information CD4 -322 was completed as a slant injector through the Nanuq Kuparuk interval. The well is currently injecting through existing perforations. Electric line deployed Halliburton Stimtube will be used for the stimulation. Proposed Operations: 1. Run tie -in CCL 2. Stimulate Nanuq Kuparuk interval at 18,538'- 18,558' MD. I CdnocoPhlillips Alaska, Inc. ALPINE CD4 -322 134 -322 _ TUBING ( 31-182 99 , API: ; 501032055100 Well Type Angle @ TS: deg - ( OD:4.500, SSSV Type: WRDP Ong Completion: 8/2212007 Angle @ TO: 45 deg @ 19452 00:4.5 ID:3.958) Annular Fluid: Last W /O: Rev Reason: NEW WELL, PULL BALUROD, PERF, set INJ VLV - RODUCTION ._.. ..__ (34-19436, Reference Log 37' RKB Ref Log Date _ Last Update: 9/12/2007 00:7.000, Last Tag: TD 9452 ftKB _ _ _ Wc26.00) Last T Date- Max Hole Angle: 73 deg @ 5100 SURFACE (36 -3580, Casing String - COMPLETION _ _ OD:9.625, Description Size Top Bottom TVD _ Wt Grade 1 7 WC40.00) PRODUCTION 7.000 34 19436 7728 _ 26.00 L -80 SURFACE 9.625 1 36 3580 2385 40.00_ L -80 CONDUC I OR 16.000 37 114 114 61.00 H -40 WELD Tubing String - TUBING Size Top Bottom TVD Wt Grade Thread 4.500 31 18299 7184 12.60 L -80 IBTM Perforations Summary M; Gas Lift Interval 18538 18558 TVD Zone Status Ft SPF Date Type Com ment - _ andrel /Dummy 7263 - 7270 20 6 9/3/2007 IPERF 2 7/8" PJ OMEGA, 130 deg Valve 1 ph ;18119 - 18120, Gas Lift Mandrels /Valves 00:5.984) St MD TVD Man Mfr I Man Type V Mfr V Type VOID Latch Port TRO Date Run Vlv Cmnt 1 18119 71281 CAMCO KRG -1 DMY 1.0 BK 0.000 0 8/20/2007 Other (plugs, equip., etc.) - COMPLETION Depth TVD Type Description ID 31 31 HANGER FMC TUBING HANGER 3.958 2289 1952 NIP CAMCO DB NIPPLE 3.812 2289 1952 VA A -1 INJECTION VALVE O N DB6 LOCK set 9 /7/2007 1.125 18226 7161 PACKER BAKER PREMI PACKER 3.875 18287 7180 NIP HES'XN' NIPPLE 3.725 PACKER ;18226 - 18227, 18298 7184 1 WLE WIRELINE GUIDE — . 3.875 OD:5.970) – I NIP - ;18287 - 18288, 013:5.000) W LEG ;18298-18299 , OD:5.000) i Perf ;18538 - 18558) I � I • MEMORANDUM TO: Jim Regg ~ / P.I. Supervisor ~~~~ ~I 3~'a ~ FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 31, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-322 COLVILLE RIV NAN-K CD4-322 Srr. Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: COLVILLE RIV NAN-K CD4-322 Insp Num: mitRCNO9o729101101 Rel Insp Num: API Well Number: 50-103-20551-00-0o Permit Number: 207-101-0 .~ Inspector Name: Bob Noble Inspection Date: ~~23/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4-322 Type Inj. W ~'~ 7161 jA 512 3015 ~ 2995 2991 " f p.T.D 2071010 TypeTest SPT Test psi 179025 ~ ~A 336 649 636 632 Interval 4YRTST P~ P / Tubing 2225 I 2225 2220 2220 Notes: ar ~*4 . '~'' ~- ~ 1k~~l~~W~ Friday, July 31, 2009 Page 1 of 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-322 May 13, 2009 AK-MW-515927 CD4-322 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20551-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20551-00 Digital Log Images: 1 CD Rom 50-103-20551-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com U~ C. ao ~ _ `v1 / ~oS'~ Signed: ' L V 6J,,d • ~ J. Eggemeyer Engineering Leader Drilling & Wells ~ P. O. Box 100360 Anchorage, AK 99510-0360 ~~~~~~~~ ~ ~ ~ ~ ~~ Phone: 907-265-6049 May 13, 2008 ~, ~ T. Maunder o ~ State of Alaska - Alaska Oil & Gas Conservation Commission ~~ n~ 333 West 7t" Avenue Suite 100 ~°~ Anchorage, Alaska 99501 ~ Q ~ ~ ~ ~ ~- ~~ C ° m o ~ Subject: Additional Well Summaries ~ ~~„1 ~ t ~ ` ~ ~ Dear Mr. Maunder: a ConocoPhillips Alaska, (nc. submits the attached well summaries for wells 1A-01, CD4-07, 1 J-122, 1 J-122L1, 1 J-122L2, CD4-322, 1 J-162, 1 J-162L1 you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. ~h~~~~~~~~,~ ~,.~~~ If you have any questions regarding this matter, pfease contact me at 265-6049. Sincerely, ;k ,, 4. ~~ J~' 7~~i~~i~.- a~ ~ i . 3/~~(~~'. ~~'«.. ~~~ - . . Eggemeyer Engineering Team Leader CPAI Drilling J E/skad ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 • ~a~-1o~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: G~a~ ,~ MAR ~a 20~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 ~c~~~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 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 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 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 CD4-16 206-131 SF NA 5" NA 2.55 3!18/2009 Cp4-17 206-118 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 ~~~~,~ 4~~1~ ~; ~~~~; ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-101 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-322 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20551-00 3. (Check one box only) 5a. Sundry number. 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final 0 307-293 10/25/2007 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 407* 407 totals (bbls): 2007 / 4th 20381 100 0 20481 16 12/8/2007 12/31/2007 CD4-301 2008 / 1st 9844 100 0 9944 10 1 /1 /2008 1 /10/2008 CD4-301 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 Total Ending " Report is due on the 20th volume 30225 200 407 30832 26 (bbls): 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 2Q for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "annular flush, freeze rotect, leak-off test, in'ectivit test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~`~. ~.. ~/` Date: ~~~~~ 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 DATA SUBMITTAL COMPLIANCE REPORT 1 111 9/2 0 0 8 Permit to Drill 2071010 Well Name/No. COLVILLE RIV NAN-K CD4-322 Operator CONOCOPHILLIPS ALASKA INC MD 19452 TVD 7739 Completion Date 9/7/2007 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT, CCL Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D Asc Directional Survey Cement Evaluation II' C Lis 15726 Induction/Resistivity f I' pt 15726 LIS Verification Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Chips Received? "~7'#-- Analysis ~#- Received? Comments: Compliance Reviewed By: API No. 50-103-20551-00-00 (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / • Scale Media No Start Stop CH Received Comments 0 19452 Open 9/12/2007 5 Col 1 100 19175 Case 9/28/2007 SCMT, 2 7/8' Powerjet Omega, SBHPS 3-Sep- 2007 3551 19452 Open 12/7/2007 LIS Veri, GR, NPHI, NCNT, RHOB, FCNT, RPX, RPD 3551 19452 Open 12/7/2007 LIS Veri, GR, NPHI, NCNT, RHOS, FCNT, RPX, RPD Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops / N Date: ~~ 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: 207-101 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-322 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20551-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 307-293 10/25/2007 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 407" 407 totals (bbls): 2007 / 4th 20381 100 0 20481 16 12/8/2007 12/31/2007 CD4-301 zoos/1st 9844 100 0 9944 10 1/1/2008 1/10/2008 CD4-301 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 rotas Ending Report is due on the 20th volume 30225 200 407" 30832 26 (bbls>: 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 Description(s): ''annular flush, freeze protect, leak-off test, in'ectivit test volumes correct to the best of my knowledge. I hereby certify that the foregoing is true a nd // ~~ ~ Signature: ~ ~~_t_,k•'l Date: l~ll3~Du' 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 i. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-101 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-322 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ WDSPL ^ 50-103-20551-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 307-293 10/25/2007 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 407* 407 totals (bbls): 200 / atn 20381 100 0 20481 16 12/8/2007 12/31/2007 CD4-301 2008 / 1st 9844 100 0 9944 10 1/1/2008 1/10/2008 CD4-301 2008 / 2nd 0 0 0 0 0 2008 / 3rd Total Ending * Report is due on the 20th 30225 200 407 30832 26 (bbls)e 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 Description(s): *annular flush, freeze rotect, leak-off test, in'ectivit test volumes I hereby certify that the foregoin is true and correct to the best of my knowledge. Signature: ~ ~ ~'~ ~- Date: "7 rt $ ~n ~ 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: `~ ZQ7-101 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-322 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. 0. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^~ WDSPL ^ 50-103-20551-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation Q or Final ^ 307-293 10/25/2007 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 407'` 407 totals (bbls): 200 / atn 20381 100 0 20481 16 12/8/2007 12/31 /2007 CD4-301 zoos / 1st 9844 100 0 9944 10 1/1/2008 1/10/2008 CD4-301 2008 / 2nd 008 ! 3rd Total Ending Report is due on the 20th volume 30225 200 407* 30832 26 Ex: of the month following the final month of the quarter (bbls): . July 20 for the second quarter, Apri120 for the first 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, leak-off test, in'ectivit test volumes I hereby certify that the foregoin is~true and correct to the best of my knowledge. `~~~ ~~ ` ~°°' Signature: Date: 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 Page 1 of 1 i • Maunder, Thomas E (DOA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.com] Sent: Wednesday, January 30, 2008 8:13 AM Ta: Maunder, Thomas E (DOA) Cc: Alisup-Drake, Sharon K Subject: RE: Operations Reports thanks to-n. } am surs we can accomm~date. ~Ce ~ ~~-- ` V ~ From: Maunder, Thomas E (DOA) [maitto:tom.maunder@alaska.gov] Sent: Wednesday, ]anuary 30, 2008 8:07 AM To: Eggemeyer, Jerome G ~,; ~~~v±ja~~=.~ , r,.,~ . ;;, ~:'. Cc: Allsup-Drake, Sharon K ° ~" ° Subject: RE: Operations Reports Thanks Jerome. These aren't urgentiy needed. Only other request, is send the reports "singte sided". When we get double-sided, we have to shoot additional copies in order to scan. Tom From: Eggemeyer, lerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Tuesday, January 29, 2008 10:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. As soon as Sharon is abie to organize the data it will be sent aver (hopefuily only a#ew days depending on other activities). ~e# us know if it is needed more urgently. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent; Tuesday, January 29, 2008 4:38 PM To: Eggemeyer, Jerome C. Cc: Allsup-Drake, Sharon K Subject: Operations Reports Jerome and Sharon, Thanks for sending the more detailed operations reports. I have further reviewed the Commission's files regarding 407's submitted since about August and found that more complete reports are needed for a few other wells. The wetls are: ~ 1J-162, -162L1 207-080, 207-181 ~ ~ ~ ~ \_c ~~ CD4-322 207-101 ~`r`~--`'~-~ ~ ~ ~ ~~~ 1 J-122, -122L1, -122L2 207-070, 207-071, 207-072 For the multilateral wells, a complete summary is only needed for the main welfbore with only the specific operations needed for the laterats. Your assistance in making the well records complete is appreciated. t wiil be reviewing the recently submitted sundry reports shortly and will send another message if necessary. Call or message with any questions. Tom Maunder, PE AOGCC ~~f` r f-- ~~'~ ~ C~ 8/18/2009 R-`'~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION GOMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-101 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-322 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ Q WDSPL ^ 50-103-20551-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ~ 307-293 10/25/2007 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 407* 407 totals (bbls): 200 / ath 20381 100 0 20481 16 12/8/2007 12/31/2007 CD4-301 2008 / 1st 2008 / 2nd 2008 / 3rd Total Endl~g Report is due on the 20th volume 20381 100 407* 20888 16 (bbls): of the month following the Tina! month of the quarter. Ex: July 20 for the second quarter April 20 for the first 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, leak-off test, in'ectivit test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: l ~ ~--~-~ Date: ~ r°( ~O~ 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 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 2, 2007 RE: MWD Formation Evaluation Logs: CD4-322 AK-MW-5159277 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#: 50-103-20551-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. A~h~a,~4~9~,8 _~ ~:~ Date,; Signed: ~„~ ~~~ ao~ -«~ ~` ~s-~a~ ~ ~ d ~~ SARAH PAUN, GOVERNOR ~, ~~.t. oit0-7~A Oaa4 ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSFiRQA'1`IO1Q COMbIISSIOI~T ;;+ ANCHORAGE, ALASKA 99501-35 ~~ PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-322 Sundry Number: 307-293 Dear Mr. Alvord: 39 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 requester ' DATED this ~5 day of October, 200? Encl. ~~5~~~~7 ~-~7 /0,2'~-07 STATE OF ALASKA ~.1~~ a~ SEP 2 0 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION ~iaska Oil & Gas Cods. Comfnissio~ Ancltoea>a 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 207-101 ConocoPhillips Alaska a. API Number: 50-103-20551-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Aiaska CD4-322 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: CD4-16, GD4-17, CD4-321, Nanuq 3 2400' ND Torok and Seabee formation, shale, siltstone and sandstone p~ i W t i b ~ v as e rece ng zone: ) b) water wells within one mile: rr;~~ 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: None densities range from diesel to 12#/gal 2233 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 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 8-Oct-07 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 product cleanup fluids for CD1 and CD2 18. I hereby certify that thefo regoing is tr u and correct to the best of my knowledge. e ,/~~ (~~ ~ ~ / ~ / ~ / Signature: ~ V - ~ Title: ! I ( awl 4+^ ~`'^"'~' ~r ~ _ _ Printed Phone Name: Chip Alvord Number: 265-6120 Date: 9119107 Commissi Use Only ~~ ~/ ti J'1 Conditions of approval: C.OM~~~ W~Cfc ~ ( c~ ~,i~ a-S • LOT review and approval: ' Subsequent form re uired: ~~- c~ Approva! number. L~ 1 ~ (7~~ S ~F~, 0 ~? ~ ~ 2007 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: IQ ~~~ Form 10-403RD Rev. 6/2004 U K ` ~ „`~UCTIONS ON REVERSE ~~ ~ T' d 3u%~~~q~~l~~ " L~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 19, 2007 Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue, Suite 100 Anchorage, Alaska 99501-3539 SAP 2 ~ x.007 Alaska Oil ~ Oas ~a~s~Oers~tr-"t5sion Arch Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4-322 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-322 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 CD4-322 approximately October 8, 2007. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 9-5/8" x 7" casing annulus 11. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 12. Additional information regarding wells within 1/4 mile radius at AOGCC: No additional wells needed. CD4- 07 is currently being drilled and its surface casing is within the '/4 mile radius. The surface casing has been set, but the well is not far enough along to provide all the necessary information in this annular disposal package. 13. 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 (16.8 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 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. 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 Galin s Drilling Engineer cc: CD4-322 Well File Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1530 ConocoPhillips RECEIVED C~ • Annulus Disposal Transmittal Form -Well CD4-322 AOGCC Regulations. 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD4-322 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 sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording 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 wells 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 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 2233 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 oral 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 CD4-07, CD4-304, CD4-303, CD4-301 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 coin Hance would be im rudent. 16 Any additional data required by the commission to confum N/A containment of drillin waste. Well CD4-322 Date 9/19/2007 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) 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/ft Header Pressure (for wells on gas lift) 1.000 psi Version I.0 - Jan'OS Pburst85% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,385 * 0.052 *MWmax ) + 1500 - (0.4337 * 2,385 ) MWmax = 35.7 PPg en '! a_ 'y: _: R: <-: U N b a 2,385 TVD ~ ~ d ~ U 0 0 0 Surface Casing Strin Size 9.625 in Weight 40 ppf Grade L 80 rburstloo% 5,750 psl Pburst85% 4 $$$ psi Depth of Shoe 2,385 ft F[T/LOT @ Shoe 18 ppg or 2,233 psi FIT/LOT for Annulus 16.8 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 8,390' MD 3,961' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85 % - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 3,961 * 0.052 *MWmax ) + 1,500 - (0.0700 * 3,961) - 1,000 MWmax = 21.2 PPg 4.5 "Tubing 2nd Casing String Size 7 in 7,739 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 Pst Pcollapse85% 4,599 psi Top of Cement 3,961 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax avowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,385 * .052 * 18 ) Pmax allowable - 2,233 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD4-322 CD4-322 x Y Surface Casin Shoe ASP 4 Coordinates NAD 27: 375674.64 5957731.19 ells Details @ AOGCC*' Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ante from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments CD4-16 y 927 376571.7 5957499.3 18.1 2388.5 17.90 Nol for annular disposal, due to proximity to Nanuq 3 CD4-17 900 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 CD4-321,CD4-211 61839 7/3/2006 1/4/2007 2632 378134.12 5956792.58 16.3 2440.26 14.4 volume extension to 70000 bbl, permit #306-266 CD4-209 y 2295 377935.02 5957333.89 14.7 2376.79 17.5 Not or annular disposal CD4-210 y 2024 377547.47 5956963.14 18.0 2385.97 17.3 CD4-211 y 306-392 12/29/2006 D - D - 31937 6/20/2007 7/11/2007 1696 377354.32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test@18.4 ppg CD4-213 y 2110 377441.38 5956577.89 18.1 2400.5 21.40 Nat or annu ar disposal. High Ann test Probably ice plug, will retest if needed CD4-214 y 1553 377016.49 5956949.56 17.3 2400.8 17.6 Not or annular disposal CD4-215 y 1360 376762.06 5956914.11 17.6 2400.4 17.50 Not or annular disposal CD4-302 y 307-257 9/6/2007 3589 379247.67 5957393.4 18.1 2390.43 17.10 CD4-306 y 307-258 9/6/2007 1628 377262.19 5958093.22 18.0 2376.29 14.90 CD4-318 y 306-181 512612006 D - D - 942 5/31/2006 8/2/2006 1497 376138.31 5956308.17 18.2 2375.32 17.1 nab a to pump- D pumping CD4-319 y 305-373 121912005 D - D - D - , CD4-320 32010 12/14/2005 7/2/2006 2453 377174.72 5955790.44 18.4 2396.47 16.1 CD4-320 y 2272 377915.36 5958108.91 17.1 2387.33 17.8 Not or annular disposal CD4-321 y 306-393 1/2/2007 31117 7/14/2007 8/20/2007 795 375795.28 5956945.38 18.0 2385.47 16.3 CD4-322 n 0 375674.64 5957731.19 18.0 2385.44 16.8 Nanuk 1 n Exploration P&A'd Nanuk 2 n Exploration P&A'd Nanuq 3 y 1383 377015.63 5957391.42 11.8 1774.97 Exploration, X-Y location calculated at 2 ' ND, N T the surface shoe depth Nanuq 5 y 3042 378326.61 5956241.68 14.9 2393.75 15.1 Not for annular disposal Nanu 3 2400" ND 896 376499.3 5957380.8 To show roximit to Nanuq 3 at 2400' TVD Lateral distance in feet, between surface casing shoes, in the X-Y plane '" As of September 10, 2007 Note that this sheet is not the definitive record for annular disposal volumes ._~~ o ~,.., a a~ o ~_ ~ M b a~- N q7 A I N ~ V Z_ O I • Q j A mlo _~~ 3 (el c+wuow(-)vmos Operator. ConocoPhilips Alaska Inc. Gdd CertecHon: -0.93 Job No: Fi.ld: CoMlla River Unit Mayn.Hc OadnaMon: 22.52 AFE Ne: CD4-322 All No: WaH Dlp: py; IN/A Doyley per 100 ff Coordkiafe (NE) R.ler.nc.: Sada<e Lacalon Odplnd VS Plana: 274.60 Parani Wek %: 377766.39 ft View VS Plane: 274.60 R%1 N.IyM: Y: 5957128.10 II UnH Syslem: Plan View M n V n ~ f~ ~O t~ n n CO n (+~ c'7 M M M M S C z 4N/A IN/A iN/A Meon Sea Level CDC-322 55.73 H API Based /FPS Surface C sing 1/~ Miie O^ ~y~O~ n~ ~V~/ G~ ~ R ' 3~1~ ~ ~ "~ acJQ GQD~ 4~~0~ G O GO~ti3 a ~. a~~Qo~ o~ o _~. O~ G ~y V Owes Ow4 O G G O~ `L ~,~g O~4 G ~ GO ~~ yg h East (+) /West (-) Comments: 5959000 5958000 5957000 5956000 Plan View Page 1 of 1 (CD4-322 Toolbox.xls) 9/17/2007 2:45 PM ConocoPhilli s p Casing Detail 9 5/8" Surface Casin_g Well: CD4322 Date: 7/30/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.20 FMC Gen V Hanger 2.18 36.20 Jts 3 to 92 90 Jts 9-5/8" 40# L-80 BTC Csg 3461.08 38.38 Halliburton Float Collar 1.26 3499.46 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.58 3500.72 Ray Oil Tools "Silver Bullet" Float Shoe 2.20 3578.30 3580.50 TD 12 1/4" Surface Hole 3590.24 12 1/4" hole - 3590' MD 2388.6' TVD 9 5/8" csg shoe - 3580.24' MD 2385.2' TVD TOTAL BOWSPRING CENTRALIZERS - 53 1 per jt on Jt #1 - #13 (stop ring on Jt #1 8~ 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, 69,71,73,75,77,79,81,83,85,87,89,90 98 joints in the pipe shed. 92 jts to run -Last 6 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque - 8600 ft/Ibs Remarks: Up Wt - 200 k Dn Wt - 125 k Block Wt - 75k Supervisor: D. Mickey/N. Woods ~~ ~ Cement Detail Report CD4-322 Surface Casing Cement Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud ! KO Date End Date DRILLING ORIGINAL DRILLING WCC.WAS.0858.14.01 7/26/2007 7/27/2007 8/22/2007 Cement Details Description Gementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 7/30/2007 22:00 7/31/2007 00:30 CD4-322 Comment Cement 9 5/8" csg as follows: Pumped 40 bbls Biozan water w/nut plug as marker w/ rig pump -Switched over to Dowell -Pumped 5 bbls water -Test lines to 4000 psi -Dropped btm plug -Mixed & pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped Lead slurry (Arcticset Lite) @ 10.7 ppg -Observed nut plug marker @ shakers w/ 404 bbls lead slurry pumped -Pumped down surge can (pumped 419 bbls total lead) -Mixed & pumped tail slurry (Class G w/ additives) 49 bbls @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ dowell -switched to rig pumps & displaced w/ 245 BBLS of 9.8 ppg mud. Continue displacing cement with a total of 245 bbls 9.8 ppg mud pumped @ 6 bpm, 590 psi. Slowed rate to 3 bpm, 450 psi -plug bumped at 2425 sks. FCP 990 psi. Total of 200 bbls cement to surface. Check floats - OK. ;Cement Stages - - - _ i - - ;Sta e # <Sta a Number?> _ Description Objective Top (ftK6) Bottom (ftK6) Ful rn? Gmnt Rtm (... Top Plug? Btm Piuy? Surface Casing Cement 36.0 3,580.0 ~ No 200.0 Yes Yes 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) 8 5 460.0 990.0 Yes 15.00 No Depth tagged (ftK8) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Fluids & Additives - - _ -_ - __ Fluid -- _- -- - - Fluid Type Fluid Description Estimated Top (ftK8) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbQ Lead Cement 0.0 3,080.0 508 ASL 419.0 '/ Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.63 21.75 10.70 Additives Additive Type Concentration Conc Unit label - _- - - --- Fluid _ _ _ _ Fluid Type Fluid Descripfion Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 3,080.0 3,580.0 235 G 51.0 / Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Report Printed: 9/10/2007 ~ ' Security Level: Development Daily Drilling Report CD4-322 ..,,, Report Number: 5 Rig: DOYON 19 Report Date: 7/30/2007 AFE T,~p.~.-.-._. .- --- --- --- Netvmrk/ID ti_. - - - - Total AFE+Sup -- - ~ X Drilling 7,550,000.00 10190241 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-322 Development NANUQ KUPARUK 3.46 5.0 0.00 3,590.0 3,590.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,366.43 83,600.33 342, 782.43 1,107,374.18 Actual Start Date Origina l Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/26/2007 7/27/2007 25.59 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 3,580.2ftK6 Ops and Depth @ Morning Report 24hr Forecast NU Csg Head & BOPE ROPE Test - PU BHA #2 -Drill 20' new hole -LOT -Displace to LSND Last 24hr Summary Wash down to TD @ 3590' MD - POOH on TT working through tight areas - LD BHA - RU ~ Run 9-5/8" Csg to 3580' MD - Circ & Condition mud -Pumping Cement. General Remarks Weather Head Count 42 deg, NE @ 12 mph, Dense Fog 47.0 ----_ Supervlso~ Tale Don Mickey, Rig Supervisor Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor '.Time Loq ,.,,,, Lnd Dx I~r.: t~-r~ (hia) Phase -- __ __ i I c~c ~ Op Code ~ OcSul_ (~xia j PtJ-T TrblCode Depth Start TzblClass {ftKB) Depth End (ftKB) ~,~:~~,.~,~ 00:00 01:30 1.50 SURFAC DRILL TRIP P 891.0 3,550.0 RIH from 891' to 3550' MD. 01:30 01:45 0.25 SURFAC DRILL TRIP P 3,550.0 3,590.0 Precautionary wash & ream from 3550' to 3590' MD. Stage pumps to 600 gpm with ICP = 2050 psi, 50 RPM, 7500 TRO. 01:45 02:45 1.00 SURFAC DRILL CIRC P 3,590.0 3,550.0 Circulate BU's while recipricating pipe from 3550' to 3590' MD -Pumping at 600 GPM, 1960 psi, 50 RPM, Trq 7000 ft*Ibs. Flow check -Static. 02:45 06:45 4.00 SURFAC DRILL TRIP P 3,550.0 981.0 POOH on TT from 3550' to 981' MD - Hole taking proper fill. Pulled 25k over from 1172' MD to 981' MD- Worked pipe through tight areas. Up Wt 145k, SO Wt 110k. Worked specific area from 856' to 887' continuously hanging up at same spot (pulling 25k over). 06:45 07:30 0.75 SURFAC DRILL CIRC P 981.0 705.0 POOH pumping from 981' to 796' MD - 32spm @ 350 psi - FCP 190psi -Pipe still pulling heavy, work through with 20 rpm, 4000 Trq. RIH clean with no rotary & no pumps to 981' MD - TOOH clean with no pumps to 705' MD. 07:30 07:45 0.25 SURFAC DRILL TRIP P 705.0 1,172.0 RIH from 705' to 1172' MD - Dwn Wt 125k with slight bobbles from 1050' - 1077' and 1120' - 1130' MD (5-10k over) with Wt dropping back to 125k. 07:45 08:00 0.25 SURFAC DRILL TRIP P 1,172.0 886.0 POOH on TT from 1172' to HWDP @ 886' MD -Flow check static. 08:00 09:00 1.00 SURFAC DRILL TRIP P 886.0 168.0 Continue POOH on TT from 886' to 168' MD. 09:00 11:30 2.50 SURFAC DRILL PULD P 168.0 LD Jars, NMFC's -Download MWD - LD MWD -motor & bit. 11:30 12:00 0.50 SURFAC DRILL PULD P LD stab -float sub & XO -Clear floor of BHA tools. 12:00 13:15 1.25 SURFAC CASING RURD P RU csg tongs & equipment to run 9 5/8" casing. Latest BOP Test Data - - - - ---- - - - - -- . ~ Date - - _..---__..-- - - --- Comment Page 1/3 Report Printed: 9/10/2007 i Security Level: Development - ` Daily Drilling Report CD4-322 Report Number: 5 Rig: DOYON 19 Report Date: 7/3012007 __ _ __-_ -. Time Log __ - _ -- - - _ __ _ _ --- St: rt F rd ! rur Tim- De tt ~ tr F~ r Ti - rs) P N T fth ~,~ r I :3 ( ~ ~, k,ro~ r ~c ~ ~~e i .,, p P __ irbi Code Trbi Gaa~ i v ~rxie O Sub-Code / ~~ _- 13:15 13:30 0.25' SURFAC: CASING SFTY P Held pe-job meeting with crew on running casing. 13:30 16:45 3.25 SURFAC CASING. RNCS P 0.0 1,730.0 Run 9 5/8" 40# L-80 MBTC casing as follows: FS (Ray Oil Tools silver bullet) 2 jts csg - FC (Halliburton Super Seal) 2 jts csg (first four connections made up w/ BakerLoc -fill pipe & check floats) 41 jts (45 jts. total in hole) to 1730.57' 16:45 17:30 0.75 SURFAC CASING CIRC P 1,730.0 1,730.0 Establish circ -Circ btms up -Stage pump up to 4 bbllmin @ 210 psi PU wt. 135 SO wt 120 17:30 19:45 2.25 SURFAC CASING RNCS P 1,730.0 3,580.0 Continue running 9 5/8" 40# L-80 MBTC casing f/ 1730' to 3542' (92 jts total in hole) PU FMC fluted hanger & landing jt. - Land fluted hanger on landing ring w/ FS @ 3580' & FC @ 3499' 19:45 20:15 0.50 SURFAC CASING RURD P 3,580.0 3,580.0 RD casing equipment - RU cmt head & lines 20:15 21:45 1.50 SURFAC CEMENT CIRC P 3,580.0 3,580.0 Establish circ -Circ & condition for cmt job -Staging pump up to 6 bbls/min FCP 350 psi 21:45 22:00 0.25 SURFAC CEMENT SFTY P 3,580.0 3,580.0 Held pre-job meeting w/ crew on cementing 9 5!8" csg (continue circualting ) 22:00 00:00 2.00 SURFAC CEMENT DISP P 3,580.0 3,580.0 Cement 9 518" csg as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pump -Switched over to Dowell -Pumped 5 bbls water -Test lines to 4000 psi -Dropped btm plug - Mixed & pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped Lead slurry (Arcticset Lite) @ 10.7 ppg -Observed nut plug marker @ shakers w/ 404 bbls lead slurry pumped -Pumped down surge can (pumped 419 bbls total lead) - Mixed & pumped tail slurry (Class G w/ additives) 49 bbls @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ dowel) - switched to rig pumps & displaced w/ 245 BBLS of 9.8 ppg mud. Mud :Check Data _ _ YPC&I. „ri ~ ~ r i .,m~ I r ~I '~D - HTHPFfIt DensiiyTemp Solids. Con 7,;ze _ Depth (ftKB) Dens (Ib/y +, U ai; f V C,+4c (cp) (Ibf/1DCdt t~` ~ I ~I I t 1 rrt'i I t~' _~„ j r.78T {Ib/bbl) (mL130mrn) pH (°F) (%) Spud Mud 3,590.0 59 20.0 17.000 6.0 5 0 15 00~ 33.0 ~ 9.1 -~--1- ~lnjection Fluid _ ~~ Fl~i.7 Source - - --- From Lease(b63) Destination -- - - N~~r Water Based MuJ ~ ~ 340.0 CD1 19 ,From CD4-322 ___ - ---- I Wellbores _ _ _ _ _ _ --- Wellbore Name ~ Wellbore API/UWI CD4-322 _ 501032055100 Saction Si, e n~ ~ _ _ Act Top(ftKB) _ ~ t Btm ~I~kP.) Start Date End Date CELLAR ~ 96 0.0 4.0 2/26/2007 2/26/2007 COND1 16 0.0 114.0 2/26/2007 2/26/2007 INTRMI 8 3/4 0.0 19,452.0 8/1/2007 8/8/2007 SURFAC 12 1/4 114.0 3,590.0 7/27/2007 7/29/2007 Page 2/3 Report Printed: 9/10/20071 ~~ i~ Daily Drilling Report Security Level: Development CD4-322 Report Number: 5 Rig: DOYON 19 Report Date: 7/30/2007 ~Casin Strin s CasingDescrfptfon RunD~a;~ 00(in) ~~ _ _ WtQbs/ft) Grado D~:~'~ __ _ - fiK.6~ ~ C-mment - _ ___ __ Surface -- - 7/30/2007 9 5/8 40.00 L-80 Run 9 5/8" 40# L-80 MBTC casing as follows: FS 3,580.2 - - - (Ray Oil Tools silver bullet) 2 jts csg - FC (Halliburton Super Seal) 2 jts csg (first four connections made up w/ BakerLoc -fill pipe & check floats) 41 jts (45 jts. total in hole) to 1730.57' - Establish circ - Circ btms up -Stage pump up to 4 bbl/min @ 210 psi PU wt. 135 SO wt 120 -Continue running 9 5/8" 40# L-80 MBTC casing f/ 1730' to 3542' (92 jts total in hole) PU FMC fluted hanger & landing jt. -Land fluted hanger on landing ring w/ FS @ 3580' & FC @ 3499' --- _____ .Cement _ _ _ _ -- - -- -- - - Surface Casin Cement -Started 7/30/2007 Type Wellbore Cemented String Cement Evaluation Results CD4-322 Surface, 3,580.2ftK6 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) Surface Casing Cement 36.0 3,580.0 5 460.0 _ Fluid Class Amount (sacks) ~'. V i 7b1) Densely {Ib/gal) Yield (f{'Isack) Est Top (ftKB)' Est B;ria {ftKB) Lead Cement ASL 508 419.0 10.70 --- 4.63 0.0 3,080.0 Tail Cement G 235 51.0 15.80 1.17 3,080.0 3,580.0 Page 3/3 Report Printed: 9/10/2007 Security Level: Development \ Daily Drilling Report CD4-322 . ~.,~~ Report Number: 6 Rig: DOYON 19 Report Date: 7131/2007 AF=E Type __ - --_ _ Network%II:) ~. ~ - -_ Total AFE+Sup Drilling 10190241 _ _ _ 7,550,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-322 Development NANUO KUPARUK 4.46 6.0 0.00 3,590.0 3,590.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,116.15 86,716.48 240,615.12 1, 347, 989.30 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/26/2007 7/27/2007 25.59 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 3,580.2ftK6 Ops and Depth @ Morning Report 24hr Forecast RIH picking up DP. PU BHA. RIH an d cut Drill Line. Drill Shoetrack + 20'. CBU. FIT. Change mud to LSND. Drill 8.75" hole. Last 24hr Summary Cement 9-5/8" Csg & Test to 3500 psi for 10 mins - ND Riser - NU Csg Head ~ BOPE -Test BOPE. General Remarks Weather Head Count AOGCC Rep Chuck Scheve Waived BOP Test Overcast 47.0 Supervisor Tit3e Dave Burley, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor ,Time Log I Start End Dur Time Depth Start Depth Er 1 Tlme Tme (hrs) Phase Op Code ~~.>Sul ,,,,. F-N-T t t -Je Trt-.I Gass. {ftK8) (ftKB) ~ Or>erahon 00:00 00:30 0.50 SURFAC CEMENT DISP P _ 3,580.0 3,580.0 Continue displacing cement with a total of 245 bbls 9.8 ppg mud pumped @ 6 bpm, 590 psi. Slowed rate to 3 bpm, 450 psi -plug bumped at 2425 sks. FCP 990 psi. Total of 200 bbls cement to surface. Check floats - OK. 00:30 01:30 1.00 SURFAC CASING DHEQ P 3,580.0 0.0 RU and test 9-5/8" Csg to 3500 psi for 30 mins. 01:30 03:00 1.50 SURFAC CASING RURD P 0.0 0.0 Blow down cement lines, RD Cement Head, Lnd Jt, Elevators, and Bales. 03:00 04:00 1.00 SURFAC CASING NUND P 0.0 0.0 ND Surface Riser 04:00 05:30 1.50 SURFAC CASING NUND P 0.0 0.0 Pull speed head -Set Well head and test to 1000 psi. 05:30 10:00 4.50 SURFAC CASING OTHR P 0.0 0.0 Set BOP's - MU Riser -Change lower VBR Rams. 10:00 10:30 0.50 SURFAC CASING OTHR P 0.0 Install wear bushing 10:30 13:30 3.00 SURFAC DRILL OTHR P 0.0 2,850.0 RIH picking up 90 joints of 5" drill pipe 13:30 13:45 0.25 SURFAC DRILL CIRC P 2,850.0 2,850.0 CBU to condition thick mud 13:45 14:30 0.75 SURFAC DRILL OTHR P 2,850.0 0.0 POOH -stand back drill pipe 14:30 16:45 2.25 SURFAC DRILL PULD P 0.0 2,760.0 RIH picking up 87 joints of 5" drill pipe from pipe shed. 16:45 17:45 1.00 SURFAC DRILL TRIP P 2,760.0 0.0 POOH and stood back 5" DP. 17:45 00:00 6.25 SURFAC WELCTL BOPE P 0.0 0.0 Pulled wear bushing and set test plug. Filled stack and tested Hydrill 250/3500 psi. Tested Rams, Choke lines, valves, Kill line, and floor valves to 250/5000 psi. Tested 5" and 7". Tested closing unit. Pulled test plug and reset wear bushing. Mud Check Data -- --- T - ~ ~I ~ TYP'=' L-p~h ittF F1~ Din t , ,I) ~~. b is ^C~ PV r~,lc (cp) YP Calc Qbf/100ft~) (I Gt.l {10s} Gel (16m) Gel (3vrnJ aN'IOOtt~ Qbfll DOfts) (Ibf/10Dft~) MBT HTHP Flt nee jai - T~rn~' ddo r,~~-r ! {Ib/b~•.'.~ (m1J30min) '. pH '. 'Fi ,,.~ - - - Spud Mud ~ 3,590 ~ ~- 5~ 20.0 - 17.000 ---- 6.0 5.0 15.000 - _ - 33.0 ~ 5.1 In'ection Fluid - - Fluid Other Suu ~ ' t ~ F -i~ Le ac a 920.0 CD1-19 i dily I'~ vie same Water Based Mud 1350.0 CD1-19 From CD4-322 Latest BOP Test Data C~ - 1 ~ Comment Page 1/2 Report Printed: 9/10/2007 i ' Security Level: Development Daily Drilling Report CD4-322 Report Number: 6 Rig: DOYON 19 Report Date: 7131/2007 ---_ - - _ _ Weilbores -- - -- Wellbore Name _ __ Wellbore API/UWI CD4-322 I 501032055100 Section Sze (kn) Act i ~~, ti h:B~~ Act Btm (ftKB~ Start Date End Date CELLAR 96 0.0 4.0 2/26/2007 2/26/2007 COND1 16 0.0 114.0 2/26!2007 2/26/2007 INTRM1 8 3/4 0.0 19,452.0 8/1/2007 8/8/2007 SURFAC 12 1/4 114.0 3,590.0 7/27/2007 7/29/2007 ~I I i I Page 2/2 Report Printed: 9/10/2007 Well Name: CD4-322 Rig: Drilling Supervisor: Mickey /Woods Type Of Test: OpenholeTest LOT/FIT HOIe Slze: USE PICK LIST ~ Casin Shoe Dept RKB-CHF: 36.7 Ft 3580.0 Ft-MD 2385.0 F Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC Casin Test Mud Weight: 9.9 ppg ~ PP9 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 21.0 Lb/100 Ft2 Test Pressure: 3500.0 psi Rotating Weight: #~ Lbs Rotating Weight: 74000.0 Lbs Blocks/Top Drive Weight: 74000.0 Lbs Blocks/Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 3.6 bbls Estimates for Test: 1017 psi 1 bbls - r I~ -- _ - FMW = 1 oa~_off Pressure + Mud Weight = 1020 PIT 15 Secc^~+ 0.052 x TVD EMW at 3580 Ft-MD w: o: ~ - rn w a 0.052 x 2385 + 9.8 Shut-in Pressu Ft-ND) = 18.0 _p1~~ 1000 Lost 40 psi during test, held 98.9% of test pressure. 161 1 Pump Rate: 8.00, Strk/min ~ re Inte rity Test Sh ut-in si Min psi 0 0.00 1020 40 0.25 1000 110 0.50 990 170 1.00 950 220 1.50 92 300 2.00 920 400 2.50 910 500 3.00 900 580 3.50 890 1900 15 3480 11 800 5.00 880 2100 20 3460 12 ~' 870 5.50 870 2275 25 3460 13 910 6.00 870 2450 30 3460 14 v 940 6.50 870 2650 15 990 7.00 870 0 5 10 15 20 25 30 barrels Shut-In time, Minutes VOlume VOlume VOlume Volume ~~CASING TEST f LEAK-OFF TEST O PIT Point Pum ed Bled Back Pum ed Bled Back s s s s Tested 9 5/8" csg after bumping plug on cmt. Job PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 8/1/2007 Volume Input Volume/Stroke Pump used: #2 Mud Pump ~ - .-- - Strokes ~ 0.1000 Bbls/Strk ~ ~ Pumping down annulus and ~P. ~ Casin Test P h Hole Depth Pumping Shut-in Pi Summary • Cfl V 0 C0 V N O O ao 0 ~ ~ t1 M N ~ ~ 0 0 0O f~ (D ` N 0 0 0 G% 0 0 a0 ' Cp CO CO CD CO O a0 CO 00 aD ~ t` ~ f Y a O 0 ~ ~ ~ to ~ t! ) ~ ~ to ~ lf? ~ l17 ~ to ~ ~ to ~ tC) N M .~ ~ dr I- 7 ~ m a td ~ t O to ~ ~ In N In M In ~ Ln ~f? ~ CO to I~ to CO to 0 t1~ 0 ; G1 D ~ . ~ O O N M ~ t0 CO f~ CO 0 ~ m . ` ~ E 3 m d ~' d ~ = to r O O ~ N ~ M a0 M a0 O ~ aD ti CD CO CD CD CO (O CO O y . N ~n v ~' ~n N V r O N ~n ~ ~ O CO ~ M M M M N N N ~ N In O CD CO CO I~ n ~ CO 00 CO CO r- CO (D (O (O CO (O CO (D t0 CO c Q- E °' ~ Q ~ ~ ~ N O N ~ (O a0 r N ~ CO CO N to M ln `7 Ln ll') ln (O ~A f~ 1(~ O p ~ ' a ~ ~ o o A o ~ ~ r- ~ R+ ri v ui co I~ > a m V1 Y ~ Q d V C l 0 E m ' m 7 t O r^ N M ~ IA CO f~ 00 0 0 lI') O N O 'p N ~ C ,_ ~ d M c c , V ~ '~ °- ~ a ~ ~ o ~ ~' ~ m > ~ -- V) t~ ~o ' ' ?~ , N ~ ' o, W C O N F- tO O ~p C ~ ' Y N ~ O d~ ~ ~ H !C o c ' ~ ~ _ 0 ~ ~ O w/ ~ I ` vi C. ~ M . M a 0 ~ d c O (7 LV ~ ~ c A m d H u ti o ti o co ~ ° ~ d ~ Z J ~ ~ C w 'L N - ~ C LL m W = d ~ p ~ L ~ ~ h ~ a ~ ~ ' ~ °O d .~o ~ d ~ :T w ~ ~ V a a E ~ ~' 3 .S ~ `~ ~ ° r N O Z ~, a ' ~ ~~ a,n ~ + W a . ~ ~ O N ~' O O N ~ p ~, ~n ~ Q ~ W ~ r x II , d ~~,.~ OCU ~ `N ~..~ ~ ~ o N ~ ~ o r O v ~ ~ ~ J O ~ ~ C ~ ~ ~ ~ C ~ V O y N ~ I~ ~ w t~C7 ~ Q1 0 O .C C L O ~ M V C U U C ~ C • N H ~ - C _O ~ ' d ~ 3 ~ • Q D J ~ LL ~ ~ + M U ~ C J Y ~ M 0 ~ ~ 7 0~ 7 p_ 01 0 0 V ®~ ~ ~ Q ( j l0 C Q O ~ ~ N O O ~ ~ K ~ a v p N ` CC I L ~ Y~l m twit ~ N ~ ~ C N p ~ ~ ~ ~_ ~ tL ~ ~ C o W ~~ w LL ~ ~ L ~ C) O m O A d O = C c y ~ ~ Y d 3 fn ~ y UU m •l~6 L U .~O ~~ ~ y ~. N H A J ~ E e6 = F' N ~ Y ~= U U e ce .~ w 'O ~- v II Z rn O a? 3 3p NEW O - ~ W 0 2 O 3anss~~d as E r a r ~ O ~ ~ ` C ~ O ~ a; a E ~~ ~ ~ 3 ~ a ~ ~; m a~ ~ ~ U w O O o ~ ~ ` ~ Y . ~ ~ N 0 W C CO ~ ~ ~ (6 u. ~ ~ ~ b~ o O ~ N Y ~' ~. a ~ ~ 4 ~ J ; -p ~ C) w O ~ ~ N O (6 ~ -fl V"' ~ ~ O a. ~, ,~ H ~ 3 ~ a-°i ~ ~ o w c v w I- ~ C a~ 7 v ~ .ro w ~ v N Z U •~ U u' N ~ 0 to I~ O h O C ~ c ~ ~ ~ Casing Detail Well: CD4-322 ConOGOPhillips 7" Casin_p Date: 08/12/07 Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.15 FMC Gent/ Hanger 2.34 34.15 Jts 235 to 452 218 Jts 7" 2ti# L-80 BTCM Csg 9362.03 36.49 Tam Port Collar 2.12 9398.52 Jts 3 to 234 232 Jts 7" 26# L-80 BTCM Csg 9947.22 9400.64 Halliburton Float Collar 1.04 19347.86 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.44 19348.90 Ray Oil Tools "Silver Bullet "Float Shoe 2.21 19434.34 7" Shoe @ 19436.55 8 3/4" hole @ 19,452' 8-3/4" Hole TD @ 19,452' MD / 7,739 TVD 7" Shoe @ 19,436.55' MD / 7,728 'TVD Total Centralizers: 68 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts.233 to 236 Straight blade cent. one per jt. on joint #'s 241 - 247 Straight blade cent. one per jt. on joint #'s 368,369,370 Straight blade cent.one on every other jt.# 372 to 450 490 joints in shed - 452 total jts. to run Last 38 jts. Out Use Run & Seal i e do e Average make up torque 8000 ft/Ibs Supervisor: Lutrick /Hill Page 1 r _-~ ~ Cement Detail Report CD4-322 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING WCC.WAS.0858.14.01 7/26/2007 7/27/2007 8/22/2007 '~Cement Details --_ - - --- ___ _-- Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 8/12/2007 08:00 8/12/2007 11:10 CD4-322 Comment Dowell pumped 5 bbls CW-100. Tested lines to 3700 psi. Pumped 25 bbls CW-100, 40 bbls 12.5 MudPush, Dropped bottom plug, Pumped 30 bbls 11 ppg lead cement (42 sx), 37 bbls 15.8 ppg cement (177 sx), Dropped top plug and pumped 5 bbls fresh water. Rig pumped 40 bbls inhibited 9.6 brine followed by 689 bbls 9.6 brine. Bumped plug. Had flow out annulus. Shut well in. CementSta es __ -- - -- - - - - - --- Stage # 1 _________-- Description Objective Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Primary 17,922.0 19,436.0 Yes Yes Yes Cement Q (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) R 'p? Stroke (ft) Rotated? Pipe RPM (rpm) 5 4 5 900.0 1,500.0 No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out B) Drill Out Diameter (in) Comment .Cement Fluids 8 Additives iFluid Fluid Type Lead Cement Fluid Description Estimated Top (ftK6) 17,922.0 Est Btm (ftK6) 17,121.0 Amount (sacks) 50 Class G Volu umptd (bbl) 30.0 Yield (ft'/sack) 3.37 Mix H2O Ratio (gal/sa... 11.29 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cp) Thickening Time (hrs) Cmp Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amoun[ (sacks) Class Volu ped ( bl) Tail Cement 17,121.0 19,436.0 177 G 37.0 Yield (ft /sack) 1.16 Mix H2O Ratio (gal/sa... 5.07 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) Cmp 7 s" Additives Additive Type Concentration Conc Unit label (Stage # 2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? - Cmnt Rtrn (... Top Plug? - - Btm Plug? Intermediate Casing 2nd stage K-2 8,390.0 9,398.0 Yes Yes 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) 5 3 4 700.0 1,400.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives - _ _ - -- - --- - -- Fluid ' - Fluid Type -- - Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class --- Volume Pumped (bbl) Intermediate Cement 8,390.0 9,398.0 190 G 40.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label - Report Printed: 9/10/2007 ~~ -` Security Level: Development Daily Drilling Report CD4-322 Report Number: 18 Rig: DOYON 19 Report Date: 8/12/2007 Af'E Typ~_ NehvorkllG k' Total AFE+Sup -J - -- f Drilling - - - - -- 10190241 -- - --- 7,550,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-322 Development NANUO KUPARUK 16.46 18.0 0.00 19,452.0 19,452.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 7,802.60 648,198.29 604,996.60 4,696,052.11 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7!26/2007 7/27/2007 25.59 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 19,436.6ftK6 Ops and Depth ~ Morning Report 24hr Forecast RIH w/ combo tool on 4" DP Cement 2nd stage. LD 4" DP. RIH w/ 4 1/2" completion equipment. Last 24hr Summary RIH w/ 7" csg to 19,436'. Cement and test csg. RIH w/ combo tool on 4" DP. General Remarks Weather Head Count 49" - SW @ 12 mph - Vis 10 mi -Clear 49.0 Supervis_,r Titie Donnie Lutrick, Rig Supervisor Rig Supervisor Larry Hill, Riq Supervisor Rig Supefvisor Time Lo Start End I [7 ~,i i Time Time ~ (hrs) ~ Phase ~ I Op Code OpSub-Code F- ;r~c i i i h ~fa~ ' Depth End {'~-T '. Trbl Code Trbl Class. '1n~~1 IhKB) - -,~~on 00:00 01:15 1.25 PROD1 CASING CIRC P 17,375.0 17,375.0 Circ. and cond mud. Stage pump to 4.5 bpm, 620 psi, Up wt 330k - Dn wt 145k 01:15 04:30 3.25 PROD1 CASING RNCS P 17,375.0 19,436.0 Cont. to RIH w/ 7" casing from 17375' and landed out at 19436'. 04:30 05:00 0.50 PROD1 CEMENT RURD P 19,436.0 19,436.0 UD Franks fill-up tool. Blowdown TD, R/U cement equip. 05:00 07:30 2.50 PROD1 CEMENT CIRC P 19,436.0 19,436.0 Est. Circ. Circ and cond. for cement job. Stage pump to 4.5 bpm at 610 psi. 07:30 07:45 0.25 PROD1 CEMENT SFTY P 19,436.0 19,436.0 PJSM 07:45 11:15 3.50 PROD1 CEMENT SFEO P 19,436.0 19,436.0 Dowell pumped 5 bbls CW-100. Tested lines to 3700 psi. Pumped 25 bbls CW-100, 40 bbls 12.5 MudPush, Dropped bottom plug, Pumped 30 bbls 11 ppg lead cement (42 sx), 37 bbls 15.8 ppg cement (177 sx), Dropped top plug and pumped 5 bbls fresh water. Rig pumped 40 bbls inhibited 9.6 brine followed by 689 bbls 9.6 brine. Bumped plug. Had flow out annulus. Shut well in. 11:15 11:30 0.25 PROD1 CEMENT OTHR P 19,436.0 19,436.0 Bled off pressure. Checked float equip. OK. 11:30 12:30 1.00 PROD1 CASING DHEQ P 19,436.0 19,436.0 RU and test casing to 3500 psi for 30 min. 12:30 13:30 1.00 PROD1 CASING RURD P 19,436.0 19,436.0 Bleed off pressure. Check floats. OK. Annulus pressure - 0 psi. Open well. Static. RD cement head and csg equipment. Blow down choke. 13:30 14:30 1.00 PROD1 CASING DHEQ P 0.0 0.0 Pull thin wear bushing. Install pack-off and test to 5000 psi. 14:30 15:15 0.75 PROD1 CASING RURD P 0.0 0.0 LD long bails. RU short bails. 15:15 16:45 1.50 PROD1 RIGMNT SVRG P 0.0 0.0 PJSM. Slip and cut 120' drilling line. Service top drive. 16:45 00:00 7.25 PROD1 CEMENT TRIP P 0.0 4,303.0 PU and RIH Tam Combo Tool and 4" DP to 4303'. Latest BOP Test Data I- a~.- Gnmment 8/1 /2007 250/350015000 Page 1/2 Report Printed: 9/10/2007 Security Level: Development Daily Drilling Report CD4-322 Report Number: 18 Rig: DOYON 19 Report Date: 8/12/2007 !Mud Check Data ---, YN Csl. gel 7~,s~ _, I 7":m. C~ ~-, i ~ ~ H1 H i. r F'~- U~n~it. T~~n;~ b ':o~~. ~p:, I , tt ` ~: Type OeNuS (S hG) '~ Geno tlolyat) Vim ici-f ~ Pv i.e,c c .. ~~Jf. , NaCI KCL 19,525.0 ~ ~ ~ ~ ~ ~ ~ ~ r l ~ ~ i-ci-.1 -. , ~ ~ - _ _ _ _~_ --- - 1 - ~Injection Fluid - - -- -- - - Flur; source .From Lease (bbl D-=~inatior > Note Diesel Water 45.0 150.0 From CD4-322 to 321 Same Water Based Mud _ _ 2161.0 Same Weilbores Ibore Name ~Wellbore API/UWI -- - -- ~ CD4 322 5010320551 G0 ..- ~ ri - - - Size (m; Act Top (f3K6) ~ Aot Btm (ftKB) -- ~_ Sfarf Date ~ f ~ li:,te CELLAR 96 0.0 4.0 2/26/Z007 2/26/2007 COND1 16 0.0 114.0 2/26/2007 2/26/2007 INTRM1 8 3/4 0.0 19, 452.0 8/1/2007 8/8/2007 SURFAC 12 1/4 114.0 3, 590.0 7/27/2007 7/29/2007 _ Surve Data - - MD (ftKB- -- I ~~ ~ -- - Azm ~T` ~ ~,nhB) VS (ft) ~ "~ h5 ~~ I ~., C ~ 5 ,.~' ~ 19 452.00 44.94 271 0 , %.739.24 17,016.12 1,342.73 16,963-08 0.00 - - Casmg Strin~_ __ _ - - - - - ---- - Casing D~ rr ti ~~ Intermediate r~ ,~ L ~t. ~ ~ - ~ ~ , n ,'J~il '~ 1-: L~ ;, i d~12,200i ~ `'h 00 L-80 1 ~ rth C ~ __ 9 4.6 6 ~'~-mmen_c !Cement Intermediate Casin Cement - Started 8!12/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD4-322 Intermediate, 19,436.6ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 17,922.0 19,436.0 4 900.0 -- Fluid _ -- I Amount {sar•;cl J i tb1) Densu is ,. ti e-.i ~fi ,-;crQ Est Top (ftKB) Est Btm (ftKB) __ Lead Cement --- 50 - - - G 30.0 11.00 ---- 3.37 - 17,922.0 17,121.0 Tail Cement G 177 37.0 15.80 1.16 17,121.0 19,436.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 2 Intermediate Casin g Cement 8,390.0 9,398.0 3 700.0 r~ Fluid ~~ _ ~ ,;;~sa Arr>We~t (saw,,,, ~ :. l bblj Dens ate, Y,eld{fNlsack) Est Top {ftKB) .. Est BYm (ftKB) _ Intermediate Cement _ G 190 40.0 15.80 _ J 1.17 8,390.0 9,398.0 IIII----Pressure Test Data Item Tested Leta Pres (psiJ F , -,. i ~o.,, Intermediate, 19,436.6ftKB 8/12/2007 3,500.0 No 3500 for 30 min Page 2/2 Report Printed: 9/10!2007 r~ r1 Daily Drilling Report Security Level: Development CD4-322 ,~ ,~,~ Report Number: 19 Rig: DOYON 19 Report Date: 8/13/2007 __ _ -- -_ AFE Type NetworkllD # Iaal AFE+Sup Unlling 10190241 7,550,t~00.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-322 Development NANUQ KUPARUK 17.46 19.0 0.00 19,452.0 19,452.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 33, 513:94 681,712.23 219,911.94 4,915,964.05 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/26/2007 7/27/2007 25.59 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 19,436.6ftK6 Ops and Depth @ Morning Report 24hr Forecast RIH w/ 4 1/2" Completion Equipm ent RIH w/ 4 1/2" co mpletion equipment Last 24hr Summary RIH w/ combo tool. Perform 2nd stage .cement job. POH LD 4" DP. General Remarks Weather Head Count 51?-SW@9mph-Vis 10mi-OVC 51.0 __ Supervisor TBIe Donnie Lutrick, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor ~Riy Supervisor Time Lo Start End ;Jw _ __ -- - _ __ - I _ _ - r-ie Oepth Start D~~th End lime Time nrs) Phase i Op Code OpSub-Code ~- {'~-~ Trbl Code Tr61 Class- (fib) (nKB) ~ Uperat~on 00:00 06:15 6.25 PROD1 CEMENT PULD P 4,303.0 9,330.0 RIH Tam Combo Tool on 4" DP from 4,303' to 9,330' picking up DP from pipe shed. 06:15 08:30 2.25 PROD1 CEMENT PULD P 9,330.0 9,398.0 Located Tam Port Collar @ 9,398' and spaced out with pups. 08:30 09:15 0.75 PROD1 CEMENT RURD P 9,398.0 9,398.0 Rigged up Plug Drop Head and cement lines. PJSM. 09:15 10:15 1.00 PROD1 CEMENT OTHR P 9,398.0 9,398.0 Established circulation, dropped ball and displaced to seat pressured up to 800 psi. 10:15 12:00 1.75 PROD1 CEMENT OTHR P 9,398.0 9,398.0 Bled pressure to 200 psi and shifted Port Collat to open position. Cups lost pressure and would not re engage. 12:00 13:30 1.50 PROD1 CEMENT DISP P 9,398.0 9,398.0 Dowell pumped 5 bbls CW100. Tested lines to 3500 psi. pumped 20 Bbls CW 100 .Pumped 40 bbls 12.5 ppg MudPush, 41 bbls 15.8 cement (190 sx), drop closing dart, 20 bbls water followed by 57.9 bbls mud. CIP @ 1328 Hrs. 13:30 14:15 0.75 PROD1 CEMENT CIRC P 9,398.0 9,398.0 Closed Tam Port Collar with Bag closed. Tested to 2000psi. Reversed out 110 Bbls @ 4.5 BPM 950 psi. 14:15 14:45 0.50 PROD1 CEMENT OTHR P 9,398.0 9,490.0 Rigged down and laid down Baker plug dropping head. RIH 1 stand to 9,490'. 14:45 15:15 0.50 PROD1 CEMENT CIRC P 9,490.0 9,490.0 Sheared out choke with 2900 psi. Reverse circulated 100 Bbls. No cement. 15:15 15:45 0.50 PROD1 CEMENT TRIP P 9,490.0 9,365.0 POOH to 9,365' laying down 4" DP and pups. 15:45 16:30 0.75 PROD1 CEMENT OTHR P 9,365.0 9,365.0 Rigged up and tested casing to 3500 psi. Blew down lines. 16:30 00:00 7.50 PROD1 CEMENT TRIP P 9,365.0 315.0 POOH laying down 4" DP to 315' Injection Fluid _- -- - -- _ Diesel , ~ -- ___ _ -_ 30.0'. --- .From CD4-322 to X21 I -- _ -- - Wellbores --- _ _ _ Wellbore Name Wellbore API/UWI CD4-322 501032055100 Latest BOP Test Data Date Comment ___- 8i 1 12007 250/3500/5000 --- Page 1/2 Report Printed: 9/10/2007 r~ ~`~~ Daily Drilling Report Security Level: Development CD4-322 ,..~ Report Number: 19 Rig: DOYON 19 Report Date: 8/13/2007 --- ---- Section _ CELLAR Size (in) 96 --- 4:.t itRLi Hal Btm (ftKB) 0.0 4.0 2/26/2007 i ~tc~ End DatE~ 2/26/2007 COND1 16 0.0 114.0 2/26/2007 2/26/2007 INTRMI 8 3/4 0.0 19,452.0 8/1/2007 8/8/2007 SURFAC 12 1/4 114.0 3,590.0 7/27/2007 7/29/2007 Survey Data _ _ MD (ftK$) i ,_ P,zrn ~. _ A'll hC~ JS ifri I NS ;':, rN.'itti ~ DLS ~-1 ,K 19,452.00 44.94 271.83 7,739.24 17,016.12 1,342.73 -16,963.08 0.00 Page 2/2 Report Printed: 9/10/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-322 Rig: Doyon 19 Date: 8/13/2007 Volume Input Pum Rate: Drilling Supervisor: Lutrick /Hill Pump used: Cement unit ~ Barrels ~ 1.0000' Bbls/strk ~ , 0.80 Bbl/min ~ , Type Of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In te rit Test Hole Size: 9-~/$" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 34.7 Ft 3580.0 Ft-MD 2385.0 Ft-TVD 8400.0 Ft-MD 3970.0 Ft-TVD Bbls si Min si Bbls si Min si Casing Size and Description: 9-s/8" 40#/Ft L-80 BTC ~ O 0 0 0.00 860 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 1 180. 0.25 791 Enter outer casing shoe test results in comments Mud Weight: 10.0 ppg 2 2 250 0.50 771 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 3 318 1.00 750 Hole Size is that drilled below outer casing. 4 4 382 1.50 73 Use estimated TOC for Hole Depth. 5 5 445 2.00 720 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 6 500 2.50 710 Estimates for Test: 620 si 0.8 bbls 7 7 547 3.00 700 ~ ~ 8 8 598 3.50 690 EMW =Leak-off Pressure + Mud Weight = 840 PIT 15 Second 9 9 654 4.00 682 + 10 0.052 x TVD 0.052 x 2385 Shut-in Pressure, si 10 10 696 4.50 672 EMW at 3580 Ft-MD (2385 Ft-TVD) = 16.8 791 15 11 740 5.00 663 ~ooo 20 12 786 50 5 658 -- . ~. ~~~ C1~`{ Y-1 25 13 829 6.00 653 30 14 861 6.50 646 ~ 15 879 7.00 642 _ 16 ,~ 874 7.50 637 17 872 8 00 633 . ~ 8.50 630 j ~ .. 9.00 627 ~ 9.50 62 N eoo w ` 10.00 61 . a 0 o z a s s i o , z , a i s , a o s , 0 1 5 2 0 2 e so ~~ CASIN G TEST Ba rrels -aL EAK-OF F TEST S hut- O P In tim IT Poin e, M t inute s Vol PUm ume ed Volume Bled Back Volume PUm ed Volume Bled Back s s s s Comments: 9 5/8" casing shoe PIT = 18.0 ppg V LJY-JLG /`11111UIQI LV I Summary _.. To:~ arid ~hartnon , Yeti. h~ce rec~~~tm_d ~o dispose of "n~i+t-~rc,c~ucG" c" dun t:Y~ fluids fram tho' routine taixint; c•~f nu.d acid cement cat ,~:Lpir.e as o:cll a^~ the cleat uf~ firzids reaztitng ~rc~tri rl~anzng €~ttt tha ~ta~1'.-~s at the mud ~;1~rC in pee_r~arcZtla>i tcrr u:,inq oi? base ~3ud, ~rr.e Cc>>;:iriissiUi kSara pxeva.c}us~:~;! r:pY?rovcd ciispo:-~z.ng ~~f tY:e °nevr frrcic~tct'" t~l~cAn <tp L1t-rlcis vi.s3 `ar:ntzlar disposal at CD t pad. Dire to the geolo<~ical ser~i-iris _it ;.lpine, C7.afi~ 1 and f'3a~s 'L di~posa? UptiCrTIS ire lit^ited. i'h11 ips' px;:sdeco son, ~Rt~.C}, rid est~;Y.rlis}lets the ,1 im.tat ion of ai.^>po~al v~tior:s tU the Co:~tnis;}ion's s~'rts~arr,on ar;cl anr_ular dis~c,sal eras ~tppzc>u~d ~ the nr:act~it-al and enti~iroruaentaZ alterna~_ve. Ir these rr~guests the v:a1tH fluids axe no di f~:ret:t t2:~n _~reviou~~y. ap~aX`a~ed atsd ,=irc~ ::h.. r~-:salt o` tree ongoing de~relnpnteri'~ act'xva.:ins at xl}jXn~- The CC,rttr~,issioners have aueYrarS tea me r_t~ .;end yoga this nt=~t~sage. By copy. cal` hs er:Gil . Phillips is 2.u.Lho~izc~d, ~C} c~i,sp~S~ c>f r, 1e$t7~ ttp fluid.: as descrik3Gd xx your r~^z i 1 , Plea:;p cell v~iLh arty rluesta.ors- Tcrm ~Taundr.r. , UE Sr. Petrr,leuttt Eri~,ii:eer Y.c~cc r~'.i,P ;;n~~ C'c:~rd wr_~s'G~ > D~a-~ GIs`. tiatznder< > 2~r; noted i:t the Cttae:zed email.. Tarn t`azison pYevi"ousl~~ requester3 av.4iiori~.atic~n to disposo cf nevr-product cleat a~ f=ttids such as cement rinsate, and twuci and, br:'ire X.yit ruses fx«ttr mixing cipr-_ratians ria anniil~tr :> inec:rtiotz ir. pexmtt~a v:ell_s at tY?e Alpine CDC Ltrill Side. r~ti noted brloti~r; i AoC;{'C a}~provecl such disposal at the Cn1 gill SzG-e i.n 1995, hasec ora tnc integral relationship of CY~e mud maxi-nq L-acil.~:~y and ttz~ on-site drilling ~ opez~nr..crn_ > Phillips k:oul~l I_i.l;e to continuing ~u>:stt.g t'-iis req~se~t. Significant: Glean > r}utr of tasks at the mud mixing fac,ilit~~ must occur in prepaxaGion I~ox the > tc~:;tporary usc~ of oil }3ased rnuc~ prorauc:ts at alpine ^n tl~,e coming tnanths. ^he availability of anrYulax clzsposal as an crptan for tank rime fluids and ~ sirtilax wastes .aot;ld gxe~atly >=zcilita;~c this groc~ss, t`PYhichlly, rout>ne rinses arc ht_r_e~iciallir reused, hcrvever, there is aCOt~~BYn a~at~t tht? > patentia c>~ant'ity of fluid t2i~t could be generated du*_-ing tl-:i, large'scale > cyan up pxoress.} J > Tanks at-. the rn~d mixing facilityy contain either neW ar=d ~issd mud > products. Thaug:l rinses in _cont~ct-T~rith used pz-oduc~s maw ~c inj>'~ted in. > the permitted. class Il dis?os~l tell ~Ch1Qi~? , rinses -af n~~r~ ~raducts. v;ould > r~~;:~entally :oe zot:te~ to the class ~ i3isposa? s.rell (tit~_{}2} , vrher~ there is ~'t di L i citl ty ::~ararng solids content _ The class I ~h'e~11 is a critical > litel.ine for facility infrast±ucture, kseirrg the disposal. ]ocatc?n for all > dotnc~stic effluent, anci it i° a proxit:y Lo pxpvenc anlr comp~omis~ to t~is > disposal faCilit,y. annular dispC~sal_ rtr~sent~s a pro£er~ed :paste m~nagets~t_ alternatiti~e ir_ thiscase - a • • ..-•~;,, Ti~ank tau ~re~`Y much for your carisicieration +~~ th%s request _ ?l caste dc~ not l~:esitat~ try contact fne czr ms~ d1l:e~naCe -,pia email car gone at (~ID7} X70=~2~3€5 iz yc'~u Yra~,~e c~zest.ac~n~ c~~ nao~l ~d~iS.;.onal inf~~-cctati4rl. I'z~~nr_on Donnelly > A,_pire ?ie=c< ErzvilflnznenLal ~oo~-diriatar t4~?} X70-F20G > ..____ Ft~r.~.rarded h;% ~I1~ Ln'v Cc~~--cfPPf'G r~rt rlIG2/Ei1' =2~t7 l~t'I ---_~°~ ZfLP i;m,. C:ac~rd` TO; CO..~--Tt1:ti.1T:C1E'T.:C?~1~"1711171_ST~'.t~.3{.u.a r CC: ~ S~Ytsjert: RE~auesr" t4c7 7"zijecr C~ms~t .:az3saz.c ar G~ > Dear I~ir. IZac~zlCier, > Injec~t.i.c~n ~~ c_em~t:L' rzns~r.e ui~d ~:1~an~ua fluids f~-vzn a:uc~ ~arztl brine zui:xn~~ o}~drations at L'ne 1~lpi~ze mud plant faci.l.ty ir.t,U upX:zczv~cl annular disposal ~pPraticzns t<;as grazat;ecl lay ~n~ .~~z~s~ca t~i.I ?u~d Gas Conse~-:~ativn C~zzunxs~iozz ~ (}z{zGGG} _n the 1'farch 11, 7`~9~ lett~x from ~'~t~GCC tv ~7oucsGhes~`er of Fi~CO > t'~Ias'~.a, ~_ic., r:otr~ Phillips llaska, Tiic. ft~?~7) `Ihe appro~.ral ~;a~ ~-artf:ed to > P,~~1" spur;. f' i.c~l ly fox- R1 gzi.nF~ Dr = I Si t~ CD1 ar>d 3~ttiiori zest v<~luz~ies u~~ t~.o 35, 004 Y~arxel~: tuhrougFr the anr.;rl~r sp=zC:a. PSI request f;liat :lais appro-ral be extended tea drilling rzz?~~_atinnz a ~lpir:z_ a Drili Site C`J2. Cerner.l rnixinc olacr_~aczar.s nor sett-ng surface cozitluctary > +~.i.11, he T~~kng plar_~. at the Grind and.Ir_ject facility s.~tiich is c~u~rently > a~tachea tv lrh~ drilling -rice at CD2. C?~on c.ori7~l.c~~~c~z: of. the cementing in.. of the co.acitzctars; the lines <nnd zn.xi.ng t-..ank :ill na~~~ tea .7~e xirzsed anc,~ ~rhe"": > x'insa-e di~pc~sed of. PAI request apprtr~:af t:~.a i;lject ibis z'iz~s<~Cc, anC~ o~hez clen~-up zro;; the xnud and brim mixing optirati.oas, i:itc~ the arz:rn~l space of approved :ells located at IIr=11 Site CL>2.. 'I L' you i7avc any quest~,pns }alcasc ccnt_act me ~h ~?~4-~~2Dt~..; > Tcm Lan On lp,in~ Field Envixvrzm~xttal Cc~rsglianee tom~naurzd~cvci • • Note to File CD4-322 (207-101...307-293} Colville River Unit (Nanuq-Kuparuk) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhiliips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 200 bbls of cement was circulated to surface.. The net cement remaining in the surface hole was 34% XS of the calculated hole volume. -- On the initial leak off test, the pressure slope rises exhibiting 2 slopes to the determined FIT point at 18.0 EMW. 2 slopes are not uncommon in GRU. Minimal fluid was pumped into the format~ns. During the observation period, the pressure declined to about 16.7 EMW. The infial leak off indicates that the surface casing shoe is well cemented. -- No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted but the casing was not reciprocated. --An infectivity test down 9-5l8" x 7" annulus was conducted. Pressure steadily increases although at a decreasing rate until the break at 17.1 EMW. The pressure slightly declines with additional pumping to 17.0 EMW. During the observation period, the pressure declined to 15.0 EMW. Since the difference between the FIT and pumpin was small, CAPI conducted a Z"~ infectivity test. Qnce lines were #illed, the pressure climbs steadily to a break at 14.0 EMW. Pressures decline wi#h additions! pumping to about 12.2 EMW. After pumping was halted, the pressure declines to 11.7 EMW. This 2"d injectiv'rty test indicates that disposal should be conducted at EMWs less than the shoe FIT. --CPA provided a listing of all surface casing shoes within '/~ mile radius of CD4-322. The nearest well is CD4-321 800' distant wwithh 3 other wells including Nanuq 3 900' distant. Nanuq 5 is beyond the'/. mile radius. Based on examination of the submitted in#om~tation, l recommend approval of ConocoPhillips' request for the subject weN. Tom Maunder, PE Sr. Petroleum Engineer October 24, 2007 G:\common\tommaunder\Well Information\By Subject\Annttlar Dis~sal\471 <~8--CD4322.doc r ~ • Note to File CRU CD4-322 (PTD 2071010) October 4, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD4-322 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annuli of well CD4-322. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at -2,330' true vertical depth subsea ("TVDSS"), near the base of a 30-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 2, CD4-321, CD4-16, Nanuq 3, and CD4-306. 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 Sections 23 and 24, T11N, RSE, UM and in Section 24, T11N, 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 -1,733' (Nanuq 3) to -2,333' TVDSS (CD4-16), 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 lie at about -3,900' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 27-foot thick interval containing several 1- to 4-foot thick beds of silty sandstone and sandstone that lie between about -2,428' and -2,455' TVDSS, which is just below the surface casing shoe. The aggregate thickness of thin potential injection beds is about 14'. 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. CD4-322 Note to File Index Map • October 4, 2007 Page 2 of 3 [n this area, the base of permafrost occurs at about -800' TVDSS, which is 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 Nanuk 2 and Nanuq 3 indicate that traces of methane were first measured between -70' and -340 TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 10 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 mudlog) were -2,170' and -1,535' TVDSS, respectively. So, the entire proposed disposal zone may contain some methane gas. Supporting documentation to ConocoPhillips' annular disposal applications states: ``There are no USUW 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. I'he shallowest oil shows observed in nearby wells Nanuk 2 and Nanuq 3 occur at -3,765' and -3,940' 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. The following chart provides an estimate of the affected areas surrounding the affected wellbores. A worst-case assumption will be made. Well logs of CD4-322 are not available at present. However, a Phis interval, which lies between about -2,560' and -2,615' TVDSS, will provide lower confinement for any injected wastes. • • CD4-37.2 Note to File October 4, 2007 Page 3 of 3 count of sand within the most likely disposal zone using gamma ray curves from offset wells Nanuq 3 and CD4-306 indicates about 10' of net sand. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sand and siltstone porosity of l2% 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 wellbores. Injected Fluid vs Affected Radial Distance CD4-322 Wellbore (assumes 10' aggregate injection zone thickness and 12% porosity) :500 a 250 m ` i C ~~ _,_~ a ~ _-r- -- 200 ! - ~ _~ I - _: __ - __.--,-~~--~- E .--- m ~ . '~ ~ 150 _r--~ C ,-' ~ ,i ,~ ~ ~~ 0 X, ~ 100 /_~_~~ _ i 0' ~ V i y / w r Q 50 /' - -- - - -- I r~ . _ _ - -- - -- -- 0 ~----~ _ _ _ _ ---- - - --- - _- --- 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath about 800' 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. [ mend approval of this annular disposal project. r Steve Davies ~D ' `~ D 7 Senior Petroleum Geologist Cpa r. ~,/.~~~ io~~~ EM RANDUM ~ State of Alaska M O Alaska Oil and Gas Conservation Commission DATE: Monday, October 22, 2007 TO: Jim Regg P.I. Supervisor ( ~~ ~ cOl ~ ~ J ~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-322 FROM: John Crisp COLVILLE RIV NAN-K CD4-322 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv rn~ NON-CONFIDENTIAL Comm Well Name: COLVILLE RN NAN-K CD4-322 mitJCr071015075926 Insp Num: Rel Insp Num: API Well Number: ~0-103-20551-00-00 Permit Number: 2o7-tot-o Inspector Name: John Crisp Inspection Date: to~`IZi2oo7 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cna-3zz 'TYpeInj. j ~' '~ TVD % - ~ ~I~s IAT ~~ jj z~7s _ --. z76i ~ z76z ~ --- T -,--r----- P.T I zonola jTYPeTest SPT ~ Test psi I L i~9s.~s ~, A 3zo ~, asi i ~ asa ! a66 ; _ -!--- ._ ~ Interval hnraL P/F _ P ~ Tubing ~~ zzsa j z26~ ~, zzba i zz67 i i NOtes: Initial MIT. Monday, October 22, 2007 Page 1 of 1 P Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesda ,October 16, 2007 12:01 PM To: 'NSK Problem Well Supv' ~,~, ~ ~~'~~~~'' ~ Subject: RE:Emailing: MIT CRU CD4-322 10-12-07.x1s o ``~f I spoke to John Crisp this morning; he confirmed the numbers in his report match those you pulled from SetCim. You do not need to send anything else - I will discuss with Bob when he returns. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: NSK Problem Well Supv [mailto:n1617@conocophillips.coml Sent: Tuesday, October 16, 2007 10:22 AM To: Regg, James B (DOA) Subject: Emailing: MIT CRU CD4-322 10-12-07.x1s « MIT CRU CD4-322 10-12-07.x1s» Jim, Enclosed is the test data for the initial witnessed MITIA on well CD4-322 ass discussed earlier. Let me know if you have any questions and what data set you decide on. Thanks. Perry Klein Problem well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com • Page 1 of 3 Maunder, Thomas E (DOA) From: Galiunas, Elizabeth G [Elizabeth.C.Galiunas@conocophii{ips.com) Sent: Wednesday, October 24, 2007 1:19 PM To: Maunder, Thomas E (DOA) Subject: RE: CD4-322 (207-101) AD Request Tom, Here is more explanation for the comments section. These numbers are to explain the 7.1 ppg MW calculation. The well was flushed with water and freeze protected with 6$ bbls of diesel. Diesel pumped: 68 bbls = 2409' and / 2005 tvd = 720 psi Hyd.(est. wt. of diesel @ 6.9 ppg) Surface Casing Shoe @ 3580' and l 2385' tvd 380 ' tvd (8.4 ppg) FW = 166 psi -fresh water in annulus from flushing annulus prior to pumping diesel. Total Hydrostatic: Pd~esei + Pfre~n Water= 720 psi + 166 psi "Total 886 psi hyd. = 7.14 ppg ave All fluid pumped was diesel. Let me know if you want more information. Thanks, Liz Galiunas From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 24, 2007 12:27 PM To: Galiunas, Elizabeth C Subject: RE: CD4-322 (207-101) AD Request Thanks Liz, The pressure curve is much changed from before. A question on the calculation in the notes section. Are the footages and or tvd? I really can't reconcile the numbers with the and (3580) or tvd (2385) of the surface shoe. Thanks in advance. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Wednesday, October 24, 2007 10:52 AM To: Maunder, Thomas E (DOA) Subject: RE: CD4-322 (207-101) AD Request Hi, Tom, 10/24/2007 . . Page 2 of 3 Here is the second annular LOT test done on CD4-322. I made some notes in the comment section of the report. let me know if you have any questions. \ 1 (~ ~~ ~S~ ~r~C\v CJE~ Zr U ~~C4~~Oh kGndest regards, P Liz d~~ ,r~„ ,~ Liz Galiunas t~/a Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 08, 2007 3:22 PM To: Galiunas, Elizabeth C Subject: RE: CD4-322 (207-101) AD Request Liz, Thanks for the information. I went back through other records I have and the LOT/pump in information looks similar to CD4-210. Based on the experience with that well, I think it may be appropriate to conduct another pump-in. Please discuss with your colleagues and let me know your thoughts. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Monday, October 08, 2007 2:40 PM To: Maunder, Thomas E (DOA) Subject: RE: CD4-322 (207-101) AD Request Tom, have a look at the excel sheet I have attached. The Summary page is what we send you usually. The PIT Plot page is how we choose the LOT point. We usually draw 2 lines to help show the LOT point. Call and I can go through this more. Sometimes those summary sheets get hard to see what is really going on with the slope of the line. Vern and I looked over this one and moved it a hair to 829 psi at 13 bbls, since the 840, was slightly off the best place where the slope changes. To answer your second question/comment, it does appear that at CD4 the sand it "tighter"'. Not sure as to why this is. regards, Liz Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907}-265-6247 10/24/2007 Page 3 of 3 Cell: (907)-441-4871 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 08, 2007 12:10 PM To: Galiunas, Elizabeth C Cc: Johnson, Vern; Noel, Brian Subject.: CD4-322 (207-101) AD Request Liz, et al, 1 am reviewing the AD application for this well and have a couple of questions ... 1. On the pump in test, a pressure of 840 psi is chosen for the calculation. How was this determined? 840 is not one of the listed values. Admittedly the pressure between bbls is decreasing. 2. There doesn't appear to be a lot of room" between the FIT after drillout and the pump in EMW. It seems that the earth is "tighter" at CD4. Look forward to your reply. Tom Maunder, PE AOGCC 10/24/2007 ! • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.u~ ~ 1- ~ j;~ OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Alpine / CRU /CD4-322 10/15/07 R. French Well CD4-322 Ty e Inj. W TVD 7,175' Tubing 2262 2267 2275 2278 Interval I P.T.D. 2071010 Type test P Test si 1794 Casing 759 3019 2993 2988 P!F P Notes: Data from 10/15/07 retest, not a stae witnessed test OA 428 614 576 570 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test 1 ~ II IIl1U1 1 Cpl 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1 /OS 2007-1015_MIT_CRU_CD4-322xis • ConocoPhillips September 25, 2007 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission ~~~~ ~ ~ ~~~~ 333 West 7th Avenue Suite 100 ~~l~a~i3 tSif ~;;,. ~~~„-;; ~~rml~ssii7n Anchorage, Alaska 99501 r,,., ~ ,; , Subject: Well Completion Report for CD4-322 (APD 207-101) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Nanuq Kuparuk well CD4-322. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~~"2~lOG, WELL COMPLETION OR RECOMPLETION REPOR7~~'~~~...~~/~t~• ~~n~ti~srri~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ Q WDSPL ^ WAG ^ Other ^ No. of Completions: ~ .~ tb. Well Class: ~" ~~=€+,3C3t~'~ Development ^ Exploratory ^ Service 0 Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., G~. ~-p~ orAband.: °~.9, ~+ ~~ ~ ^' 12. Permit to Drill Number: 207-101 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 27, 2007 - 13. API Number: 50-103-20551-00 ' 4a. Location of Well (Governmental Section): Surface: 2987' FNL, 477' FEL, Sec. 24, T11 N, R4E, UM - 7. Date TD Reached: August 8, 2007 ~ 14. Well Name and Number: CD4-322 - Top of Productive Horizon: 1699' FNL, 726' FEL, Sec. 21, T11 N, R4E, UM 8. KB (ft above MSL): 37' RKB Ground (ft MSL): 56' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 1664' FNL, 1600' FEL, Sec. 21, T11 N, R4E, UM 9. Plug Back Depth (MD + TVD): 19221' MD / 7586' TVD Nanuq Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377767 y- 5957426 Zone- 4 10. Total Depth (MD + TVD): • 19452' MD / 7739' TvD 16. Property Designation: ADL 380077, 387208, ASRCNPRA02 TPI: x- 361702 y- 5958995 Zone- 4 Total Depth: x- 360829 - 5959046 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 2289' MD / 1952' TVD 17. Land Use Permit: 380077 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 (TVD): 1600' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res, SCMT, CCL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD 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" 11 cu yds Portland Type III 9-5/8" 40# L-80 37' 3580' 37' 2385' 12.25" 508 sx AS Lite, 235 sx Class G 7" 26# L-80 37' 19436' 37' 7728' 8.75" sx CI G, 1 so sx CI G } `~,'~", ~~ 23. Open to production or injection? Yes ~ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 18299' 18226' 18538'-18558' MD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection September 10, 2007 Method of Operation (Flowing, gas lift, etc.) water injector Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL 1500 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) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ 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 se crate sheets with this form, if needed Submit detailed descri lions, core chi s hoto ra hs and laborato anal tical results er 20 AAC 25.071. Ci}ialr! E~i iQN } ( P )~ P~ P,P 9 P rY Y~ p ~~~~.~ V..~ NONE i Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE i i 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1707' 1600' needed, and submit detailed test information per 20 AAC 25.071. C-30 3656' 2411' C-20 4880' 2818' K-3 8077' 3857' K-2 8859' 4114' ALB 97 13393' 5590' Nanuq 14946' 6093' Top HRZ 17671' 6983' Base HRZ 18196' 7152' K-1 18283' 7179' Kuparuk C 18427' 7226' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, cement detail sheet, mechanical integrity test 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name/^r C Alvord Title: WNS Drilling Team Lead Signature /+~ Date ~' ~S f~ ~ Phone - ~ ~ , G ~ 2 o ~, 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 Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report Companc: ConocoPhillips Alaska Inc . Uair. 8/27/2007 'l'ime: 12:03:14 Pa~c: 1 Field: Colville River Unit Co-ordi~»>trfNE) Reference: Well: CD4-322. True North Site: Nanuq CD4 Vertical Ifs D) Re ference: CD4-322: 55.7 ~~cll: CD4-322 Section I~~s) Refer ence: Well (O.OON,O.O OE,274.60Azi) \1ellp.rth: CD4-321 su rvey (':~Icolation Method: Minimum Curva ture llh: Oracle Field: Colville River Unit _ _ ~ North Slope Alaska ! United Sta tes Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (C larke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: CD4-322 Slot Name: API 50-103-20551-00 Well Position: +N/-S -104.61 ft Northing: 5957428.10 ft Latitude: 70 17 31.937 N +E/-W -406.70 ft Easting : 377766.39 ft Longitude: 150 59 22.615 W Position Uncertainty: 0.00 ft Wellpath: CD4-322 Drilled From: Well Ref. Point API 50-103-20551-00 Tie-on Depth: 36.73 ft Current Datum: CD4-322: Height 55.73 ft Above System Datum: Mean Sea Level Magnetic Data: 7/24/2007 Declination: 22.52 deg Field Strength: 57556 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.73 0.00 0.00 274.60 Survey Program for Definitive Wellpath Date: 8/18/2007 Validated: Yes V ersion: 8 Actual From To Survey Toolcode Tool Name ft ft 79.00 441.00 CD4-322 Gyro (79.00-441.00) C B-GYRO-SS Camera based gyro single shot j 568.28 19411.45 CD4-322 I IFR+MS+Sag (568.28-19 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~1D Incl .4aim TVD S}s Tl'D it/S E,'~~ VapN 11~1ap}~. t'nnl ft deg deg ft ft ft ft ft ft i 36.73 0.00 0.00 - 36.73 _ ___ -19.00 _ __ 0.00 - 0.00 __ _ _ - 5957428.10 377766.39 _ _ __ -- TIE LINE 79.00 0.40 248.00 79.00 23.27 -0.06 -0.14 5957428.05 377766.25 CB-GYRO-SS 169.00 0.30 303.00 169.00 113.27 -0.04 -0.63 5957428.07 377765.76 CB-GYRO-SS 259.00 0.60 282.00 259.00 203.27 0.18 -1.28 5957428.30 377765.11 CB-GYRO-SS 351.00 2.70 250.00 350.95 295.22 -0.46 -3.79 5957427.70 377762.59 CB-GYRO-SS 441.00 3.90 248.00 440.80 385.07 -2.33 -8.62 5957425.91 377757.73 CB-GYRO-SS 568.28 4.75 267.97 567.73 512.00 -4.14 -17.90 5957424.25 377748.42 MWD+IFR-AK-CAZ-SC 596.28 4.89 266.99 595.63 539.90 -4.24 -20.25 5957424.19 377746.07 MWD+IFR-AK-CAZ-SC 627.34 5.15 269.87 626.57 570.84 -4.32 -22.97 5957424.16 377743.36 MWD+IFR-AK-CAZ-SC 659.17 5.50 268.77 658.26 602.53 -4.35 -25.92 5957424.17 377740.40 MWD+IFR-AK-CAZ-SC 704.54 5.95 273.59 703.40 647.67 -4.25 -30.44 5957424.34 377735.88 MWD+IFR-AK-CAZ-SC 734.79 7.08 281.12 733.46 677.73 -3.79 -33.84 5957424.86 377732.50 MWD+IFR-AK-CAZ-SC 765.02 8.59 279.02 763.41 707.68 -3.08 -37.90 5957425.64 377728.45 MWD+IFR-AK-CAZ-SC 785.09 9.53 275.54 783.23 727.50 -2.68 -41.03 5957426.08 377725.33 MWD+IFR-AK-CAZ-SC j 810.13 10.61 275.54 807.88 752.15 -2.26 -45.39 5957426.58 377720.98 MWD+IFR-AK-CAZ-SC i 839.89 12.34 282.83 837.04 781.31 -1.29 -51.22 5957427.64 377715.16 MWD+IFR-AK-CAZ-SC ~~ 882.21 14.05 287.26 878.25 822.52 1.24 -60.53 5957430.32 377705.89 MWD+IFR-AK-CAZ-SC 934.80 17.42 293.03 928.86 873.13 6.21 -73.88 5957435.51 377692.63 MWD+IFR-AK-CAZ-SC 979.69 19.16 294.39 971.48 915.75 11.88 -86.77 5957441.39 377679.83 MWD+IFR-AK-CAZ-SC 1029.80 20.29 292.84 1018.65 962.92 18.65 -102.27 5957448.41 377664.45 MWD+IFR-AK-CAZ-SC 1125.16 22.12 287.66 1107.56 1051.83 30.52 -134.62 5957460.80 377632.30 MWD+IFR-AK-CAZ-SC 1220.54 27.14 290.66 1194.24 1138.51 43.65 -172.11 5957474.54 377595.03 MWD+IFR-AK-CAZ-SC 1315.01 29.37 289.34 1277.45 1221.72 58.93 -214.14 5957490.50 377553.26 MWD+IFR-AK-CAZ-SC 1410.39 32.66 288.17 1359.18 1303.45 74.70 -260.67 5957507.03 377506.99 MWD+IFR-AK-CAZ-SC ~ ~~ 1505.93 35.22 284.83 1438.44 1382.71 89.80 -311.81 5957522.95 377456.11 MWD+IFR-AK-CAZ-SC ~ 1600.48 37.69 283.93 1514.49 1458.76 103.74 -366.23 5957537.77 377401.93 MWD+IFR-AK-CAZ-SC 1695.31 41.00 280.21 1587.82 1532.09 116.23 -425.01 5957551.22 377343.37 MWD+IFR-AK-CAZ-SC ! 1790.59 45.41 279.01 1657.26 1601.53 127.09 -489.31 5957563.12 377279.26 MWD+IFR-AK-CAZ-SC i 1885.52 48.13 277.58 1722.27 1666.54 137.05 -557.74 5957574.19 377211.00 MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report (~ompany: ConocoPhillips Alaska Inc- Dartr. 8/27/2007 Timr. 12:03:14 Page Field: Colville River Unit Co-o rdiuate(NE) kcfcrencr. WeIL CD4-322, True North site Nanuq CD4 FcrYi cal(TVD)Refcrcncc: CD4-322'. 5 5.7 ~~ ell: CD4-322 Section (~'S ) Reference: Well (QOON.O-OOE,2i4.60Azi) ~~ellpath: CD 4-322 surveyCakul;ifi un 1lethod: Minimum C urvature Db: Oracle tiurcc~ ~tU tnc l ~cim TFll SasTV U V/S E/~V S1ap~I MapE Tool ft deg deg.. ft ft ft ft ' ft ft 1980. 58 52. 13 276.82 1783. 20 1727 .47 146 .18 -630 .11 5957584. 49 377138. 79 MWD+IFR-AK-CAZ-SC 2075. 24 55 .19 278.84 1839. 29 1783 .56 156 .59 -705 .63 5957596. 13 377063. 46 MWD+IFR-AK-CAZ-SC i 2169. 95 57 .51 280.36 1891. 77 1836 .04 169 .75 -783 .36 5957610. 55 376985. 96 MWD+IFR-AK-CAZ-SC 2265. 25 60 .42 279.87 1940. 90 1885 .17 184 .09 -863 .74 5957626. 19 376905. 83 MWD+IFR-AK-CAZ-SC 2360. 57 64 .04 276.85 1985. 31 1929 .58 196 .31 -947 .16 5957639. 77 376822. 63 MWD+IFR-AK-CAZ-SC 2455. 64 68 .20 274.37 2023. 79 1968 .06 204 .77 -1033 .65 5957649. 64 376736. 29 MWD+IFR-AK-CAZ-SC 2550. 93 70. 20 273.09 2057. 63 2001 .90 210 .56 -1122 .54 5957656. 87 376647. 52 MWD+IFR-AK-CAZ-SC 2646. 19 71. 44 272.02 2088. 93 2033 .20 214 .57 -1212 .41 5957662. 33 376557. 72 MWD+IFR-AK-CAZ-SC 2741. 17 71. 02 271.75 2119. 49 2063 .76 217 .53 -1302 .29 5957666. 75 376467. 91 MWD+IFR-AK-CAZ-SC 2835. 76 72. 15 272.47 2149. 37 2093 .64 220 .83 -1391 .98 5957671. 52 376378. 30 MWD+IFR-AK-CAZ-SC 2931. 37 71. 36 273.93 2179. 30 2123 .57 225 .90 -1482 .64 5957678. 06 376287. 75 MWD+IFR-AK-CAZ-SC 3027. 11 70 .77 273.81 2210. 37 2154 .64 232 .01 -1572 .99 5957685. 64 376197. 51 MWD+IFR-AK-CAZ-SC 3118. 98 72 .78 274.31 2239. 10 2183 .37 238 .19 -1660 .03 5957693. 23 376110. 59 MWD+IFR-AK-CAZ-SC ~ 3216. 87 72 .50 274.63 2268. 31 2212 .58 245 .47 -1753 .17 5957702. 02 376017. 59 MWD+IFR-AK-CAZ-SC 3312. 04 72 .24 274.26 2297. 13 2241 .40 252 .50 -1843 .60 5957710. 52 375927. 29 MWD+IFR-AK-CAZ-SC 3407 .31 70 .62 273.49 2327. 47 2271 .74 258 .61 -1933 .70 5957718. 09 375837. 31 MWD+tFR-AK-CAZ-SC 3502. 83 70. 46 273.85 2359. 30 2303 .57 264 .37 -2023 .58 5957725. 32 375747. 55 MWD+IFR-AK-CAZ-SC 3542. 03 70. 31 273.48 2372. 45 2316 .72 266 .73 -2060 .43 5957728. 28 375710. 74 MWD+IFR-AK-CAZ-SC 3674. 02 70. 38 274.88 2416. 85 2361 .12 275 .79 -2184 .39 5957739. 35 375586. 95 MWD+IFR-AK-CAZ-SC 3767. 80 70. 55 274.87 2448. 21 2392 .48 283 .30 -2272 .45 5957748. 29 375499. 03 MWD+IFR-AK-CAZ-SC 3863. 27 70. 88 274.31 2479. 74 2424 .01 290 .52 -2362 .28 5957756. 96 375409. 34 MWD+IFR-AK-CAZ-SC 3958. 44 71. 22 274.21 2510. 65 2454 .92 297 .20 -2452 .04 5957765. 10 375319. 71 MWD+IFR-AK-CAZ-SC 4053. 49 71 .27 274.79 2541. 21 2485 .48 304 .26 -2541 .77 5957773. 62 375230. 12 MWD+IFR-AK-CAZ-SC 4148. 12 71 .30 275.17 2571. 57 2515 .84 312 .04 -2631 .05 5957782. 85 375140. 98 MWD+IFR-AK-CAZ-SC 4243. 58 71 .05 275.52 2602. 37 2546 .64 320 .46 -2721 .01 5957792. 73 375051. 17 MWD+IFR-AK-CAZ-SC ~ 4338. 67 70 .77 275.63 2633. 47 2577 .74 329 .19 -2810 .45 5957802. 91 374961. 90 MWD+IFR-AK-CAZ-SC I I 4433. 41 70. 28 275.53 2665. 06 2609 .33 337 .87 -2899 .35 5957813. 04 374873. 16 MWD+IFR-AK-CAZ-SC 4528. 56 70. 27 275.86 2697. 17 2641 .44 346 .76 -2988 .47 5957823. 38 374784. 20 MWD+IFR-AK-CAZ-SC ~ 4623. 58 70. 06 276.30 2729. 41 2673 .68 356 .23 -3077 .35 5957834. 29 374695. 49 MWD+IFR-AK-CAZ-SC 4718. 28 69. 79 276.63 2761. 92 2706 .19 366 .24 -3165 .73 5957845. 74 374607. 30 MWD+IFR-AK-CAZ-SC 4813. 81 69. 73 276.81 2794. 97 2739 .24 376 .73 -3254 .75 5957857. 67 374518. 47 MWD+IFR-AK-CAZ-SC 4909. 10 70. 30 276.35 2827. 54 2771 .81 386 .99 -3343 .71 5957869. 38 374429. 69 MWD+IFR-AK-CAZ-SC 5004. 27 72 .47 274.93 2857. 92 2802 .19 395 .85 -3433 .45 5957879. 69 374340. 11 MWD+IFR-AK-CAZ-SC 5100. 31 73 .08 274.60 2886. 36 2830 .63 403 .47 -3524 .87 5957888. 79 374248. 84 MWD+IFR-AK-CAZ-SC 5194. 87 72 .53 273.72 2914. 31 2858 .58 410 .02 -3614 .96 5957896. 81 374158. 87 MWD+IFR-AK-CAZ-SC 5290. 29 72. 72 272.94 2942. 81 2887 .08 415 .31 -3705 .88 5957903. 58 374068. 06 MWD+tFR-AK-CAZ-SC 5385. 14 72. 34 272.92 2971. 28 2915 .55 419 .94 -3796 .23 5957909. 67 373977. 80 MWD+IFR-AK-CAZ-SC 5480. 73 71. 93 272.27 3000. 60 2944 .87 424 .06 -3887 .12 5957915. 27 373887. 00 MWD+IFR-AK-CAZ-SC 5575. 28 71. 18 271.66 3030. 52 2974 .79 427 .13 -3976 .76 5957919. 80 373797. 43 MWD+IFR-AK-CAZ-SC 5667. 95 71. 56 271.55 3060. 12 3004 .39 429 .59 -4064 .54 5957923. 68 373709. 71 MWD+IFR-AK-CAZ-SC 5765. 29 69. 81 271.76 3092. 32 3036 .59 432 .25 -4156 .36 5957927. 83 373617. 96 MWD+IFR-AK-CAZ-SC 5858. 87 69. 35 271.68 3124. 97 3069 .24 434 .88 -4244 .02 5957931. 89 373530. 36 MWD+IFR-AK-CAZ-SC 5955. 07 69 .08 272.80 3159. 11 3103 .38 438 .39 -4333 .88 5957936. 86 373440. 57 MWD+IFR-AK-CAZ-SC I 6049. 95 68 .90 273.51 3193. 13 3137 .40 443 .27 -4422 .32 5957943. 17 373352. 23 MWD+IFR-AK-CAZ-SC 6145. 61 68 .85 274.35 3227. 60 3171 .87 449 .38 -4511 .34 5957950. 73 373263. 33 MWD+IFR-AK-CAZ-SC 6240. 67 70. 52 272.89 3260. 61 3204 .88 455 .00 -4600 .31 5957957. 80 373174. 47 MWD+IFR-AK-CAZ-SC I 6336. 03 70. 96 273.36 3292. 06 3236 .33 459 .91 -4690 .19 5957964. 17 373084. 68 MWD+IFR-AK-CAZ-SC 6431. 08 70. 19 272.29 3323. 67 3267 .94 464 .33 -4779 .72 5957970. 04 372995. 25 MWD+IFR-AK-CAZ-SC 6526. 01 69. 98 272.79 3356. 01 3300 .28 468 .29 -4868 .89 5957975. 45 372906. 16 MWD+IFR-AK-CAZ-SC 6621. 19 70. 21 273.12 3388. 41 3332 .68 472 .90 -4958 .26 5957981. 51 372816. 88 MWD+IFR-AK-CAZ-SC 6716. 27 70. 12 273.32 3420. 68 3364 .95 477 .92 -5047 .56 5957987. 99 372727. 69 MWD+IFR-AK-CAZ-SC 6810. 99 70. 44 273.48 3452. 64 3396 .91 483 .21 -5136 .57 5957994. 72 372638. 78 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConacoFhiilips Alaska Inc. Uatr. 8/27f2007 Time: '12:03~1a Pai;c: 3 Field: Colville River Unit Co-u rdiuatc (NEp Reference: WeN: GD4-322. True North Sitc: Nanuq CDa ~~crti c:il (lv D) Reference: CD4-322: 5 5.7 Well: CD4-322 secti unl~'S) Reference: Well (O.OON,O.OOE274.60Azi) Wellpath: CD4-322 Sui~ c} Calc idation Method: Minimum C urvature Db: Oracle tiiirvcv MD Inc l ~~iin ~Il'D RvsTVD V/1 F:~~~ 11apY MapE luol ft deg deg ft ft ft ft ft ft I 6906 .77 70 .97 274.27 3484. 29 3428. 56 489. 32 -5226. 76 5958002. 30 372548. 71 MWD+IFR-AK-CAZ-SC j 7001 .74 71 .14 274.73 3515. 12 3459. 39 496. 37 -5316. 31 5958010. 80 372459. 30 MWD+IFR-AK-CAZ-SC 7096 .98 71 .32 276.44 3545. 77 3490. 04 505. 15 -5406. 05 5958021. 03 372369. 72 MWD+IFR-AK-CAZ-SC 7192 .44 71 .39 276.58 3576. 28 3520. 55 515. 40 -5495. 92 5958032. 75 372280. 04 MWD+IFR-AK-CAZ-SC 7286 .41 72 .06 277.75 3605. 75 3550. 02 526. 53 -5584. 45 5958045. 32 372191. 70 MWD+IFR-AK-CAZ-SC 7379 .76 71 .95 276.82 3634. 59 3578. 86 537. 79 -5672. 51 5958058. 00 372103. 84 MWD+IFR-AK-CAZ-SC 7476 .31 71 .92 275.69 3664. 53 3608. 80 547. 79 -5763. 76 5958069. 49 372012. 78 MWD+IFR-AK-CAZ-SC 7571 .97 71 .86 274.96 3694. 27 3638. 54 556. 23 -5854. 28 5958079. 39 371922. 41 MWD+IFR-AK-CAZ-SC 7667 .22 71 .53 274.85 3724. 18 3668. 45 563. 96 -5944. 38 5958088. 59 371832. 46 MWD+IFR-AK-CAZ-SC 7762 .60 71 .16 274.72 3754. 69 3698. 96 571. 50 -6034. 44 5958097. 59 371742. 54 MWD+IFR-AK-CAZ-SC 7857 .56 71 .01 274.92 3785. 48 3729. 75 579. 05 -6123. 95 5958106. 59 371653. 17 MWD+IFR-AK-CAZ-SC 7953 .06 71 .13 274.27 3816. 46 3760. 73 586. 29 -6214. 00 5958115. 29 371563. 26 MWD+IFR-AK-CAZ-SC 8047 .65 71 .03 272.51 3847. 13 3791. 40 591. 58 -6303. 31 5958122. 03 371474. 05 MWD+IFR-AK-CAZ-SC 8142 .94 70 .43 271.64 3878. 58 3822. 85 594. 83 -6393. 21 5958126. 75 371384. 23 MWD+IFR-AK-CAZ-SC 8238 .25 70 .30 271.77 3910. 60 3854. 87 597. 51 -6482. 93 5958130. 88 371294. 57 MWD+IFR-AK-CAZ-SC 8333 .41 70 .31 271.77 3942. 67 3886. 94 600. 27 -6572. 48 5958135. 10 371205. 08 MWD+IFR-AK-CAZ-SC 8428 .66 70 .04 272.62 3974. 98 3919. 25 603. 70 -6662. 02 5958139. 99 371115. 62 MWD+IFR-AK-CAZ-SC 8523 .36 71 .14 272.23 4006. 45 3950. 72 607. 48 -6751. 26 5958145. 22 371026. 46 MWD+IFR-AK-CAZ-SC 8618 .49 70 .94 273.07 4037. 36 3981. 63 611. 64 -6841. 13 5958150. 84 370936. 68 MWD+IFR-AK-CAZ-SC 8713 .95 71 .46 273.87 4068. 12 4012. 39 617. 11 -6931. 33 5958157. 77 370846. 59 MWD+IFR-AK-CAZ-SC 8807 .88 71 .21 273.91 4098. 18 4042. 45 623. 15 -7020. 11 5958165. 25 370757. 92 MWD+IFR-AK-CAZ-SC 8902 .64 71 .80 275.10 4128. 24 4072. 51 630. 21 -7109. 70 5958173. 77 370668. 47 MWD+IFR-AK-CAZ-SC 8997 .59 71 .87 275.29 4157. 85 4102. 12 638. 38 -7199. 55 5958183. 40 370578. 77 MWD+IFR-AK-CAZ-SC 9092 .71 71 .21 275.14 4187. 96 4132. 23 646. 58 -7289. 40 5958193. 06 370489. 07 MWD+IFR-AK-CAZ-SC ~ 9187 .97 70 .71 275.11 4219. 04 4163. 31 654. 62 -7379. 09 5958202. 56 370399. 53 MWD+IFR-AK-CAZ-SC ~ 9283 .08 70 .91 275.16 4250. 30 4194. 57 662. 66 -7468. 55 5958212. 05 370310. 22 MWD+IFR-AK-CAZ-SC ~ 9378 .26 70 .70 274.24 4281. 60 4225. 87 670. 03 -7558. 14 5958220. 87 370220. 77 MWD+IFR-AK-CAZ-SC 9472 .96 70 .10 274.10 4313. 36 4257. 63 676. 52 -7647. 11 5958228. 80 370131. 92 MWD+IFR-AK-CAZ-SC I 9568 .80 70 .76 272.19 4345. 47 4289. 74 681. 47 -7737. 28 5958235. 22 370041. 86 MWD+IFR-AK-CAZ-SC 9663 .95 70 .88 271.87 4376. 73 4321. 00 684. 65 -7827. 09 5958239. 86 369952. 12 MWD+IFR-AK-CAZ-SC 9758 .87 70 .98 272.06 4407. 74 4352. 01 687. 73 -7916. 74 5958244. 39 369862. 53 MWD+IFR-AK-CAZ-SC 9854 .86 71 .01 273.61 4439. 00 4383. 27 692. 21 -8007. 39 5958250. 36 369771. 98 MWD+IFR-AK-CAZ-SC 9950 .64 70 .24 274.09 4470. 78 4415. 05 698. 28 -8097. 54 5958257. 89 369681. 95 MWD+IFR-AK-CAZ-SC 10045 .52 70 .78 274.77 4502. 43 4446. 70 705. 19 -8186. 71 5958266. 24 369592. 90 MWD+IFR-AK-CAZ-SC t 10141 .24 71 .48 275.29 4533. 39 4477. 66 713. 13 -8276. 94 5958275. 65 369502. 83 MWD+IFR-AK-CAZ-SC 10236 .67 71 .87 275.77 4563. 40 4507. 67 721. 86 -8367. 11 5958285. 85 369412. 82 MWD+IFR-AK-CAZ-SC 10332 .25 70 .84 276.01 4593. 95 4538. 22 731. 16 -8457. 19 5958296. 60 369322. 91 MWD+IFR-AK-CAZ-SC 10427 .61 70 .56 274.68 4625. 47 4569. 74 739. 54 -8546. 80 5958306. 44 369233. 45 MWD+IFR-AK-CAZ-SC ~ 10522 .29 71 .10 275.61 4656. 56 4600. 83 747. 56 -8635. 87 5958315. 91 369144. 54 MWD+IFR-AK-CAZ-SC 10617 .68 70 .88 274.34 4687. 64 4631. 91 755. 38 -8725. 71 5958325. 19 369054. 84 MWD+IFR-AK-CAZ-SC ~ 10713 .12 70 .90 274.04 4718. 88 4663. 15 761. 97 -8815. 65 5958333. 24 368965. 02 MWD+IFR-AK-CAZ-SC 10807 .40 71 .42 274.83 4749. 33 4693. 60 768. 87 -8904. 61 5958341. 58 368876. 19 MWD+IFR-AK-CAZ-SC 10903 .50 71 .20 274.95 4780. 12 4724. 39 776. 63 -8995. 31 5958350. 82 368785. 64 MWD+IFR-AK-CAZ-SC 10998 .90 70 .70 275.72 4811. 26 4755. 53 785. 02 -9085. 10 5958360. 66 368696. 01 MWD+IFR-AK-CAZ-SC 11093 .90 70 .34 274.24 4842. 94 4787. 21 792. 79 -9174. 32 5958369. 88 368606. 94 MWD+IFR-AK-CAZ-SC 11189 .99 71 .92 272.21 4874. 02 4818. 29 797. 90 -9265. 09 5958376. 47 368516. 27 MWD+IFR-AK-CAZ-SC 11284 .07 71 .55 272.17 4903. 51 4847. 78 801. 31 -9354. 37 5958381. 33 368427. 07 MWD+IFR-AK-CAZ-SC 11378 .67 71 .27 272.02 4933. 67 4877. 94 804. 59 -9443. 97 5958386. 06 368337. 53 MWD+IFR-AK-CAZ-SC 11473 .31 70 .94 272.83 4964. 31 4908. 58 808. 38 -9533. 43 5958391. 31 368248. 16 MWD+IFR-AK-CAZ-SC 11569 .81 70 .68 274.70 4996. 04 4940. 31 814. 36 -9624. 37 5958398. 77 368157. 34 MWD+IFR-AK-CAZ-SC 11663 .04 70 .23 275.94 5027. 23 4971. 50 822. 51 -9711. 84 5958408. 33 368070. 01 MWD+IFR-AK-CAZ-SC i 11757 .87 70 .19 274.83 5059. 33 5003. 60 830. 88 -9800. 68 5958418. 15 367981. 33 MWD+IFR-AK-CAZ-SC ~ 11853 .31 71 .69 274.88 5090. 50 5034. 77 838. 51 -9890. 56 5958427. 24 367891. 59 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Cunipa~n~ Field: Site: Well: Wellpath: Survey 41D ft : Conoco Phillips Alaska Inc- Colville River Unit Nanuq CD4 CD4-322 CD4-322 Incl Azim TVB deg deg ft ~1'~D ft lS ft Ih~ie: 812 712 0 0 7 Co-ordiunte(~iE}Reference: VerCical (f~`D) Referencr. Secfionl~ti)Reference: Survey Calculation Method: E!~V ~1apY ft ft ~Iinre: 1203:14 Pa;;c J WeIC CCk}-322, TrueNorth CD4-;322:55.7 Well (O.OON,O.OOE,274.60Azi) Minimum Curvature llh: OraCie ~1apP: Tooi __ ft 11948. 57 72 .83 275. 26 5119. 53 5063 .80 846. 53 -9980.93 5958436. 73 367801. 37 MWD+IFR-AK-CAZ-SC 12044. 48 72 .19 275. 51 5148. 35 5092 .62 855. 12 -10072.00 5958446. 79 367710. 46 MWD+IFR-AK-CAZ-SC 12138. 35 71 .95 275. 62 5177. 25 5121 .52 863. 78 -10160.89 5958456. 90 367621. 73 MWD+IFR-AK-CAZ-SC 12233. 13 70 .62 273. 79 5207. 66 5151 .93 871. 15 -10250.35 5958465. 72 367532. 41 MWD+IFR-AK-CAZ-SC 12328 .81 70 .16 271. 71 5239. 78 5184 .05 875. 47 -10340.37 5958471. 51 367442. 48 MWD+IFR-AK-CAZ-SC I 12424 .55 70 .05 273. 39 5272. 36 5216 .63 879. 48 -10430.31 5958476. 97 367352. 63 MWD+IFR-AK-CAZ-SC ~ 12519 .64 70 .65 274. 48 5304. 34 5248 .61 885. 62 -10519.64 5958484. 57 367263. 41 MWD+IFR-AK-CAZ-SC 12614 .44 70 .75 275. 64 5335. 67 5279 .94 893. 52 -10608.77 5958493. 91 367174. 43 MWD+IFR-AK-CAZ-SC 12709. 85 70 .71 274. 70 5367. 16 5311 .43 901. 63 -10698.46 5958503. 48 367084. 89 MWD+IFR-AK-CAZ-SC 12805. 15 71 .39 274. 41 5398. 11 5342 .38 908. 79 -10788.31 5958512. 10 366995. 18 MWD+IFR-AK-CAZ-SC 12899. 34 70 .85 274. 56 5428. 58 5372 .85 915. 76 -10877.16 5958520. 51 366906. 46 MWD+IFR-AK-CAZ-SC 12996 .02 70 .65 273. 97 5460. 46 5404 .73 922. 55 -10968.18 5958528. 78 366815. 57 MWD+IFR-AK-CAZ-SC 13091 .23 70 .23 273. 97 5492. 33 5436 .60 928. 76 -11057.68 5958536. 44 366726. 19 MWD+IFR-AK-CAZ-SC 13186 .33 71 .15 274. 14 5523. 78 5468 .05 935. 10 -11147.21 5958544. 24 366636. 79 MWD+IFR-AK-CAZ-SC 13281 .80 71 .43 272. 51 5554. 41 5498 .68 940. 35 -11237.48 5958550. 95 366546. 62 MWD+IFR-AK-CAZ-SC 13376 .71 71 .47 273. 53 5584. 60 5528 .87 945. 09 -11327.33 5958557. 15 366456. 86 MWD+IFR-AK-CAZ-SC 13472. 22 71 .09 274. 21 5615. 26 5559 .53 951. 19 -11417.58 5958564. 72 366366. 73 MWD+IFR-AK-CAZ-SC 13567. 47 71 .26 274. 87 5645. 99 5590 .26 958. 33 -11507.45 5958573. 32 366277. 00 MWD+IFR-AK-CAZ-SC 13662. 70 69 .97 275. 27 5677. 60 5621 .87 966. 27 -11596.93 5958582. 71 366187. 67 MWD+IFR-AK-CAZ-SC 13758. 08 70 .30 275. 25 5710. 01 5654 .28 974. 49 -11686.26 5958592. 38 366098. 49 MWD+IFR-AK-CAZ-SC 13852 .97 71 .55 273. 99 5741. 02 5685 .29 981. 71 -11775.64 5958601. 06 366009. 25 MWD+IFR-AK-CAZ-SC j 13948 .44 71 .75 274. 16 5771. 08 5715 .35 988. 15 -11866.03 5958608. 96 365918. 98 MWD+IFR-AK-CAZ-SC ' 14043 .56 71 .68 273. 93 5800. 92 5745 .19 994. 52 -11956.12 5958616. 80 365829. 01 MWD+IFR-AK-CAZ-SC 14138 .55 71 .33 274. 02 5831. 05 5775 .32 1000. 77 -12045.99 5958624. 50 365739. 27 MWD+IFR-AK-CAZ-SC 14233. 09 71 .31 274. 06 5861. 33 5805 .60 1007. 07 -12135.32 5958632. 26 365650. 05 MWD+IFR-AK-CAZ-SC 14328. 38 70 .97 274. 69 5892. 14 5836 .41 1013. 95 -12225.23 5958640. 60 365560. 27 MWD+IFR-AK-CAZ-SC 14423. 76 71 .34 274. 44 5922. 94 5867 .21 1021. 14 -12315.21 5958649. 25 365470. 43 MWD+IFR-AK-CAZ-SC 14518 .61 71 .09 275. 17 5953. 49 5897 .76 1028. 66 -12404.70 5958658. 22 365381. 09 MWD+IFR-AK-CAZ-SC 14614 .05 71 .17 273. 91 5984. 36 5928 .63 1035. 81 -12494.72 5958666. 83 365291. 20 MWD+IFR-AK-CAZ-SC 14708 .84 70 .41 273. 02 6015. 55 5959 .82 1041. 22 -12584.07 5958673. 70 365201. 96 MWD+IFR-AK-CAZ-SC I 14803 .90 70 .69 272. 68 6047. 20 5991 .47 1045. 67 -12673.59 5958679. 61 365112. 53 MWD+IFR-AK-CAZ-SC 14899 .22 71 .18 274. 47 6078. 34 6022 .61 1051. 29 -12763.50 5958686. 69 365022. 73 MWD+IFR-AK-CAZ-SC 14994. 61 71 .95 274. 70 6108. 50 6052 .77 1058. 53 -12853.71 5958695. 39 364932. 66 MWD+IFR-AK-CAZ-SC 15090. 08 70 .78 274. 92 6139. 01 6083 .28 1066. 11 -12943.85 5958704. 43 364842. 66 MWD+IFR-AK-CAZ-SC 15185. 68 70 .23 275. 88 6170. 91 6115 .18 1074. 59 -13033.57 5958714. 37 364753. 10 MWD+IFR-AK-CAZ-SC 15280. 89 70 .20 274. 72 6203. 14 6147 .41 1082. 87 -13122.77 5958724. 09 364664. 05 MWD+IFR-AK-CAZ-SC 15374. 23 70 .28 274. 61 6234. 70 6178 .97 1090. 01 -13210.33 5958732. 66 364576. 63 MWD+IFR-AK-CAZ-SC 15471 .17 70 .57 273. 32 6267. 18 6211 .45 1096. 33 -13301.44 5958740. 46 364485. 63 MWD+IFR-AK-CAZ-SC 15566 .74 70 .59 273. 24 6298. 95 6243 .22 1101. 48 -13391.43 5958747. 07 364395. 75 MWD+IFR-AK-CAZ-SC ~ 15661 .47 70 .39 273. 54 6330. 59 6274 .86 1106. 76 -13480.56 5958753. 80 364306. 72 MWD+IFR-AK-CAZ-SC I 15756 .74 70 .76 273. 92 6362. 27 6306 .54 1112. 61 -13570.22 5958761. 10 364217. 18 MWD+IFR-AK-CAZ-SC 15851. 25 71 .39 274. 09 6392. 93 6337 .20 1118. 85 -13659.40 5958768. 80 364128. 12 MWD+IFR-AK-CAZ-SC 15946. 63 71 .46 273. 70 6423. 31 6367 .58 1124. 99 -13749.60 5958776. 40 364038. 04 MWD+IFR-AK-CAZ-SC 16041. 69 71 .27 274. 74 6453. 69 6397 .96 1131. 62 -13839.43 5958784. 49 363948. 33 MWD+IFR-AK-CAZ-SC 16135. 69 70 .26 274. 32 6484. 65 6428 .92 1138. 63 -13927.91 5958792. 94 363859. 99 MWD+IFR-AK-CAZ-SC 16231 .75 70 .84 274. 61 6516. 64 6460 .91 1145. 69 -14018.21 5958801. 46 363769. 82 MWD+IFR-AK-CAZ-SC 16326 .97 71 .67 275. 30 6547. 24 6491 .51 1153. 47 -14108.04 5958810. 71 363680. 14 MWD+IFR-AK-CAZ-SC 16422 .24 71 .58 274. 65 6577. 27 6521 .54 1161. 32 -14198.11 5958820. 01 363590. 21 MWD+IFR-AK-CAZ-SC ~ 16516. 67 71 .19 274. 29 6607. 42 6551 .69 1168. 29 -14287.33 5958828. 43 363501. 13 MWD+IFR-AK-CAZ-SC ' 16611. 91 70 .72 274. 30 6638. 49 6582 .76 1175. 03 -14377.10 5958836. 63 363411. 49 MWD+IFR-AK-CAZ-SC 16707. 30 70 .61 273. 74 6670. 08 6614 .35 1181. 34 -14466.89 5958844. 40 363321. 82 MWD+IFR-AK-CAZ-SC 16802. 05 70 .54 274. 17 6701. 59 6645 .86 1187. 51 -14556.04 5958852. 01 363232. 79 MWD+IFR-AK-CAZ-SC ! ~ Halliburton Company Survey Report ('urop,in~: ConocoPhillips Alaska Inc- llate: 8/27/2007 Time: 12:03.14 Page: 5 field: Colville RiveYUnit ('u-ordinate(NE) Reference: Well: CD4-3'L2, True North Site: Nanuq CD4 Veriical(TVD) Reference: CD4-322: 55:7 Weil: CD4-322 Sectiun IVS)Reference: Weli (O.OON.O.OOE,274.60Azi) ~~`cllpath: CD4-322 ~tiurveyCaikulation Method: Minimum Curvature Dh: Oiacle Survc}, MD Intl A;ciin T1 D ~fiys T~'U V/S E/VV ~1apN ~1apti Taul ft deg deg ft ft ft ft ft ft 16897.24 70.88 273.03 6733.03 6677.30 1193.15 -14645.70 5958859.11 363143.24 MWD+IFR-AK-CAZ-SC 16992.17 71.86 272.56 6763.36 6707.63 1197.53 -14735.55 5958864.96 363053.48 MWD+IFR-AK-CAZ-SC 17087.58 71.49 272.55 6793.36 6737.63 1201.57 -14826.03 5958870.46 362963.09 MWD+IFR-AK-CAZ-SC 17181.84 71.08 274.13 6823.60 6767.87 1206.77 -14915.15 5958877.11 362874.07 MWD+IFR-AK-CAZ-SC 17277.15 69.88 273.91 6855.45 6799.72 1213.07 -15004.76 5958884.86 362784.58 MWD+IFR-AK-CAZ-SC 17369.74 71.24 274.53 6886.26 6830.53 1219.49 -15091.83 5958892.71 362697.63 MWD+IFR-AK-CAZ-SC 17463.22 70.94 274.35 6916.56 6860.83 1226.34 -15180.00 5958900.98 362609.59 MWD+IFR-AK-CAZ-SC 17556.17 71.17 274.45 6946.74 6891.01 1233.08 -15267.66 5958909.15 362522.07 MWD+IFR-AK-CAZ-SC 17648.98 71.72 275.40 6976.27 6920.54 1240.64 -15355.32 5958918.13 362434.55 MWD+IFR-AK-CAZ-SC 17742.21 71,15 275.16 7005.95 6950.22 1248.77 -15443.32 5958927.69 362346.70 MWD+IFR-AK-CAZ-SC 17833.15 71.07 275.24 7035.40 6979.67 1256.57 -15529.01 5958936.88 362261.15 MWD+IFR-AK-CAZ-SC 17924.24 70.84 276.08 7065.12 7009.39 1265.06 -15614.69 5958946.77 362175.63 MWD+IFR-AK-CAZ-SC 18017.03 71.14 276.16 7095.34 7039.61 1274.42 -15701.92 5958957.53 362088.57 MWD+IFR-AK-CAZ-SC 18108.38 71.85 275.51 7124.34 7068.61 1283.22 -15788.10 5958967.74 362002.55 MWD+IFR-AK-CAZ-SC 18201.46 71.75 275.15 7153.41 7097.68 1291.43 -15876.14 5958977.38 361914.67 MWD+IFR-AK-CAZ-SC 18294.04 71.50 273.45 7182.60 7126.87 1298.02 -15963.75 5958985.39 361827.18 MWD+IFR-AK-CAZ-SC ' 18387.20 70.64 273.38 7212.82 7157.09 1303.27 -16051.71 5958992.07 361739.32 MWD+IFR-AK-CAZ-SC ~ 18480.76 70.36 274.38 7244.05 7188.32 1309.24 -16139.70 5958999.47 361651.45 MWD+IFR-AK-CAZ-SC ~ 18574.67 69.91 274.29 7275.96 7220.23 1315.92 -16227.77 5959007.58 361563.51 MWD+IFR-AK-CAZ-SC i 18668.54 67.81 273.74 7309.81 7254.08 1322.05 -16315.10 5959015.13 361476.29 MWD+IFR-AK-CAZ-SC. II 18761.52 65.67 273.43 7346.53 7290.80 1327.39 -16400.35 5959021.85 361391.15 MWD+IFR-AK-CAZ-SC 18854.87 62.93 272.76 7387.01 7331.28 1331.94 -16484.34 5959027.77 361307.26 MWD+IFR-AK-CAZ-SC I 18946.18 59.96 271.36 7430.65 7374.92 1334.83 -16564.48 5959031.96 361227.18 MWD+IFR-AK-CAZ-SC 19039.47 57.35 271.00 7479.18 7423.45 1336.48 -16644.13 5959034.90 361147.58 MWD+IFR-AK-CAZ-SC 19131.99 54.46 270.93 7531.03 7475.30 1337.77 -16720.72 5959037.44 361071.02 MWD+IFR-AK-CAZ-SC 19224.66 51.72 270.84 7586.68 7530.95 1338.91 -16794.81 5959039.79 360996.97 MWD+IFR-AK-CAZ-SC 19318.19 48.54 270.96 7646.63 7590.90 1340.04 -16866.57 5959042.08 360925.24 MWD+IFR-AK-CAZ-SC 19411.45 44.94 271.83 7710.53 7654.80 1341.68 -16934.46 5959044.82 360857.39 MWD+tFR-AK-CAZ-SC 19452.00 44.94 271.83 7739.24 7683.51 1342.59 -16963.08 5959046.20 360828.79 PROJECTED to TD • Ct~~t~~oPhiflips Nle7hr7ew Web RePOrtkeg Well Name: CD4-322 Job Type: DRILLING ORIGINAL Time Log Summary 07/26/2007 00:00 01:00 1.00 MIRU MOVE DMOB P Move 20 stds 5" DP & 1 Std 5" HWDP f/ off drillers side to drillers side of derrick to balance the weight for rig move 01:00 01:15 0.25 MIRU MOVE SFTY P PJSM on getting rig ready for move 01:15 03:15 2.00" MIRU MOVE DMOB P Prep rig for move - blow down lines - disconnect service lines - raise stairs - disconnect electric - move ball mill awa 03:15 03:30 025 MIRU MOVE SFTY P PJSM on moving rig 03:30 09:30 6.00 MIRU MOVE MOB P Move rig f/ CD4-306 to CD4-322 - move pump & motor complexes - Skid floor to moving position - Move sub - Spot rig over well - Move pump & motor complexes into place - Connect service lines & high line power " Acce t ri 0600 hrs " 09:30 12:00 2.50 SURFA DRILL RURD P NU surface riser & lines. 12:00 13:00 1.00 SURFA DRILL PULD P Bring BHA components to rig floor 13:00 21:30 8.50 SURFA DRILL OTHR P Load pipe shed w/ 5" DP - 534 jts.- Re air dra chain module. 21:30 00:00 2.50 SURFA DRILL PULD P PU & Std back 5" DP f/ pipe shed - Continue work to repair drag chain module. 07/27/2007 00:00 09:30 9.50 SURFA DRILL PULD P Continue to PU & Std back 5" DP f/ pipe shed - Picked up a total 294 jts. of 534 total needed for Int - Continue re airs on dra chain module 09:30 10:00 0.50 SURFA DRILL PULD P RIH w/ 1 Std HWDP w/ jars - LD jars - PU 1 Jt. HWDP & Std. back in derrick Finish w/ re airs to dra chain module 10:00 12:00 2.00 0 73 SURFA DRILL PULD P MU BHA #1 - bit - motor w/ 1.83 bend - float sub - stab - XO - MWD - UBHO - U load MWD 12:00 12:15 0.25 73 73 SURFA DRILL SFTY P Pre-Spud Safety meeting w/ crew 12:15 13:00 0.75 73 73 SURFA DRILL OTHR P Fill hole & check for leaks - OK - Pressure test mud lines to 3500 psi. a~ ~p3 ~ (~ +~'~ ~~:.. ~~e~d @~mc~` .~ ~J J -1 ~ ~ U ~.1 07/27/2007 13:00 19:30 6.50 73 615 SURFA DRILL DDRL P Spud in - Drill 12 1/4" hole w/ motor f/ 114'to615'MD-614.3'TVD. 40 RPM WOB 10/20 550 GPM @ 1260 psi Total of 5 G ro surve 's taken. 19:30 20:30 1.00 615 615 SURFA DRILL SRVY P Final Gyro survey taken - Survey tool damaged, only inclination read. 30' surveys recorded - Per MWD/IFR, Surve readin s clean. 20:30 22:15 1.75 615 753 SURFA DRILL DDRL P Continue to drill 12-1/4" hole f/ 615' to 753' MD. 751' ND. ADT 4.13 hrs, Rot 2.31 hrs, Slide 1.82 hrs 40 RPM WOB 10/20 450 GPM @ 980 si 22:15 00:00 1.75 753 526 SURFA DRILL CIRC P Stoped Drilling and Circulated - Unable to hold inclination and turn - Potential close approach projected. POOH to 526' MD, Pumping 420 GPM @ 670 psi, 40 RPM. Waiting on direction from town. 07/28/2007 00:00 00:15 0.25 526 753 SURFA DRILL TRIP P RIH from 526' to 753' MD. 00:15 00:45 0.50 753 783 SURFA DRILL DDRL P Drilled 12-1/4" surface hole w/ motor f/ 753' U 783' MD 781' ND. ADT - 0.44 hrs AST - 0.44 hrs WOB 30 k GPM 350 @ 880 psi Trying to get build & turn to move away f/ close approach on well C D4-321 *" Conferred with town prior to drilling ahead 00:45 01:45 1.00 783 783 SURFA DRILL CIRC P Circulate while working pipe f/ 783' to 688' MD. 450 gpm @ 700 psi w/ 40 rpm - 4,000 ft/Ibs toruqe ~* Conferrin with town on lan forward 01:45 12:00 10.25 783 1,742 SURFA DRILL DDRL P Drill 12 1/4" hole w/ Motor f/ 783' to 1742' MD 1619' ND ADT - 6.22 hrs ART - 2.75 hrs AST - 3.47 hrs WOB 20 -25 k RPM 40 GPM 400l500 @ 1050 /1320 psi String wt. - PU 127 SO 120 Rot 125 Torque on/off btm. - 7000/5500 ft/Ibs. Continued gaining distance away f/ close approach to CD4-321. Well back on plan - Well path never crossed any No-go lines on ellipse 07/28/2007 12:00 00:00 12.00 1,742 2,626 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 1742' to 2626' MD 2082' ND ADT - 7.65 hrs ART - 4.82 hrs AST - 2.83 hrs WOB 20-30 k RPM 50 GPM 650 @ 2140 psi String wt. - PU 130 SO 110 Rot 125 Tor ue on - 8000l5500 ft/Ibs. 07/29/2007 00:00 12:00 12.00 2,626 3,169 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 2626' to 3169' MD 2257' ND ADT - 9.05 hrs = ART - 7.82 hrs AST - 1.23 hrs WOB 20/30 k RPM 50 GPM 650 @ 2250 psi String wt. - PU 130 SO 115 Rot 125 Tor ue on /off btm. - 8,500/7,000 ft/Ibs 12:00 18:15 6.25 3,169 3,590 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 3169' to 3590' MD 2388' TVD ADT - 4.58 hrs. = ART 4.03 hrs AST - .55 hrs WOB 20l25 k RPM 50 GPM 650 to 600 @ 2360 to 2150 psi String wt. PU 135 SO 117 Rot 125 Torque on/off btm. - 8,000/7,500 ft/Ibs. 18:15 19:00 0.75 3,590 3,590 SURFA DRILL CIRC P Circ hole clean for wiper trip @ 600 gpm @ 1970 psi w/ 50 rpm - Flow ck Static. 19:00 00:00 5.00 3,590 891 SURFA DRILL WPRT P Wiper trip f/ 3590' to 891' MD. Pumping 550 gpm @ 1660 psi w/ 50 rpm - slow pump rate to 450 gpm @ 1170 psi @ base of permafrost - Blow down TD - Flow ck - Static 07/30/2007 00:00 01:30 1.50 891 3,550 SURFA DRILL TRIP P RIH from 891' to 3550' MD. 01:30 01:45 0.25 3,550 3,590 SURFA DRILL TRIP P Precautionary wash & ream from 3550' to 3590' MD. Stage pumps to 600 gpm with ICP = 2050 psi, 50 RPM, 7500 TRQ. 01:45 02:45 1.00 3,590 3,550 SURFA DRILL CIRC P Circulate BU's while recipricating pipe from 3550' to 3590' MD - Pumping at 600 GPM, 1960 psi, 50 RPM, Trq 7000 ft*Ibs. Flow check - Static. 02:45 06:45 4.00 3,550 981 SURFA DRILL TRIP P POOH on TT from 3550' to 981' MD - Hole taking proper fill. Pulled 25k over from 1172' MD to 981' MD- Worked pipe through tight areas. Up Wt 145k, SO Wt 110k. Worked specific area from 856' to 887' continuously hanging up at same spot ullin 25k over . 06:45 07:30 0.75 981 705 SURFA DRILL CIRC P POOH pumping from 981' to 796' MD - 32spm @ 350 psi - FCP 190psi - Pipe still pulling heavy, work through with 20 rpm, 4000 Trq. RIH clean with no rotary & no pumps to 981' MD - TOOH clean with no aumps to 705' MD. 07/30/2007 07:30 07:45 0.25 705 1,172 SURFA DRILL TRIP P RIH from 705' to 1172' MD - Dwn Wt 125k with slight bobbles from 1050' - 1077' and 1120' - 1130' MD (5-10k over) with Wt dro in back to 125k. 07:45 08:00 0.25 1,172 886 SURFA DRILL TRIP P POOH on TT' from 1172' to HWDP @ 886' MD - Flow check static. 08:00 09:00 1.00 886 168 SURFA DRILL TRIP P Continue POOH on TT from 886' to 168' MD. 09:00 11:30 2.50 168 SURFA DRILL PULD P LD Jars, NMFC's - Download MWD - LD MWD - motor & bit. 11:30 12:00 0.50 SURFA DRILL PULD P LD stab - float sub & XO - Clear floor of BHA tools. 12:00 13:15 125 SURFA CASINC RURD P RU csg tongs & equipment to run 9 5/8" casin . 13:15 13:30 0.25 SURFA CASIN( SFTY P Held pe-job meeting with crew on runnin casin . 13:30 16:45 3.25 0 1,730 SURFA CASINC RNCS P Run 9 5/8" 40# L-80 MBTC casing as follows: FS (Ray Oil Tools silver bullet) 2 jts csg - FC (Halliburton Super Seal) 2 jts csg ( first four connections made up w/ BakerLoc - fill pipe & check floats) 41 jts (45 jts. total in hole to 1730.57' 16:45 17:30 0.75 1,730 1,730 SURFA CASIN CIRC P Establish circ- Circ btms up - Stage pump up to 4 bbl/min @ 210 psi PU wt. 135 SO wt 120 17:30 19:45 2.25 1,730 3,580 SURFA CASIN( RNCS P Continue running 9 5/8" 40# L-80 MBTC casing f! 1730' to 3542' (92 jts total in hole) PU FMC fluted hanger & landing jt. - Land fluted hanger on landing ring w/ FS @ 3580' & FC @ 3499' 19:45 20:15 0.50 3,580 3,580 SURFA CASIN RURD P RD casing equipment - RU cmt head & lines 20:15 21:45 1.50 3,580 3,580 SURFA CEME CIRC P Establish circ - Circ & condition for cmt job - Staging pump up to 6 bbls/min FCP 350 si 21:45 22:00 0.25 3,580 3,580 SURFA CEME~ SFTY P Held pre job meeting w/ crew on cementing 9 5/8" csg 22:00 00:00 2.00 3,580 3,580 SURFA CEME~ DISP P Cement 9 5/8" csg as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pump - Switched over to Dowell - Pumped 5 bbls water - Test lines to 4000 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPush @ 10.5 ppg - Mixed & pumped Lead slurry (Arcticset Lite) @ 10.7 ppg - Observed nut p~ug marker @ shakers w! 404 bbls lead slurry pumped - Pumped down surge can (pumped 419 bbls total lead) - Mixed & pumped tail slurry (Class G w/ additives) 49 bbls @ 15.8 ppg - Dropped top plug w/ 20 bbls water f/ dowell - switched to rig pumps & displaced w/ 245 BBLS of 9.8 ppg mud. 07/31/2007 00:00 00:30 0.50 3,580 3,580 SURFA CEME~ DISP P Continue displacing cement with a total of 245 bbls 9.8 ppg mud pumped @ 6 bpm, 590 psi. Slowed rate to 3 bpm, 450 psi -plug bumped at 2425 sks. FCP 990 psi. Total of 200 bbls cement to surface. Check floats - OK. 00:30 01:30 1.00 3,580 0 SURFA CASIN DHEQ P RU and test 9-5/8" Csg to 3500 psi for 30 mins. 01:30 03:00 1.50 0 0 SURFA CASIN RURD P Blow down cement lines, RD Cement Head, Lnd Jt, Elevators, and Bales. 03:00 04:00 1.00 0 0 SURFA CASIN NUND P ND Surface Riser 04:00 05:30 1.50 0 0 SURFA CASINC NUND P Pull speed head - Set Well head and test to 1000 si. 05:30 10:00 4.50 0 0 SURFA CASIN OTHR P Set BOP's - MU Riser - Change lower VBR Rams. 10:00 10:30 0.50 0 SURFA CASINC OTHR P Install wear bushing 10:30 13:30 3.00 0 2,850 SURFA DRILL OTHR P RIH picking up 90 joints of 5" drill pipe 13:30 13:45 0.25 2,850 2,850 SURFA DRILL CIRC P CBU to condition thick mud 13:45 14:30 0.75 2,850 0 SURFA DRILL OTHR P POOH - stand back drill pipe 14:30 16:45 2.25 0 2,760 SURFA DRILL PULD P RIH picking up 87 joints of 5" drill pipe from i e shed. 16:45 17:45 1.00 2,760 0 SURFA DRILL TRIP P POOH and stood back 5" DP. 17:45 00:00 6.25 0 0 SURFA WELCT BOPE P Pulled wear bushing and set test plug. Filled stack and tested Hydrill 250/3500 psi. Tested Rams, Choke lines, valves, Kill line, and floor valves to 250/5000 psi. Tested 5" and 7". Tested closing unit. Pulled test plug and reset wear bushin . 08/01/2007 00:00 00:30 0.50 0 0 SURFA WELCT OTHR P Set wear bushing - Blow down lines 00:30 02:30 2.00 0 136 SURFA DRILL PULD P MU BHA #2 - 8 3/4" PDC - 7600 GeoPilot - MWD/LWD assembly 08/01/2007 02:30 03:00 0.50 136 136 SURFA DRILL OTHR T Attenpted to initialize tools - communication failure - break out res/nuke collars repair broken connector - MU tools 03:00 03:45 0.75 136 136 SURFA DRILL OTHR P Plug in and Intialize tools 03:45 04:00 0.25 136 136 SURFA DRILL SFTY P PJSM - Loading source LWD collar 04:00 04:15 0.25 136 136 SURFA DRILL OTHR P Load nukes 04:15 05:30 125 136 289 SURFA DRILL PULD P RIH with flex collars and 1 stand of hwdp - Test lines to 3500 psi - shallow test tools - good pulse - weak detection 05:30 06:00 0.50 289 750 SURFA DRILL TRIP P RIH w/ hwdp from 289' to 750' 06:00 06:45 0.75 750 750 SURFA DRILL OTHR P Shallow test tools - good pulse - poor detection 06:45 10:00 3.25 750 2,751 SURFA DRILL TRIP P RIH picking up 5" drili pipe from 750' to 2751' - Ghost reamers 779' & 1832' 10:00 11:30 1.50 2,751 2,751 SURFA RIGMN SVRG P Slip and cut drilling Line - Service Top Drive and Drawworks 11:30 12:30 1.00 2,751 3,475 SURFA CEME~ COCF P RIH - Wash down from 3321' - tagged cement 3475' 12:30 15:45 3.25 3,475 3,590 SURFA CEME~ COCF P Drill out cement - FC - Cement - FS and clean out rathole to 3590' - 650 m/ 2430 si / 60 r m 15:45 16:00 0.25 3,590 3,610 SURFA DRILL DDRL P Drill 20' of new hole to 3610' MD / 2395' TVD ADT=.23 hrs. 16:00 16:15 025 3,610 3,610 SURFA CEME~ CIRC P CBU for FIT - 650 gpm / 2330 psi / 60 rm 16:15 17:00 0.75 3,610 3,610 SURFA CEME~ FIT P RU and perform PIT to 18.0 ppg EMW - RD and blow down lines 17:00 00:00 7.00 3,610 4,368 INTRM1 DRILL DDRL P Drilled w/Geopilot from 3,610' to 4,368' MD 2,643' TVD. ADT 4.59 Hrs. WOB 8/12 K RPM 110. GPM 650. PP 1710 psi. PUW 140 SOW 115 ROVV 130 K. T On/Off 9,500/8,500 Ft Lbs. 08/02/2007 00:00 12:00 12.00 4,368 5,605 INTRM1 DRILL DDRL P Drilled w/Geopilot from 4,368' to 5,605' MD 3,039' ND. ADT 7.03 Hrs. WOB 10/20 K RPM 150. GPM 650. PP 2240 psi. PUW 160 SOW 107 ROW 135 K. Tq On/Off 12,500/11,000 Ft Lbs. ECD 11.02 12:00 00:00 12.00 5,605 6,841 INTRM1 DRILL DDRL P Drilled w/Geopilot from 5,605' to 6,841' MD 3,463' ND. ADT 7.08 Hrs. WOB 10/15 K RPM 150. GPM 650. PP 2580 psi. PUW 155 SOW 125 ROW 140 K. Tq On/Off 12,000/10,000 Ft Lbs. ECD 11.02 08/03/2007 00:00 12:00 12.00 6,841 7,792 INTRM1 DRILL DDRL P Drilled w/Geopilot from 6,841' to 7,792' MD 3,760' TVD. ADT 7.96 Hrs. WOB 10/15 K RPM 150. GPM 650. PP 2450 psi. PUW 190 SOW 120 ROW 145 K. Tq On/Off 14,500/13,000 Ft Lbs. ECD 11.45 08/03/2007 12:00 00:00 12.00 7,792 8,933 INTRM1 DRILL DDRL P Drilled wlGeopilot from 7,792' to 8,933' MD 4,137' ND. ADT 6.99 Hrs. WOB 12/18 K RPM 150. GPM 650. PP 2650 psi. PUW 175 SOW 135 ROW 153K. Tq On/Off 14,000/11,500 Ft Lbs. ECD 11.45 08/04/2007 00:00 12:00 12.00 8,933 10,076 INTRM1 DRILL DDRL P Drilled w/Geopilot from 8,933' to 10,076' MD 4,514' ND. ADT 7.87 Hrs. WOB 12/18 K RPM 150. GPM 650. PP 2460 psi. PUW 186 SOW 139 ROW 162K. Tq On/Off 14,000/12,000 Ft Lbs. ECD 10.96 12:00 00:00 12.00 10,076 11,516 INTRM1 DRILL DDRL P Drilled w/Geopilot from 10,076' to 11,516' MD 4978' ND. ADT 7.87 Hrs. WOB 12/18 K RPM 170. GPM 650. PP 2590 psi. PUW 210 SOW 140 ROW 165K. Tq On/Off 15,500/14,000 Ft Lbs. ECD 10.96 08/05/2007 00:00 12:00 12.00 11,516 12,747 INTRM1 DRILL DDRL P Drilled w/Geopilot from 11,516' to 12,747' MD 5379' ND. ADT 7.36 Hrs. WOB 12/20 K RPM 150/170. GPM 650. PP 2530 psi. PUW 216 SOW 143 ROW 175K. Tq On/Off 17,500/16,000 Ft Lbs. ECD 10.96 12:00 00:00 12.00 12,747 13,955 INTRM1 DRILL DDRL P Drilled w/Geopilot from 12,747' to 13,955' MD 5772' ND. ADT 7.47Hrs. WOB 12/20 K RPM 150/170. GPM 650. PP 2880 psi. PUW 216 SOW 143 ROW 175K. Tq On/Off 17,500/16,000 Ft Lbs. ECD 11.13 08/06/2007 00:00 12:00 12.00 13,955 15,024 INTRM1 DRILL DDRL P Drilled w/Geopilot from 13,955' to 15,024' MD 6118' ND. ADT 7.25 Hrs. WOB 15/20 K RPM 150 GPM 650. PP 2880 psi. PUW 270 SOW 140 ROW 185K. Tq On/Off 21,000/20,000 Ft Lbs. ECD 11.10 12:00 16:30 4.50 15,024 15,528 INTRM1 DRILL DDRL P Drilled wlGeopilot from 15,024' to 15,528' MD 6286' ND. ADT 3.33 Hrs. WOB 18/22 K RPM 150 GPM 650. PP 2470 psi. PUW 275 SOW 145 ROW 210K. Tq On/Off 22,000/20,000 Ft Lbs. ECD 10.86 16:30 17:00 0.50 15,528 15,528 INTRM1 DRILL CIRC NP Circulated and reduced pump rate, loosing fluid over the shakers. 270 GPM/ 60 RPM @ 690 PSI. Lubes in Dilution mud blanked off screens. 17:00 00:00 7.00 15,528 16,167 INTRM1 DRILL DDRL P Drilled w/Geopilot from 15,528' to 16,167' MD 6494' ND. ADT 4.05 Hrs. WOB 18/22K RPM 150. GPM 650. PP 2920 psi. PUW 275 SOW 145 ROW 210K. Tq On/Off 22,000/20,000 Ft Lbs. ECD 10.97 08/07/2007 00:00 12:00 12.00 16,167 17,297 INTRM1 DRILL DDRL P Drilled w/Geopilot from 16,167' to 17,297' MD 6861' ND. ADT 8.16 Hrs. WOB 15/22K RPM 150. GPM 630. PP 3040 psi. PUW 320 SOW 136 ROW 200K. Tq On/Off 26,000/25,000 Ft Lbs. ECD 11.18 12:00 12:45 0.75 17,297 17,400 INTRM1 DRILL DDRL P Drilled w/Geopilot from 17,297' to 17,400' MD 6899' TVD. ADT .74 Hrs. WOB 15/22K RPM 150. GPM 630. PP 3040 psi. PUW 320 SOW 136 ROW 200K. Tq On/Off 26,000/25,000 Ft Lbs. ECD 11.18 12:45 17:45 5.00 17,400 17,400 INTRM1 RIGMN RGRP T POOH to 17,307'. Changed out oil pump in Top Drive. Refilled with oil. RIH to 17,400'. 17:45 00:00 6.25 17,400 17,945 INTRM1 DRILL DDRL P Drilled w/Geopilot from 17,400' to 17,945' MD 7072' ND. ADT 3.98 Hrs. WOB 15/22K RPM 150. GPM 630. PP 3320 psi. PUW 280 SOW 155 ROW 200K. Tq On/Off 21,000/21,000 Ft Lbs. ECD 11.1 08/08/2007 00:00 12:00 12.00 17,945 18,846 INTRM1 DRILL DDRL P Drilled w/Geopilot from 17,945' to 18,846' MD 7383' ND. ADT 8.38 Hrs. WOB 15/22K RPM 150. GPM 600. PP 3520 psi. PUW 305 SOW 145 ROW 209K. Tq On/Off 22,000/20,000 Ft Lbs. ECD 11.43 12:00 19:30 7.50 18,846 19,452 INTRM1 DRILL DDRL P Drilled w/Geopilot from 18,846' to 19,452' MD 7739' ND. ADT 5.38 Hrs. WOB 15/22K RPM 150. GPM 600. PP 3450 psi. PUW 325 SOW 160 ROW 222K. Tq On/Off 24,000/22,000 Ft Lbs. ECD 11.45 19:30 00:00 4.50 19,452 19,162 INTRM1 DRILL CIRC P Pump hi vis sweep. Circ 3X bottoms u at 600 m- 3370 si - 150 r ms. 08/09/2007 00:00 03:15 3.25 19,162 17,671 INTRM1 DRILL WPRT P POOH Backreaming from 19,162' to 17,671'. 550 GPM 120 RPM. Flow checked well OK. 03:15 05:00 1.75 17,671 19,348 ~INTRM1 DRILL WPRT P RIH to 19,348'. 05:00 08:15 3.25 19,348 19,441 INTRM1 DRILL CIRC P Precautionary wash to 19,441'. Circulated hole clean w 600 GPM 120 RPM. Flow checked well OK. 08:15 09:15 1.00 19,441 19,441 IINTRM1 DRILL CIRC P Pumped casing pill to bit. 09:15 12:00 2.75 19,441 17,586 INTRM1 DRILL TRIP P POOH displacing casing running pill from 19,441' to 17,586'. 12:00 19:00 7.00 17,586 11,192 INTRM1 DRILL TRIP P Check flow. Static. POH on trip tank from 17,586'to 11,192'. Tightspot. 75k over ull. 19:00 19:45 0.75 11,192 10,932 INTRM1 DRILL TRIP P RIH to 11,219'. Break circulation. POH w/ pump to 10,932' at 500 gpm - 1960 si - 100 r ms. 19:45 21:00 1.25 10,932 10,110 INTRM1 DRILL TRIP P POH on trip tank to 10,110'. Tight saot. 75k over pull. 08/09/2007 21:00 00:00 3.00 10,110 8,553 INTRM1 DRILL TRIP P RIH to 10,170'. POH with pump to 8553' at 500 gpm - 1680 psi - 120 r ms. 08/10/2007 00:00 01:45 1.75 8,553 8,520 INTRM1 DRILL TRIP NP POOH to 8,553' Pulled tight. Washed and reamed ti ht s ot to 8,520'. 01:45 07:00 5.25 8,520 4,368 INTRM1 DRILL TRIP P POOH on trip tank from 8,520' to 4,368'. 07:00 07:45 0.75 4,368 4,368 INTRM1 DRILL CIRC P Hole drag up to 30 K. Broke circulation and CBU. 600 gpm 2,070 si 120 r m. 07:45 09:00 1.25 4,368 3,512 INTRM1 DRILL TRIP P POOH on trip tank from 4,368' to 3,512'. Checked well OK. 09:00 12:00 3.00 3,512 744 INTRM1 DRILL PULD P Pumped dry job. POOH from 3,512' to 744' la in down drill i e.. 12:00 13:30 1.50 744 95 INTRM1 DRILL PULD P POH LD HWDP, jars and NMFC's. 13:30 13:45 025 95 95 INTRM1 DRILL SFTY P PJSM on removing sources from MWD tools. 13:45 17:15 3.50 95 0 INTRM1 DRILL PULD P Remove sources. Download MWD. LD MWD, GeoPilot and bit. 17:15 18:00 0.75 0 0 INTRM1 DRILL RURD P RD GeoSpan unit. Pull wear bushing. Install thin wear bushin . 18:00 20:00 2.00 0 0 INTRM1 CASIN RURD P Change out saver sub to 4" XT for fill u tool. RU to run 7"cs . 20:00 23:15 3.25 0 3,426 INTRM1 CASIN RNCS P RIH w/ 80 jts 7" 26# L-80 csg to 3426'. 23:15 00:00 0.75 3,426 3,426 INTRM1 CASIN CIRC P Circulate one csg volume at 5 bpm at 340 si. 08/11/2007 00:00 04:45 4.75 3,426 7,706 INTRM1 CASINC RNCS P RIH w/ 100 jts 26# L-80 BTCM casing from 3,426' to 7,706'. 04:45 05:45 1.00 7,706 7,706 INTRM1 CASINC CIRC P Circulate casing staging pumps up to 4.5 BPM. FCP 500 si. 05:45 10:30 4.75 7,706 11,148 INTRM1 CASINC RNCS P RIH w/ 80 jts 7" 26# L-80 BTCM casing from 7,706'to 11,148'. Tam Port Collar between Jts 234 and 235. 10:30 12:30 2.00 11,148 11,148 INTRM1 CASINC CIRC P Circulate casing staging pumps up to 5 BPM. FCP 610 si. 12:30 17:15 4.75 11,148 14,808 INTRM1 CASINC RNCS P RIH w/ 85 jts 7" 26# L-80 BTCM csg from 11,148' to 14,808'. 17:15 19:30 2.25 14,808 14,808 INTRM1 CASINC CIRC P Circulate and condition mud. Stage um s u to 4.5 b m at 610 si. 19:30 23:15 3.75 14,808 17,375 INTRM1 CASINC RNCS P RIH w/ 60 jts 7" 26# L-80 BTCM csg from 14,808' to 17,375'. 23:15 00:00 0.75 17,375 17,375 INTRMI CASIN( CIRC P Circulate and condition mud at 3.5 b m at 680 si. 08/12/2007 00:00 01:15 1.25 17,375 17,375 INTRM1 CASIN CIRC P Circ. and cond mud. Stage pump to 4.5 bpm, 620 psi, Up wt 330k - Dn wt 145k 01:15 04:30 3.25 17,375 19,436 INTRM1 CASIN RNCS P Cont. to RIH w/ 7" casing from 17375' and landed out at 19436'. 04:30 05:00 0.50 19,436 19,436 INTRM1 CEME~ RURD P UD Franks fill-up tool. Blowdown TD, R/U cement e ui . 05:00 07:30 2.50 19,436 19,436 INTRM1 CEME CiRC P Est. circ. Circ and cond. for cement job. Stage pump to 4.5 bpm at 610 08/12/2007 07:30 07:45 0.25 19,436 19,436 INTRM1 CEME~ SFTY P PJSM 07:45 11:15 3.50 19,436 19,436 INTRM1 CEME~ SFEQ P Dowell pumped 5 bbls CW-100. Tested lines to 3700 psi. Pumped 25 bbls CW-100, 40 bbls 12.5 MudPush, Dropped bottom plug, Pumped 30 bbls 11 ppg lead cement (42 sx), 37 bbls 15.8 ppg cement (177 sx), Dropped top plug and pumped 5 bbls fresh water. Rig pumped 40 bbls inhibited 9.6 brine followed by 689 bbls 9.6 brine. Bumped plug. Had flow out annulus. Shut well in. 11:15 11:30 0.25 19,436 19,436 INTRM1 CEME~ OTHR P Bled off pressure. Checked float equip. OK. 11:30 12:30 1.00 19,436 19,436 INTRM1 CASINC DHEQ P RU and test casing to 3500 psi for 30 min. 12:30 13:30 1.00 19,436 19,436 INTRMI CASIN( RURD P Bleed off pressure. Check floats. OK. Annulus pressure - 0 psi. Open well. Static. RD cement head and csg e ui ment. Blow down choke. 13:30 14:30 1.00 0 0 INTRM1 CASIN( DHEQ P Pull thin wear bushing. Install pack-off and test to 5000 si. 14:30 15:15 0.75 0 0 INTRM1 CASIN RURD P LD long bails. RU short bails. 15:15 16:45 1.50 0 0 INTRM1 RIGMN' SVRG P PJSM. Slip and cut 120' drilling line. Service to drive. 16:45 00:00 7.25 0 4,303 INTRM1 CEME TRIP P PU and RIH Tam Combo Tool and 4" DP to 4303'. 08/13/2007 00:00 06:15 6.25 4,303 9,330 INTRM1 CEME~ PULD P RIH Tam Combo Tool on 4" DP from 4,303' to 9,330' picking up DP from i e shed. 06:15 08:30 2.25 9,330 9,398 INTRM1 CEME~ PULD P Located Tam Port Collar @ 9,398' and s aced out with u s. 08:30 09:15 0.75 9,398 9,398 INTRM1 CEME~ RURD P Rigged up Piug Drop Head and cement lines. PJSM. 09:15 10:15 1.00 9,398 9,398 INTRM1 CEME~ OTHR P Established circulation, dropped ball and displaced to seat pressured up to 800 si. 10:15 12:00 1.75 9,398 9,398 INTRM1 CEME OTHR P Bled pressure to 200 psi and shifted Port Collat to open position. Cups lost ressure and would not re en a e. 12:00 13:30 1.50 9,398 9,398 INTRM1 CEME~ DISP P Dowell pumped 5 bbls CW100. Tested lines to 3500 psi. pumped 20 Bbls CW 100 .Pumped 40 bbls 12.5 ppg MudPush, 41 bbls 15.8 cement (190 sx), drop closing dart, 20 bbis water followed by 57.9 bbls mud. CIP @ 1328 Hrs. 13:30 14:15 0.75 9,398 9,398 INTRM1 CEME~ CIRC P Closed Tam Port Collar with Bag closed. Tested to 2000psi. Reversed out 110 Bbls 4.5 BPM 950 si. 14:15 14:45 0.50 9,398 9,490 INTRM1 CEME~ OTHR P Rigged down and laid down Baker plug dro in head. RIH 1 stand to 9,490'. 14:45 15:15 0.50 9,490 9,490 INTRM1 CEME~ CIRC P Sheared out choke with 2900 psi. Reverse circulated 100 Bbis. No cement. 08/13/2007 15:15 15:45 0.50 9,490 9,365 INTRM1 CEME~ TRIP P POOH to 9,365' laying down 4" DP and u s. 15:45 16:30 0.75 9,365 9,365 INTRM1 CEMEf~ OTHR P Rigged up and tested casing to 3500 si. Blew down lines. 16:30 00:00 7.50 9,365 315 INTRM1 CEME~ TRIP P POOH laying down 4" DP to 315' 08l14/2007 00:00 01:00 1.00 315 0 INTRM1 CEME TRIP P Finish POH LD 4" DP 01:00 01:15 0.25 0 0 INTRM1 CEME~ PULD P Break Tam combo tool connections and LD same. 01:15 01:30 0.25 0 0 COMPZ RPCOh OTHR P Pull wear bushing. Monitor well on trip tank. 01:30 02:45 1.25 0 0 COMPZ RPCOh RURD P Clear floor. RU 4 1/2" tbg equipment. 02:45 03:00 025 0 0 COMPZ RPCOti SFTY P PJSM on running tbg. 03:00 15:00 12.00 0 10,039 COMPZ RPCOti RCST P RIH w/ 4 1/2" 12.6# L-80 IBTM tbg & completion equipment as fo~lows: WLEG - tbg pup jt. - XN nipple - 1 jt tbg - tbg pup jt. - Baker S-3 packer w/ mill out extension - tbg pup jt. - 2 jts. tbg - tbg pup jt. - Camco GLM - tbg pup jt. - 245 jts. tbg to 10,039.46' Total of 248 jts. - Pkr took wt. PU on pkr. Pkr set. WLEG at 10,039' and top of kr at 9966'. 15:00 16:15 1.25 10,039 10,039 COMPZ RPCOh CIRC T RU & attempt to circ - no circulation - RD 16:15 17:00 0.75 10,039 10,039 COMPZ RPCOti PACK T Drop rod/ball assembly - pressure up on tb to 2500 si to set acker RD 17:00 21:00 4.00 10,039 10,039 COMPZ RPCOh SLKL T RU slick line - RIH & pull dummy valve f/ GLM 21:00 22:15 1.25 10,039 10,039 COMPZ RPCO CIRC T RU & pump tbg volume (150 bbls) slicke water @ 3 bbls/min @ 220 psi - RD 22:15 00:00 1.75 10,039 10,039 COMPZ RPCOti SLKL T RIH w/ slick line & over shot to pull ball/rod assembl 08/15/2007 00:00 02:45 2.75 10,039 10,039 COMPZ RPCOh SLKL T RIH w/ slick line. Retrieve RHC catcher. POH. RD. 02:45 13:30 10.75 10,039 10,039 COMPZ RPCOti PULD P LD 375 jts 5" DP from derrick in mousehole. 13:30 13:45 0.25 10,039 10,039 COMPZ RPCOh SFTY T PJSM on RU WL and chemical ~ cutters. ' 13:45 15:00 1.25 10,039 10,039 COMPZ RPCO RURD T PU 4 1/2" elevators & RU Schulumber er wireline 15:00 19:00 4.00 10,039 10,039 COMPZ FISH ELNE T RIH w/ chemical cutter - correlate w/ CCL to cut tbg @ 9965' - 1' above top of packer - fire cutter- positive indication @ surface of cut - POOH w/ wireline & tool string - RD Schlumber er 19:00 00:00 5.00 9,965 5,900 COMPZ FISH TRIP T RU - Pull & LD 4 1/2" tbg f/ 9965' to 5900' 100 'ts of 247 'ts to ull 08/16/2007 00:00 05:30 5.50 5,900 0 COMPZ FISH TRIP T Finish POH LD 147 jts 4 1/2" tbg. 05:30 06:00 0.50 0 0 ICOMPZ FISH RURD T RD tbg equipment and clear floor. 08/16/2007 06:00 07:15 1.25 0 0 COMPZ WELC EQRP T Change top pipe rams from 4 1/2" x 7' VBR's to 4" solid bod . 07:15 12:30 5.25 0 0 COMPZ WELCT BOPE T Test all BOPE to 250 - 5000 psi with the annular to 3500 psi. Witness of test was waived by AOGCC rep Chuck Scheve. 12:30 13:30 1.00 0 0 COMPZ WELCT OTHR T LD test jt. Clear floor. Blow down top drive and choke. 13:30 13:45 0.25 0 0 COMPZ FISH OTHR T Install wear bushing. 13:45 21:15 7.50 0 0 COMPZ RPCOti PULD P LD remaining 5" DP f/ derrick 21:15 00:00 2.75 0 COMPZ FISH OTHR T Clean up rig floor - Bring milling assembly componets to rig floor - finish loading 4" DP in shed (601 jts total 08/17/2007 00:00 01:45 1.75 0 504 COMPZ RPCOti PULD T MU fishing BHA. Metal muncher pkr mill, 2-boot baskets, bit sub, string magnet, bumper sub, oil jar, 6- 4 3/4" DC's, accelerator jar, XO, and 9 jts 4" HWDP. 01:45 12:00 10.25 504 9,958 COMPZ RPCO TRIP T PU and a RIH w/with 298 jts 4" DP f/ 504' to 9958'. Rotated through port collar at 9398'. No problems. PU wt. 175 SO wt. 115 Rot wt 140 - Torque 9.5 k 12:00 12:15 0.25 9,958 9,962 COMPZ FISH CIRC T Establish circ - Wash down f/ 9958' to 9962' 12:15 15:15 3.00 9,962 9,966 COMPZ FISH MILL T Mill on packer f/ 9962' to 9966' 15:15 16:30 125 9,966 9,966 COMPZ FISH CIRC T Pump Hi -vis sweep - Circ 2 X btms up - 315 m 1263 si w/ 100 r m 16:30 17:00 0.50 9,966 9,966 COMPZ RIGMN SVRG T Service TD 17:00 00:00 7.00 9,966 17,167 COMPZ FISH TRIP T Push packer down hole f/ 9966' to 17,167' - picking up 4" DP f/ pipe shed 175 stds 08/18/2007 00:00 02:00 2.00 17,167 19,221 COMPZ FISH TRIP T Continue to push fish from 17,167' to 19,221'. Top of fish at 19,221'. Bottom of fish at 19,291'. 02:00 04:45 2.75 19,221 19,199 COMPZ FISH CIRC T LD single to 19,199'. Pump Super Sweep at 6.5 bpm - 1650 psi - 70 rpm -18,000 ft Ib torque. Circulate 2 bottoms u . 04:45 05:00 0.25 19,199 19,067 COMPZ FISH TRIP T POH to 19,067. 05:00 05:15 025 19,067 19,067 COMPZ RIGMN SFTY T PJSM on slip and cut drilling line. 05:15 06:30 1.25 19,067 19,067 COMPZ RIGMN' SVRG T Slip and cut 60' of drilling line. Service to drive. 06:30 16:00 9.50 19,067 504 COMPZ FISH TRIP T Pump dry-job. POH on trip tank from 19,067' to 504' - 16:00 17:30 1.50 504 0 COMPZ FISH PULD T Std back HWDP & DC's - LD milling assembl 17:30 18:00 0.50 0 0 COMPZ FISH OTHR T Close blind rams & test 7" csg to 3500 psi for 10 mins. - OK - bleed off o~en rams & RD 08/18/2007 18:00 18:30 0.50 0 0 COMPZ FISH OTHR T Pull wear bushing - Set screen wear bushin - 18:30 20:30 2.00 0 0 COMPZ FISH OTHR T Flush ram bodies in BOP stack 20:30 22:00 1.50 0 0 COMPZ FISH OTHR T Pull screen wear bushing - Set test plug - test top rams & rams bodies doors to 250 & 5000 psi - Pull test plu - set wear bushin 22:00 23:00 1.00 0 491 COMPZ FISH PULD T MU 6" wash shoe assembly - RIH w/ DC's & HWDP to 491' 23:00 00:00 1.00 491 1,444 COMPZ FISH TRIP T RIH w/ wash shoe f/ 491' to 1444' 08/19/2007 00:00 07:15 7.25 1,444 10,199 COMPZ FISH TRIP T RIH w/ wash shoe from 1440' to 10,199'. Reverse circ 1 drill pipe volume eve 2000'. 07:15 07:30 0.25 10,199 10,199 COMPZ FISH CIRC T Drill pipe running over. Well out of balance. Pump 30 bbls FW down annulus to balance well. 07:30 15:30 8.00 10,199 19,150 COMPZ FISH TRIP T RIH w/ wash shoe from 10,199' to 19,150' Reverse circ 1 drill pipe volume eve 2000'. 15:30 18:00 2.50 19,150 19,150 COMPZ FISH CIRC T Reverse circ 100 bbls brine - Chnage well over to 9.2 ppg clean brine - Spot 40 bbls inhibited brine f/ 19,150' to 18,110' 18:00 18:30 0.50 19,150 19,150 COMPZ FISH OTHR T Clean out under shakers 18:30 00:00 5.50 19,150 11,056 COMPZ FISH TRIP T POOH on TT f/ 19,150' to 11,056' - Pum ed d ~ob 12,203' 08/20/2007 00:00 03:30 3.50 11,056 582 COMPZ FISH TRIP T Continue POH on trip tank from 11,056' to 582'. 03:30 04:30 1.00 582 582 COMPZ RIGMN SVRG T PJSM. Slip and cut drilling line. Service ri . 04:30 06:45 2.25 582 0 COMPZ FISH TRIP T POH and std back HWDP. LD DC's, 'ars and rota shoe. 06:45 07:30 0.75 0 0 COMPZ WELCT EQRP T PJSM. Change top pipe rams from 4" to 4.5" x 7" VBR's. 07:30 08:00 0.50 0 0 COMPZ WELCT OTHR T Pull wear bushing. Set test plug. 08:00 08:30 0.50 0 0 COMPZ WELCT BOPE T Test upper pipe rams to 250-5000 psi. 08:30 08:45 0.25 0 0 COMPZ RPCOh RURD T Finish rig up tbg equipment. 08:45 09:00 0.25 0 0 COMPZ RPCOh SFTY T PJSM on running 4 1!2" tbg. 09:00 19:00 10.00 0 10,043 COMPZ RPCO RCST T RIH w/ 4 1/2" WLEG, 10' pup, XN nipple, 1 jt 4 1/2" 12.6# L-80 IBT tbg , Baker Premier Pkr with pups, 2 jts tbg and Camco KBG-2 GLM with dummy valve and 245 jts 12.6# L-80 IBT tbg to 10,043.45' 19:00 23:15 4.25 10,043 14,555 COMPZ RPCOti RCST P Continue RIH w! 4 1/2" completion f/ ~~ 10,043' to 14,555' - 360 'ts total ran ~ 23:15 23:30 0.25 14,555 14,555 ICOMPZ RPCOti OTHR P Change tbg elevators f/ 75 ton to 125 ton 08/20/2007 23:30 00:00 0.50 14,555 14,957 COMPZ RPCOh RCST P Continue RIH w/ 4 1/2" completion f/ 14,555' to 14,957' - 370 jts. ran of 452 'ts to run 08/21/2007 00:00 04:30 4.50 14,957 18,299 COMPZ RPCOh RCST P Run 4 1/2" Completion equipment from 14,957' to 18,264' - MU FMC tubing hanger and land in wellhead (total of 452 jts.) - WLEG @ 18,299', XN nipple @ 18,287', Packer @ 18,226', GLM @ 18,119', DB ni le 2289' 04:30 05:45 1.25 18,299 0 COMPZ RPCOh DHEQ P RILDS - LD LJa - install TWC - MU LJb and test tubing hanger seals to 5000 si. 05:45 08:15 2.50 0 0 COMPZ RPCOh NUND P Pull mousehole - ND riser and BOP stack 08:15 09:30 1.25 0 0 COMPZ RPCOti NUND P Install and test tree to 5000 psi 09:30 10:00 0.50 0 0 COMPZ RPCOh RURD P RU circulating manifold and hardlines to tubin and annulus 10:00 10:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM on pumping packer fluid and diesel freeze rotection 10:15 14:15 4.00 0 0 COMPZ RPCOh CIRC P Pressure test lines to 2000 psi - Displace well with 296 bbis of 9.2 ppg inhibited brine followed by 323 bbls of diesel 14:15 15:15 1.00 0 0 COMPZ RPCOh OTHR P Shut in well head (800 psi tbg - zero psi ann) bleed off lines - remove hardline and tree cap - RU Doyon lubricator and drop packer setting ball/rod - LD lubricator - MU hardline and tree ca 15:15 17:00 1.75 0 0 COMPZ RPCOh PACK P Test lines to 5000 psi - Set packer and test tubing with 4000 psi - bled to 3700 psi in 30 minutes - Line up and test annulus to 3500 psi - bled to 3490 si in 30 minutes 17:00 19:15 2.25 0 0 COMPZ RPCO RURD P Blow down lines - RD lines & manifold - RU FMC lubricator - set BPV - Secure well 19:15 00:00 4.75 0 0 COMPZ FISH PULD T Install mouse hole - LD 4" DP f/ derrick f/ derrick 08/22/2007 00:00 15:00 15.00 0 COMPZ FISH PULD T Finish LD 4" DP f/ derrick for rig move 15:00 16:00 1.00 I COMPZ RPCOti OTHR P Pull mouse hole - clean up rig floor - Release riq (a~ 1600 hrs. 8/22./2007 ~ ~ Daily Operations Summary Report C D4-322 Job: DRILLING ORIGINAL ;,~. Date E~,~~ _~r;t= 7i2b/[GU7 17/2%/200% i 7'2712Q07 7,'28/2(107 i 7/28/2007 7/29/2007 ', 7/29(2007 ~ 7!30/2007 ~7I30/20ti7 ;7/31/2007 7/31/2007 8/1/2007 8(2/2007 18/3/2007 8/4!2007 8/5/2007 8/6/2007 ~ 8/7/2007 ', 8/8/2007 ; 8/9/2007 '.8/10/2007 i 8/11 /2007 8!1212007 i 8/13/2007 8/14/2007 18/'15.'2007 8116;'2007 8/ 17'2007 8'18/2007 t5/ 10;`2 G (17 i ~ 8/20/2007 18/21 /2007 ,._ _ Last 24hr Swu _._ _- -- Move hg f/ CD4-306 to CD4-322 - Connect service fines & hook up to high line power - NU surtace riser -Load pipe shed w/ 5" DP - PU & Std back 5" DP. Continue work to repair drag chain module. "` Rig Accept at 0600 hrs 1 Std Back 98 Stds of 5" DP - MU BHA #1 -Pre-Spud Mtg -Spud @ 1300 hrs. Drill 1225" Surface hole from 114' to 1753' MD. Drilled 12-114" Surface hole with motor from 'S' to 2626' MD ~ Drilled 12-1/4"Surface hole with motor fl 2,626' to 3;590'. MD -Circ hole clean at TD Wiper trip to 891' MD. 1 Wash down to TD @ 3590' MD -POOH on TT working through Gyht areas - LD BHA - RU ~ Run 9-yid" Gsg to ~ 3580' MD -Circ & Condition mud -Pumping Cement. Cement 9-5/8" Csg ~ Test to 3500 psi for 10 mins - ND Riser - NU Csg Head'8~ BOPE -Test ROPE. Tested BOP. PU BHA and RIH. Gut drilling line. Drilled out shoetrack. Drilled 20' new hole. CBU. FIT to 18 PPG E?~W. Drilled from 3,610' to 4,368'. Drilled from 4,368' to 6,841'. Drilled from 6,842' to 8,933'. I LDrilled from 8,933' to 11,516'. Drilledfrom 11,516'to 13,955'. (Drilled from 13,955' to 16,167. i; l Drilled from 16,167 to 17,945'. ~ Drilled from 17,945' to 19,452'. CBU X 3. Wiper Trip. Made wiper trip to 17,761'. Circulated hole clean. POOH spotting casing pill Continue POOH to 8553'. ', POH LD 3600' DP and BHA. RIH w/ 7" csg to 7706' RIH w/ 7" csg f/ 3426' to 17,374' ~ RIH wl 7" csg to 19,436'. Cerraent and test csg. RIH w/ combo fool on 4" DP: RIH w/ combo tool. Perform 2nd stage cement job. POH LD 4" DP. 'Finish POOH & LD 4" DP - RU & Run 4 1/2" completion to 10039' -Packer set - RU Slick line & pull GLM valve ',spot slick water in tbg - RIH to pull balllrod RIH w/ SL pull rod/ball 3 RHC plug - LD 5" DP - P.U SWS -Cut the rig 9965' - POOH w/ tbq_ !Finish LD tbg -Test ROPE - LD remaining 5" DP Nderrick -Finish loading 4" DP in shed MU milling assembly - RIH to top of fish -Mill packer f/ 9962' to 9966' -Circ 2 x btms up -Push fish to 17,167 ' (picking up 4" DP f/ shed) Cont. RIH & push fish to tap of cmt @ 19,291'.-Pump sweep & circ. 2 x btms up - CBSdrill line -POOH - LD mill Test csg -flush stack - MU 6" wash shoe -,RIH 8/1/20(17 8/2/2007 813!2007 8/4/2007 8/5/2007 816.'%007 817,'2007 re 21)07 8'912007 J110 2(107 3111 /2007 of 12/2007 '~ 8/13!2007 8/14/2007 8!1512007 8/16/2007 8/17/2007 8/18/2007 ' 8/19!2007 8120,'2007 RIH wi ash shoe to 19.150' -reverse circ DP vol every 2000' Change over to 9.2 ppg clean brine - inhibited brine to 18,110' -POOH w/ wash shoe to 11,056' 8!2112007 I Finish POOH w/ wash shoe -C&S drill line - RU to rune completion -Run 4 1/2" completion to 14,957' 8'22;2007 Finish running completion NU BOP - NU tree -Pump packer fluid & freeze protect -Set packer & tell f/ derrick Spot 40 bbls LD 4" DP 8/22/2007 2/22/2007 Finish LD 4" DP -Clean up riq floor -`Release rig CD4-322 Well Events Summary DATE Summary 9/3/07 RAN SCMT CEMENT BOND LOG. 500 PSI ON THE TUBING AT THE TIME OF LOGGING FROM CABLE DISPLACEMENT. LOGGED FROM 19175' THROUGH JEWELRY. HIGH QUALITY CEMENT OBSERVED ABOVE AND BELOW THE KUPARUK C SAND. PERFORATE WITH 20' OF 2 7/8" POWERJET OMEGA FROM -- 18538'-18558' CORRELATED TO HALLIBURTON LWD. TUBING PRESSURE 0 PSI BEFORE PERFORATING AND 220 PSI WHEN OUT OF HOLE WITH ELINE. 9/4/07 RAN SBHP SURVEY. LOGGED PRESS/TEMP/GR/CCL FROM 18000' TO SURFACE. RESULTS: 18548' (2890 PSI, 163.5 DEG F), 18320' (2854 PSI, 160.8 DEG F), 18220' (2839 PSI, 159.1 DEG F), 18000'(2813 PSI, 157 DEG F). 9/7/07 GAUGE TUBING TO 3.82" TO 2285' RKB, BRUSH "DB" NIPPLE @ SAME, SET 3.813" A- 1 INJECTION VALVE @ "DB" NIPPLE @ 2285' RKB Cement Detail Report CD4-322 Intermediate Casing Cement 'Primary Job Type 'Job Category !AFE / RFE ! Maint.# ;Actual Start Date . Spud I KO Date End Date ,DRILLING ORIGINAL DRILLING I WCC.WAS.0858.14.01 i 7/26/2007 7/27!2007 ~ 8/22/2007 -- --- -- -- Cement Details ,'Description Cementing Start Date i Cementing End Date I Wellbore Name Intermediate Casing Cement 8/12/2007 08:00 ! 8/12/2007 11:10 j _ i CD4-322 !Comment .Dowell pumped 5 bbls CW-100. Tested lines to 3700 psi. Pumped 25 bbts CW-100, 40 bbls 12.5 MudPush, Dropped bottom plug, Pumped 30 bbls 11 ppg ,lead cement (42 sx), 37 bbls 15.8 ppg cement (177 sx), Dropped top plug and pumped 5 bbls fresh water. Rig pumped 40 bbls inhibited 9.6 brine followed by 689 bbls 9.6 brine. Bumped plug. Had flow out annulus. Shut well in. CementStages _-- _-- -- -- _--- ---_-_-- -- S- ~~ # 1 ---- - _- ---. _ ~-- - -- iDescription jObjective ;Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtrn (...(Top Plug? ~Btm Plug? ,Intermediate Casing Primary ~ 17,922.0 19,436.0 Yes Yes Yes 'Cement ~ ~ Q (start) (bbVmin) O (end) (bbl/min) 'Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) (Rotated"/ (Pipe RPM (rpm) ! 5 ~ 4 5 900.0 1,500.0 j No _ i No _ I .Depth tagged (ftK6) ~ Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) 1 Cement Fluids ~ Additives ici~~~~ ',Fluid Type ~ (Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) ~ !Class ~olu Pumped (bbl) I Lead Cement 17,922.0 17,121.0 50 G 30.0 ~ ' ,Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) Cmpr " 3.37 11.29 11.00 I _ _ Additives _ ----~ ',Additive (Type -- Concentration Conc Unit label Fluid _ _ _ !,Fluid Type 'Fluid Description ;Estimated Top (ftK8) _ ;Est Btm (ftK6) ( Amount (sacks) 'Class V oVu Pilmped (l~bl) 1, ':Tail Cement 17,121.0 19,436.0 177 G 37.0 l 'Yield (ft°Isack) L Mix H2O Ratio (gal/sa... Free Water (%) Density {Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) Cmp 1 s' ~ 1.16 _ 5.07 I 15.80 _ J Additives '':Additive Type Concentration Conc Unit label ( ;Stage # 2 _ _ _ _ ':Description Objective '!Top (ftK6) Bottom (ftKB) Full Return?~mnt Rtrn (... Top Plug? Btm Plug? Intermediate Casin g 2nd stage K-2 ~ 8,390.0 9,398.0 Yes Yes ~ No Cement !O (start) (bbllmin) O (end) (bbl/min) O (avg) (bbl/min) P (final ) (psi) P (bu mp) (psi) Recip? Stroke (ft) ;Rotated? Pipe RPM (rpm) ~ 5 ' i 3 4 , 700.0 ' 1,400.0 ! No l O t T ftK6 No t Di ill O t i D (Depth tagged (ftK6) Tag Method Depth u ) P ug Drilled o ( ame n) r u er ( ~ C ~ Comment _ Cement Fluids 8 Additives __. -- -- - -- Fluid -- -- ______ ;Fluid Type ; Fluid Description Estimated Top (ftK6) (Est Btm (ftKB) jAmount (sacks) Class Volume Pumped (bbl) ?intermediate Ceme nt 8,390.0 ! 9,398.0 190 G 40.0 ;Yield (ft'Isack) Mix H2O Ratio (gatlsa... Free Water (%) (Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) ~ 1.17 5.10 15.80 _ ~ _ - ~ Additives Cement Detail Report CD4-322 ', Surface Casing Cement --- - -- !Primary Job Type jJob Category AFE 1 RFE I Maint.# Actual Start Date Spud! KO Date End Date DRILLING ORIGINAL DRILLING WCC.WAS.0858.14.01 I 7/26!2007 7/27/2007 __8/2212007 ---- _ - - !:Cement Details - - - _ _ _ _ _ _ _ _ _ _ -- DescriptionCementing Start Date iCementing End Date Wellbore Name 'Surface Casing Cement_ _ _ 1_ 7/30/2007 22:00 ~ 7/31/2007 00:30 CD4-322 Comment Cement 9 5/8" csg as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pump -Switched over to Dowell -Pumped 5 bbls water -Test lines to 4000 psi -Dropped btm plug -Mixed & pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped Lead slurry (Arcticset Lite) @ 10.7 ppg -Observed nut .plug marker @ shakers w/ 404 bbls lead slurry pumped -Pumped down surge can (pumped 419 bbls tatal lead) -Mixed & pumped tail slurry (Class G w/ :additives} 49 bbis @ 15.8 ppg -Dropped top plug w! 20 bbls water f/ doweA -switched to rig pumps & displaced w/ 245 BBLS of 9.8 ppg mud. Continue ~ displacing cement with a total of 245 bbls 9.8 ppg mud pumped @ 6 bpm, 590 psi. Slowed rate to 3 bpm, 450 psi -plug bumped at 2425 sks. FCP 990 psi. ,Total of 200 bbls cement to surface. Check floats - OK. __. _-__ Cement Sta es - --- -- --- - -- - - -- I Stage # <Stage Number?> ~ 'Description Objective jTop (ftKB) Bottom (ftKB) Full Rett`n? ICmnt Rtrn (...(Top Plug? Btm Plug? ;Surface Casing Cement I 36.0 3,580.0 ! (Novi ~ 200.0 Yes Yes ',Q (start) (bbl/min) O (end) (bbl/min) TO (avg) (bbUmin) P (final) (psij P (bump) (psi) Recip? Stroke (ft) Rotafed? Pipe RPM (rpm! ~ 460.0 990.0 ~ Yes 15.00 No 8 5 ',Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) i _ --- - - ~ ~ --- - - - ,Comment Cement Fluids & Additives :.Fluid --- _- '.Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ( Glass Volume Pumped (bbl) .Lead Cement ',,Yield (ft fsack) I Mix H2O Ratio (gal/sa... ' 0.0 Free Water (%) 3,080.0 ~ Density (Iblgal) , 508 Plastic Viscosity (cp) ASL Thickening Time (hrs) 419.0 "/ CmprStr 1 (psi) 4.63 21.75 10.70 ~ _ Additives ___ Additive Type 'Concentration ConcUnitlabel - - - - -- - I ------ ------~ Fluid _ __ _ !Fluid Type ~ __ luid Description Estimated Top (ftKB) _ Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) ' Tail Cement 3,080.0 3,580.0 235 G 51.0 / Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gaq Plastic Viscosity (cpj Thickening Time (hrs) CmprStr 1 (psij 1.17 5.10 15.80 ~ --- Additives _ ~ iAdditive Type -- -- --- Concentration - Conc Unit label -JI • • , ` ~`~~ ~ t I~C:iANICAL INTEGRITY R :PORT ~ ~ - ,- UD u =.'. ~ _ ~ ~~'~~~`~ OPER ~ FIELD L~ Ps.~,.,. Cc~~~;~ ~ ~`~~_ :.~G rri.S~.,~. - ~1~~---C~'°Z hrT.i. NI1I~ffiER C~~ ~~~ :+}LL DAT~ TD. ~l~_?~.. ~ul~j~ TVD; ?BTD. ~~~~~?~D ~5~~?'VD iasi_^.g ~ Shoe: 1~~-\3~c~•ID ~'~~~ TtTD; yV. ?~ -?'~r`i =~.:e= . ~ ~~ Shoe : ',ID T`TD ; 'MCP _ ~.~ T':D ~:~bi ~~ ~~ll Packer ~~.~~-~ ole 5~.Le ~~~ ~ ~ and T'JD; Set a` ~ ?~~~~ ~( . ; Perfs i~sS3K to ~eY~` 51~._ ~L'r'..r~?~IC~.L ii~iTEGR?TY - ?4_RT #? Ynrulus Press Vest: =P ? 5 Cain :;0 min C om en t s : •'~J~1 e ~ C ~' Grt~~\ ` ~J ~ •t~5""r' ~'_~J ~ ~~ \ ~~ c~t r~~; cep t~ '.~'CHANIC?i, INTEGRITY -PART #2 ~-®~t~3~h~\S ~,A'3`~S~ ~s Cement Volumes :•. Amt. Liner ; Cs~\ DV Cmt -rol to cover oers ~ ~LZ~ 1f.5 ~~ `4~~~ 5 ~ ~G~t.C-~P.[~ p~~S ~ ~ - - =eoretical TOC C ~~~ f3 '`l~S ,~~ ~-~ Cement Bond Log (Yes or No) ~~~ ~ ~ - In AOGCC File L~ C3L -valuation, gone above perfs c,~~~~~~c~v'~~ r .~ Production Log: Type LON~LJS?ONS: ?arm #1: ?ar~ f2. F.valuat~on `1 ~~ aC~/~-c~1 09/19/07 • s~"'f~C.°' ~ 1 ~a~' J~P~ ~` Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth N0.4420 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Alpine Color Log Description Date BL Prints CD CD4-320" 40013769 OH EDIT MWD/LWD / 07/25/06 2 1 CD3-302 40013107 OH EDIT MWD/LWD 03/13/07 1 1 CD3-302P63 40013107 OH EDIT MWDILWD 03/08/07 1 1 CD4-322 11837501 SCMT 09/03/07 1 x, .~,.. ,~-, .,.,:: SIGNED: --,~~-~'~~~~ '~ ~~,,-~G--~. DATE: ~~::.~~~~'~ ~; ~~JI~I ~1~F~'~~r' i=?f~ +`'' t,a~~?~ I,t,afl~;. ~';C19111'tlla^If?ft Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ~"~r~c;,rnr=±±{'~~" 28-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-322 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.73' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 19,452.00' 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 ~~ a~~~-7 Signed O Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~-~o~ CD4-322 (Permit 207-101) Cement Log Maunder, Thomas E (DOA) Page 1 of 1 From: Walker, Jack A [Jack.A.Walker@conocophiHips.com] ~ ~~- ~~ Sent: Wednesday, September 05, 2007 11:14 AM To: Maunder, Thomas E (DOA) Cc: Wilson, Chris; Wiess, JORDAN F; Noel, Brian; Boehme, Brandon H; Schwartz, Guy L Subject: CD4-322 (Permit 207-101) Cement Log Attachments: CD4_322_SCMT_PERF_SBHP_09SEP2007_PRINT.zip Tom, Enclosed is the cement quality log with pertorating record and temperaturelpressure survey for Colville River Field injector CD4-322, permit to drill no. 207-101, completed in the Nanuq-Kuparuk Oil Pool at 18538-18558'MD. The log indicates high quality cement above and below the Kuparuk Sand and demonstrates isolation of injection fluids to the approved interval. Please call me with any questions. Jack Walker Western North Siope Development 265-6268 «CD4_322_SCMT_PERF_SBH P_09SEP2007_PRI NT.zip» 10/8/2007 STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION - - ,' Mechanical Integrity Test Email to: Winton_Aubert@adminstate.ak.us; Bob_Fleckenstein@adminstate.ak.us; Jim_Regg@adminstate.ak.us; Tom .Maunder@adminstate.ak.us OPERATOR: ConocoPhillips FIELD /UNIT /PAD: Alpine / Nanuq /CD4 DATE: 08/21 /07 OPERATOR'REP: Burley /Mickey AOGCC REP: TYPE INJ Codes TYPE TEST Codes D =Drilling Waist M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Waistewater R = Intemal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test MIT Report Form BFL 9!1/05 -- -- Packer Depth Pretest Initial 15 Min. 30 Min. Well CD4-322 Type Inj. W TVD 7,161' Tubing 1,850 2,050 2,050 2,050 Interval P.T.D. 207-101 Type test P Test psi 3500 Casing 1,850 3,500 3,400 3,390 P/F P Notes: OA Well Type Inj, TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA INTERVAL Codes i =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) CD4322 MIT • s o SARAH PALIN, GOVERNOR ~IL>•-7~ O~ ~`L ~ 333 W. 7th AVENUE, SUITE 100 COI~TSER~A7'I011T COMM15SIO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 C. Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-322 ConocoPhillips Alaska, Inc. Permit No: 207-101 Surface Location: 2987' FNL, 477' FEL, SEC.24, T11N, R4E Bottomhole Location: 1645' FNL, 1568' FEL, SEC. 21, T11N, R4E 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. v~~ith 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. ~'Vhen 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, Dan T. Seamount Commissioner DATED this day of July, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~r~r~ STATE OF ALASKA !""' (is6 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 R~c~~v~~ JUL 13 2007 Alaska Oil & Gas Cans. Camrnission Ancltcfaae 1 a. Type of Work: Drill 0 Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone ^ Single Zone Q 1 c. 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: CD4-322 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 18367' TVD: 7211' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2987 FNL, 477 FEL: Sec. 24 , T 11 N R 4 E 7. Property Designation ~~ 1 ~i i8.o ADL 380077, 3~ .ASR/G'NPRA02 Nanuq Kuparuk Oil Pool Top of Productive Horizon: 1698 FNL. 835 FEL, Sec. 21 ; T 11 N R 4 E 8. Land Use Permit: ALK380077 13. Approximate Spud Date: 7!27!2007 Total Depth: 1645 FNL, 1568 FEL, Sec. 21 , T 11 N R 4 E 9. Acres in Property: 5759 14. Distance to Nearest Property: 3712 FEL ASRCNPRA02 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377766.88 * y- 5957426.1 ~ Zone- 4 10. KB Elevation 55' above BPMSL (Height above GL): 37' RKB feet 15. Distance to Nearest Welf within Paal: CD4-318a 4933' at 18236' MD 16. Deviated wells: Kickoff depth: 320 - ft. Maximum Hole Angle: 71 ° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3473 psig Surface: 2705 psig 18. Casing Program S ifi ti Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" fi2.5~ H-4C# ltlielded 77 37 37 114 114' pre-installed 12.25" 9-518" 4~S# L-80 BTC 3554 37 37 3591 2400 603 sx AS Lite, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 19352 37 37 19389 7676 272 sx Class G, 184 Sx class G for K2 4.5" 12.6# L-80 IBT 18312 32 32 18344 7203 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee C BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements^ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. J®hrtSOrr Printed Name C. Alvord Title WNS Drilling Team Lead Signature Phone Date V. Johnson Commission Use Only Permit to Drill Number: 2~~ ~' ~d' API Number: 50- ~O3 " 2~ ~,~~ 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: /~ (yt'~"~'o G~,~[!'~.~'.CtiVCwI ~ ~~ 10 Samples req'd: Yes ^ No ~ Mud log req'd: Ye^ N~.~' Other: ~ ~ H2S measures: Yes ^ No ~ Directional svy req'd: Yes [~ No ^ 35bQ ~s~ Mti+.....~t. ~Q ~ ls~k~~c>".'~' opecr~.'~~oe~s~rvccoc~ `'~ /A~~a'1. APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 2/2005 U ~ ~ ~ $ ~~ ~ `,.. ~.- Submit i ~, 1-/g o7 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 • ConacoPhilli s p ~~~ July 13, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-322 Dear Sir or Madam: ,~Ut_. 13 ?C~,~7 ~aslta tail i~ Gas ~'~~ns. ~~i~rni~si~~t 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 7/27/2007. It is intended that Doyon Rig 19 be used to drill the well. CD4-322 will be a high 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.JThe well will then be closed in awaiting completion of facilities connection which will allow the well to begin injection. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. If so, 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. It is planned to drill additional rat hole below the Kuparuk sand, through the Alpine A sand for data gathering purposes. This section will be cased and cemented for isolation. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. There have been 14 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 drilling fluids handling system. 3. Diagram of diverter sef up. • If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. S' ate ,.• w~____-. rn~Js~rfison Drilling Engineer Attachments cc: CD4-322 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • CD4-322 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c finder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud i 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 f >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD ~ increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure -' mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well " control ractices, mud scaven ers j ORIGINAL • • Fiord : CD4-322 Procedure 1. Move on Doyon 19. 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. Pickup and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing point through the Kuparuk Sand and into the Alpine sand. (LWD Program: GR/RES/PWD/Density/porosity) - 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-%, 12.6#, L-80 tubing with DB profile, packer, GLM, 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, running cement evaluation logs ' below the tubing tail, perforating the Kuparuk interval and setting an injection valve. ORIGINAL • Well Proximity Risks: r: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-321 is the nearest existing well to the CD4-322 plan with 5.8' well to well separation at 600' MD. Drilling 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 low fluid loss mud are expected to be effective in dealing with lost circulation. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD4-322 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-322 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. 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 CD4-322 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) " (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) " (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 ORIGINAL c DRILLING FLUID PROGRAM • SPUD to 9-5/8"surface casing oint-12'/" 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 Funnel Viscosity 100 - 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: f 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. OR161NAL • • Completion Schematic 16" Insulated Conductor to -114' 4-'/i' 12.6 ppf L-80 IBT Mod. Tubing 3.81" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 3591' MD / 2400' TVD Updated 07-12-07 VTJ VVP08 Upper Completion: TOC +/- 8361' MD / 3953' TVD Stage cementing tool +/- 9380' MD / 4285' TVD Top of intermediate cement 300' above packer 17972' MD / 7081' TVD Kuparuk C 18544' MD / 7268' TVD Alpine A 19117' MD 7515' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ +/-50° 19389' MD, 7674' TVD ~ ~./~'0~ 1) Tubing Hanger 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 3.81" K2/Qannik sand 4) 4-1/2", 12.6#/ft, IBT-Mod Tubing +/- 8861' MD / 5) Camco KBG-2 GLM with shear valve 4116' TVD 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) 7) Baker S3 packer with Millout extension 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 9) HES "XN" (3.725") 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing pup \ 11) Wireline entry guide Top MD TVD 32' 32' 2387' 2000' 18172' 7147' 18272' 7179' 18332' 7199' 18344' 7203' VVLEG at around 200' above Kuparuk 15' perforations ORIGINAL • CD4-322 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 lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3591 / 2400 14.5 1086 1571 7" / TD 19389 / 7676 16.0 3473 2705 • 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=53 psi 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 = 1571 psi OR ASP =FPP - (0.1 x D) = 3473 - (0.1 x 7676') = 2705 psi , ORIGINAL • • Cementing Program: 9 5/8" Surface Casing run to 3591' MD / 2400' TVD. Cement from 3591' MD to 3091' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3091' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1386' MD). Lead slurry: (3091'-1707') X 0.3132 ft3/ft X 1.5 (50% excess) = 650.2 ft3 below permafrost 1707' X 0.3132 ft3/ft X 4 (300% excess) = 2138.5 ft3 above permafrost Total volume = 650.2 + 2138.5 = 2788.7 ft3 => 603 Sx @ 4.63 ft3/sk System: 603 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.63 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 Casing run to 19389' MD / 7676' TVD Cement from 19389' MD to +/-17972' MD (minimum 300' MD above top of packer) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (19389' - 17972) X 0.1503 ft3/ft X 1.4 (40% excess) = 298.2 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 298.2 + 17.2 = 315.4 ft3 => 272 Sx @ 1.16 ft3/sk System: 272 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 Sta~e: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: (9380' - 8361') X 0.1503 ft3/ft X 1.4 (40% excess) = 214.4 ft3 annular vol. Total Volume = 214.4 ft3 => 184 Sk @ 1.17 ft3/sk System: 184 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 additiy~s~e,Q1Q(QCe~n~tt ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 7/11/2007 Time: 15:48:23 Page:..:: 1 Field: Colville River Unit Co-ordinate(NE) Reference: WeIL•-Plan` CD4-322, True North f Site: . Alpine CD4 Vertical (TVD) Reference: CD4-322wp08 55.3 WeIL• Plan: CD4-322 Section (VS) Reference: Well (O.OON,O.OOE,274.60Azi) Wellpath: Plait: CD4-322 Survey Calculation Method: - Minimum Curvature ~ Db: Oracle Plan: CD4-322wp08 Date Composed: 5/29/2007 Kuparuk target Version: 3 Principal: Yes Tied-to: From Well Ref. Point Field: 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: bggm2007 Site: Alpine CD4 Site Position: 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: CD4-322 Slot Name: Well Position: +N/-S -104.61 ft Northing: 5957428.10 ft ' Latitude: 70 17 31.937 N +E/-W -406.70 ft Easting : 377766.39 ft' Longitude: 150 59 22.615 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-322 Drilled From: Well Ref. Point Current Datum: CD4-322wp08 j Height 55.30 ft Tie-on Depth: Above System Datum: 36.30 ft Mean Sea Level - Magnetic Data: 12/1/2004 Declination: 23.78 deg ', Field Strength: 57492 nT Mag Dip Angle: 80.60 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 274.60 Survey Program for Definitive Wellpath Date: 5/29/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD ft Incl deg Azim deg TVD ft +N/-S ft +E/-W ft DLS deg/100ft Build Turn deg/100ft deg/100ft TFO Target deg - 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 319.30 0.00 0.00 319.30 0.00 0.00 0.00 0.00 0.00 0.00 519.30 5.00 265.00 519.05 -0.76 -8.69 2.50 2.50 0.00 265.00 819.30 12.28 304.56 815.65 16.24 -48.07 3.00 2.43 13.19 60.00 2549.23 71.00 274.21 2060.51 197.82 -1116.56 3.50 3.39 -1.75 -33.28 18457.96 71.00 274.21 7240.26 1301.11 -16117.91 0.00 0.00 0:00 0.00 18458.06 71.00 274.21 7240.30 1301.12 -16118.02 3.50 1.35 3.41 67.26 CD4-322wp06 T1 18565.57 71.00 274.21 7275.30 1308.58 -16219.39 0.00 0.00 0.00 0.00 19387.87 50.44 274.21 7675.30 1360.95 -16930.88 2.50 -2.50 0.00 180.00 ORIGINAL WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot Plan: CD4-322 -104.61 -406.70 5957428.10 377766.39 70°1T31.937N 150°59'22.615W N/A WELLPATH DETAILS Plan: CD4-322 Rig: Doyon 19 Ref. Datum: CD4-322wp08 55.30ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 274.60° 0.00 0.00 36.30 V T M Azimuths to True North Magnetic North: 23.78° Magnetic Field Strength:57492nT Dip Angle: 80.60° Date: 12/1/2004 Model: bggm2007 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 999.30 Planned: CD4-322wp08 V3 CB-GYRO-SS 999.30 19387.87 Planned: CD4-322wp08 V3 MWD+IFR-AK-CAZ-SC a a ca z F PLAN DETAILS CD4-322wp08 Kuparuk target Version 3 5/29/2007 Start Point MD Inc Azi TVD +N/-S +E/-W 36.30 0.00 0.00 36.30 0.00 0.00 MALLlBURTON C0110C Phillips Sperry Odlling Servksa Alaska Vertical Sec[ion at 274.60° [SOOOtVin] 1000 500 a g o ° •322 08 ' ~ ~ ' 0 o° o° © c '^ v° c ° o 0 ti '.. -5000 -15000 -10000 -5000 0 West(-)/East(+) [SOOOtVin] REFERENCE INFORMATION Co-ordinate (IV/E) Reference: Well Centre: Plan: CD4-322, True North Vertical (TVD) Reference: CD4-322wp08 55.30 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: CD4-322vvp08 55.30 Calculation Method: Minimum Curvature REFERENCE INFORMATION Coordinate (N/E) Reference: Well Centre: Plan'. CD4J23, True North VeRical (TVD)fteference: CD4-322wp0855.30 Section (VSJ Reference: Slot- (O.OON,O.OOE) Measured Depth Reference: C04J22wp08 55.30 CalcuWtion Meawd'. Minimum Curvature 0 V l Z o A 51 ANTI-COLLISION SETTINGS 3lation Method:MD Interval: 25.00 Range From: 36.30 To: 19387.87 ium Range: 2135.16 Reference: Plan: CD4-322wp08 From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 1500 0 1500 1750 1750 - 2000 _-- 2000 2500 2500 3000 -_ 3000 3500 - \, 3500 4000 ~ ~ oo~D~-ne-~c D>~op[ o sooo - 6000 00 ~ 7000 -- 'Q000 - - - - 8000 _ 8000 9000 14000 SURVEY PROGRAM pth Fm Depth To Survey/Plan Tool 3 .30 999.30 Planned: CD4-322wp08 V3 CB-GYRO-SS 9 9.30 19387.87 Planned: CD4-322wp08 V3 M1IWD+IFR-AK-CAZ-SC SF.C'RON UETAILS Scc MD In< Azi TVU +N/-S +E/-W DLeg TFace VSec Targcf 1 36.30 0. W 0.00 36.30 000 000 000 0.00 0.00 2 319.30 0 (10 000 319.30 000 000 0.00 0.00 000 3 519.30 500 265.00 519 0> -0 7l -R.69 2.50 265.00 8.60 4 81930 1228 30456 B1S65 1624 -0R 07 3.00 6000 4922 5 2549.23 71.00 274 21 2(160.51 197.82 -1116 56 3.50 -33.29 1128.82 6 IRJ57.96 7100 27421 724026 1301.11 -IGI 1791 0.00 000 16170.34 7 7RJ5R 06 7100 27421 724030 1301.1'_ -1611802 3.50 6726 1617045 CD4322wpOG T1 R 9 IRSG5.57 71.00 27421 1938787 5044 27421 7271.30 767130 1308.SN -1621'1.3') 136091 -16930 RR O.UO 250 0.00 180.00 16272.09 1G9R5.49 1) From Colour To 36 250 250 500 > 500 750 750 1000 \ ` r~ n l~cn 1 ~n 1 2 ~r~-~ 7 CO[~ffANY DETAILS ConocoPltillips Alaska Inc. Engineering Calculntion Mcthnd: Minimmn Curvature Emor Systcm'. ISC W SA Scan Mclhnd: Trat'Crlinder North Error Surtice: Elliptical+Casing wam;,,g Mmnoa Ralea ¢aaea Cylinder Azimuth (TFO+A"LI) [deg[ vs Centre to Centre Separation [100fUin] laa CD4-321 (CD4-321) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ft/in] A o000000~000000°0°0°0°0°0°0°0 ~oooo~no~nooo 00000000000000 ~~ O ~I i O N~ [~ O~ O~ O~ O O O O O O N~ ~O 00 O~ H N Vi l~ ~--~ .-i ~ ~ N N M M ~ ~ iIi ~O [~ 00 01 .--i ~-+ ~--~ ~-+ ~-+ N N ~ ~ ~ U ~ ~ .~ A ~~oooo~ooooo00000000000000o U M~ O~ ~ O X 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ L N~ [~ ®N ~ l~ 0 V~ O Vi 0 Vi 0 0 0 0 0 0 0 0 0 0 0 ,.y ~ Pi~~--i~--iNNMM~et V~~CI~000~ON~'~D000 ~ 00 ~ 1 y `~ y y r a c ~ O ~ N M ~ ~ ~ ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 7/41/2007 Time: 15:48:23. Page: 2 Field: Colville River Un if Co-ordiaste(NE) I2efere~sce: Well: Plan: CD4-322, True North Site: Al pine CD4 Vertical (TVD) Reference: C D4-322wp08 55.3 Well: Plan; C D4-322 Sec tion (VS) Refereuce: Well (O.OON,OOOE,274.60Azi) Wellpatb: Pl ans C D4-322 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl ` Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comment ft deg. deg ft ft ft ft ft ft deg/100ft deg ' 36 .30 0. 00 0 .00 36. 30 -19. 00 0 .00 0. 00 5957428.10 377766. 39 0.00 0.00 100 .00 0. 00 0 .00 100. 00 44. 70 0 .00 0. 00 5957428.10 377766. 39 0.00 0.00 200 .00 0. 00 0 .00 200. 00 144. 70 0 .00 0. 00 5957428.10 377766. 39 0.00 0.00 300 .00 0. 00 0 .00 300. 00 244. 70 0 .00 0. 00 5957428.10 377766. 39 0.00 0.00 319 .30 0. 00 0 .00 319. 30 264. 00 0 .00 0. 00 5957428.10 377766. 39 0.00 0.00 KOP; 2.5 DLS, 26 400 .00 2. 02 265 .00 399. 98 344. 68 -0 .12 -1. 42 5957428.00 377764. 97 2.50 0.00 500 .00 4. 52 265 .00 499. 81 444. 51 -0 .62 -7. 09 5957427.59 377759. 29 2.50 0.00 519 .30 5. 00 265 .00 519. 05 463. 75 -0 .76 -8. 69 5957427.48 377757. 69 2.50 0.00 Build 3 DLS, 60 T 600 .00 6. 55 283 .69 599 .34 544. 04 0 .02 -16. 67 5957428.39 377749. 73 3.00 60.00 700 .00 9. 02 296 .44 698 .42 643. 12 4 .87 -29. 24 5957433.44 377737. 24 3.00 41.40 783 .19 11. 28 302 .59 780 .30 725. 00 12 .15 -41. 93 5957440.93 377724. 66 3.00 28.76 Base Permafrost 800 .00 11. 74 303 .55 796. 78 741. 48 13. 99 -44. 74 5957442.81 377721. 88 3.00 22.71 819 .30 12. 28 304 .56 815. 65 760. 35 16. 24 -48. 07 5957445.11 377718. 59 3.00 21.77 Build; 3.5 DLS 900 .00 14. 72 298 .45 894. 12 838. 82 25. 99 -64. 16 5957455.13 377702. 67 3.50 326.72 1000 .00 17. 90 293 .22 990. 09 934. 79 38. 11 -89. 47 5957467.66 377677. 56 3.50 332.66 1100 .00 21. 18 289 .54 1084. 32 1029. 02 50. 22 -120. 63 5957480.27 377646. 61 3.50 337.69 1200 .00 24. 52 286 .82 1176. 46 1121. 16 62. 27 -157. 53 5957492.92 377609. 91 3.50 341.15 1300 .00 27. 89 284 .71 1266. 17 1210. 87 74. 22 -200. 03 5957505.55 377567. 61 3.50 343.66 1400 .00 31. 29 283 .03 1353. 11 1297. 81 86. 02 -247. 97 5957518.13 377519. 87 3.50 345.55 1500 .00 34. 71 281 .65 1436. 96 1381. 66 97. 63 -301. 18 5957530.61 377466. 87 3.50 347.01 1600 .00 38. 14 280 .49 1517. 41 1462. 11 109. 01 -359. 45 5957542.93 377408. 79 3.50 348.17 1700 .00 41. 59 279 .50 1594. 16 1538. 86 120. 11 -422. 56 5957555.06 377345. 87 3.50 349.11 1800 .00 45. 03 278 .63 1666. 91 1611. 61 130. 90 -490. 29 5957566.94 377278. 33 3.50 349.87 1900 .00 48. 49 277 .86 1735. 40 1680. 10 141. 33 -562. 38 5957578.54 377206. 43 3.50 350.50 2000 .00 51. 95 277 .16 1799. 38 1744. 08 151. 36 -638. 56 5957589.81 377130. 43 3.50 351.03 2100 .00 55. 41 276 .54 1858. 60 1803. 30 160. 96 -718. 55 5957600.71 377050. 61 3.50 351.48 2200 .00 58. 88 275 .96 1912. 84 1857. 54 170. 09 -802. 04 5957611.19 376967. 29 3.50 351.85 2300 .00 62. 35 275 .42 1961. 91 1906. 61 178. 72 -888. 73 5957621.23 376880. 75 3.50 352.16 2400 .00 65. 82 274 .91 2005. 61 1950. 31 186. 81 -978. 30 5957630.77 376791. 34 3.50 352.43 2500 .00 69. 29 274. 43 2043. 79 1988. 49 194. 33 -1070. 40 5957639.79 376699. 38 3.50 352.65 2549 .23 71. 00 274. 21 2060. 51 2005. 21 197. 82 -1116. 56 5957644.03 376653. 28 3.50 352.83 Sail; 71 ° for 15909 2600 .00 71. 00 274. 21 2077. 04 2021. 74 201. 34 -1164. 44 5957648.33 376605. 47 0.00 0.00 2700 .00 71. 00. 274. 21 2109. 60 2054. 30 208. 27 -1258. 74 5957656.79 376511. 31 0.00 0.00 2800 .00 71. 00 274. 21 2142. 16 2086. 86 215. 21 -1353. 03 5957665.26 376417. 15 0.00 0.00 2900 .00 71. 00 274. 21 2174. 72 2119. 42 222. 14 -1447. 33 5957673.73 376322. 98 0.00 0.00 3000 .00 71. 00 274. 21 2207. 27 2151. 97 229. 08 -1541. 63 5957682.19 376228. 82 0.00 0.00 3009 .29 71. 00 274 .21 2210. 30 2155. 00 229. 72 -1550. 39 5957682.98 376220. 07 0.00 0.00 C-40 3100 .00 71. 00 274 .21 2239. 83 2184. 53 236. 01 -1635. 92 5957690.66 376134. 66 0.00 0.00 3200 .00 71. 00 274 .21 2272. 39 2217. 09 242. 95 -1730. 22 5957699.13 376040. 49 0.00 0.00 3300 .00 71. 00 274 .21 2304. 95 2249. 65 249. 88 -1824. 52 5957707.59 375946. 33 0.00 0.00 3400 .00 71. 00 274 .21 2337. 51 2282. 21 256. 82 -1918. 81 5957716.06 375852. 17 0.00 0.00 3500 .00 71. 00 274 .21 2370. 07 2314. 77 263. 75 -2013. 11 5957724.53 375758. 00 0.00 0.00 3591 .92 71. 00 274 .21 2400. 00 2344. 70 270. 13 -2099. 79 5957732.31 375671. 45 0.00 0.00 9 5/8" x 12 1/4" 3600 .00 71. 00 274 .21 2402. 63 2347. 33 270. 69 -2107. 41 5957732.99 375663. 84 0.00 0.00 3638 .91 71. 00 274 .21 2415. 30 2360. 00 273. 39 -2144. 10 5957736.29 375627. 20 0.00 0.00 C-30 3700 .00 71. 00 274 .21 2435. 19 2379. 89 277. 62 -2201. 70 5957741.46 375569. 68 0.00 0.00 3800 .00 71. 00 274 .21 2467. 75 2412. 45 284. 56 -2296. 00 5957749.93 375475. 51 0.00 0.00 3900 .00 71. 00 274. 21 2500. 31 2445. 01 291. 49 -2390. 29 5957758.39 375381. 35 0.00 0.00 4000 .00 71. 00 274. 21 2532. 87 2477. 57 298. 43 -2484. 59 5957766.86 375287. 19 0.00 0.00 4100 .00 71. 00 274. 21 2565. 43 2510. 13 305. 36 -2578. 89 5957775.33 375193. 02 0.00 0.00 4200 .00 71. 00 274. 21 2597. 99 2542. 69 312. 30 -2673. 18 5957783.79 375098. 86 0.00 0.00 4300 .00 71. 00 274. 21 2630. 54 2575. 24 319. 23 -2767. 48 5957792.26 375004. 70 0.00 0.00 4400 .00 71. 00 274. 21 2663. 10 2607. 80 326. 17 -2861. 78 5957800.73 374910. 53 0.00 0.00 ORIGINAL F ~ ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska lnc. Date: 7/11/2007 Time: 75:48:23 Page: 3 Field: Colville River Un it Go-ordinate(1VE) Re ference: Well: Plan: GD4-322, True North Site: .Al pine CD4 Vertical (TVD) Reference: C D4-322wp08 55.3 Well: Plan'. C D4-322 Section (VS) Reference: Well (O.OON,O.OOE,274.60Azi) Wel(patb: Plan: C D4-322 Survey Calculation Method: M inimum Curvature Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comment ft deg deg ft ft ft ft ft ft deg/100ft .deg 4500. 00 71. 00 274 .21 2695. 66 2640. 36 333 .10 -2956. 07 5957809. 19 374816. 37 0.00 0.00 4600. 00 71. 00 274 .21 2728. 22 2672. 92 340 .04 -3050. 37 5957817. 66 374722. 21 0.00 0.00 4700. 00 71. 00 274 .21 2760. 78 2705. 48 346 .97 -3144. 66 5957826. 13 374628. 04 0.00 0.00 4759. 95 71. 00 274 .21 2780. 30 2725. 00 351 .13 -3201 .19 5957831. 20 374571. 60 0.00 0.00 C-20 4800. 00 71. 00 274 .21 2793. 34 2738. 04 353 .91 -3238 .96 5957834. 60 374533. 88 0.00 0.00 4900. 00 71. 00 274 .21 2825. 90 2770. 60 360 .85 -3333 .26 5957843. 06 374439. 72 0.00 0.00 5000. 00 71. 00 274 .21 2858. 46 2803. 16 367 .78 -3427 .55 5957851. 53 374345. 55 0.00 0.00 5100. 00 71. 00 274 .21 2891. 02 2835. 72 374 .72 -3521 .85 5957860. 00 374251. 39 0.00 0.00 5200. 00 71. 00 274 .21 2923. 58 2868. 28 381 .65 -3616. 15 5957868. 46 374157. 23 0.00 0.00 5300. 00 71. 00 274 .21 2956. 14 2900. 84 388 .59 -3710. 44 5957876. 93 374063. 06 0.00 0.00 5400. 00 71. 00 274 .21 2988. 70 2933. 40 395 .52 -3804. 74 5957885. 40 373968. 90 0.00 0.00 5500. 00 71. 00 274 .21 3021. 26 2965. 96 402 .46 -3899. 04 5957893. 86 373874. 74 0.00 0.00 5600. 00 71. 00 274 .21 3053. 81 2998. 51 409 .39 -3993. 33 5957902. 33 373780. 57 0.00 0.00 5700. 00 71. 00 274 .21 3086. 37 3031. 07 416 .33 -4087. 63 5957910. 80 373686. 41 0.00 0.00 5800. 00 71. 00 274 .21 3118. 93 3063. 63 423 .26 -4181. 92 5957919. 26 373592. 25 0.00 0.00 5900. 00 71. 00 274 .21 3151. 49 3096. 19 430 .20 -4276. 22 5957927. 73 373498. 08 0.00 0.00 6000. 00 71. 00 274 .21 3184. 05 3128. 75 437 .13 -4370. 52 5957936. 20 373403. 92 0.00 0.00 6100. 00 71. 00 274 .21 3216. 61 3161. 31 444 .07 -4464. 81 5957944. 66 373309. 76 0.00 0.00 6200. 00 71. 00 274 .21 3249. 17 3193. 87 451 .00 -4559. 11 5957953. 13 373215. 59 0.00 0.00 6300. 00 71. 00 274 .21 3281. 73 3226. 43 457. 94 -4653. 41 5957961. 60 373121. 43 0.00 0.00 6400. 00 71. 00 274 .21 3314. 29 3258. 99 464 .87 -4747. 70 5957970. 06 373027. 27 0.00 0.00 6500. 00 71. 00 274 .21 3346. 85 3291. 55 471 .81 -4842. 00 5957978. 53 372933. 10 0.00 0.00 6600. 00 71. 00 274 .21 3379. 41 3324. 11 478 .74 -4936. 30 5957987. 00 372838. 94 0.00 0.00 6700. 00 71. 00 274 .21 3411. 97 3356. 67 485 .68 -5030. 59 5957995. 46 372744. 78 0.00 0.00 6800. 00 71. 00 274 .21 3444. 53 3389. 23 492 .61 -5124. 89 5958003. 93 372650. 61 0.00 0.00 6900. 00 71. 00 274 .21 3477. 08 3421. 78 499 .55 -5219. 18 5958012. 40 372556. 45 0.00 0.00 7000. 00 71. 00 274 .21 3509. 64 3454. 34 506 .48 -5313. 48 5958020. 86 372462. 29 0.00 0.00 7100. 00 71. 00 274 .21 3542. 20 3486. 90 513 .42 -5407. 78 5958029. 33 372368. 12 0.00 0.00 7200. 00 71. 00 274 .21 3574. 76 3519. 46 520 .35 -5502. 07 5958037. 80 372273. 96 0.00 0.00 7300. 00 71. 00 274 .21 3607. 32 3552. 02 527 .29 -5596. 37 5958046. 27 372179. 80 0.00 0.00 7400. 00 71. 00 274 .21 3639. 88 3584. 58 534 .22 -5690. 67 5958054. 73 372085. 63 0.00 0.00 7500. 00 71. 00 274 .21 3672. 44 3617. 14 541 .16 -5784. 96 5958063. 20 371991. 47 0.00 0.00 7600. 00 71. 00 274 .21 3705 .00 3649. 70 548 .09 -5879 .26 5958071. 67 371897. 31 0.00 0.00 7700. 00 71. 00 274 .21 3737 .56 3682. 26 555 .03 -5973. 56 5958080. 13 371803. 14 0.00 0.00 7800. 00 71. 00 274 .21 3770. 12 3714. 82 561 .96 -6067 .85 5958088. 60 371708. 98 0.00 0.00 7900. 00 71. 00 274 .21 3802. 68 3747. 38 568 .90 -6162. 15 5958097. 07 371614. 82 0.00 0.00 8000. 00 71. 00 274 .21 3835. 24 3779. 94 575 .83 -6256. 44 5958105. 53 371520. 65 0.00 0.00 8046. 27 71. 00 274 .21 3850. 30 3795. 00 579 .04 -6300. 07 5958109. 45 371477. 09 0.00 0.00 K-3 8100. 00 71. 00 274 .21 3867. 80 3812. 50 582 .77 -6350. 74 5958114. 00 371426. 49 0.00 0.00 8200. 00 71. 00 274 .21 3900. 35 3845. 05 589 .71 -6445. 04 5958122. 47 371332. 33 0.00 0.00 8300. 00 71. 00 274 .21 3932. 91 3877. 61 596 .64 -6539. 33 5958130. 93 371238. 16 0.00 0.00 8400. 00 71. 00 274 .21 3965. 47 3910. 17 603. 58 -6633. 63 5958139. 40 371144. 00 0.00 0.00 8500. 00 71. 00 274 .21 3998. 03 3942. 73 610. 51 -6727. 93 5958147. 87 371049. 84 0.00 0.00 8600. 00 71. 00 274 .21 4030. 59 3975. 29 617 .45 -6822. 22 5958156. 33 370955. 67 0.00 0.00 8700. 00 71. 00 274 .21 4063. 15 4007. 85 624 .38 -6916. 52 5958164. 80 370861. 51 0.00 0.00 8752. 67 71. 00 274 .21 4080. 30 4025. 00 628. 03 -6966. 19 5958169. 26 370811. 91 0.00 0.00 Basal K-3 8800. 00 71. 00 274 .21 4095. 71 4040. 41 631 .32 -7010. 81 5958173. 27 370767. 35 0.00 0.00 8860. 17 71. 00 274. 21 4115. 30 4060. 00 635 .49 -7067. 55 5958178. 36 370710. 69 0.00 0.00 K-2 8900. 00 71. 00 274. 21 4128. 27 4072. 97 638. 25 -7105. 11 5958181. 73 370673. 19 0.00 0.00 9000. 00 71. 00 274. 21 4160. 83 4105. 53 645. 19 -7199. 41 5958790. 20 370579. 02 0.00 0.00 9100. 00 71. 00 274. 21 4193. 39 4138. 09 652. 12 -7293. 70 5958198. 67 370484. 86 0.00 0.00 9105. 87 71. 00 274 .21 4195. 30 4140. 00 652. 53 -7299. 24 5958199. 16 370479. 33 0.00 0.00 Base K-2 ORIGINAL • ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Ina Date: 7/11/2007 Time: 15:48:23 Paget 4 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-322, True NoRh Site:. Alpine CD4 Vertical (TVD) Reference: CD4-322wp08 55.3 WeIL• Plan: CD4-322 Section (VS) Reference: Well (O.OON,O.OOE,274.60Azi) Wellpath: Plan: CD4-322 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 10100.00 10200.00 10300.00 10400.00 10500.00 10600.00 10700.00 10800.00 10900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 11900.00 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13282.88 13300.00 13400.00 13500.00 13600.00 13700.00 13800.00 13900.00 14000.00 14100.00 14200.00 14300.00 Intl Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 71.00 274.21 4225.95 4170.65 659.06 -7388.00 71.00 274.21 4258.51 4203.21 665.99 -7482.30 71.00 274.21 4291.07 4235.77 672.93 -7576.59 71.00 274.21 4323.62 4268.32 679.86 -7670.89 71.00 274.21 4356.18 4300.88 686.80 -7765.19 71.00 274.21 4388.74 4333.44 693.73 -7859.48 71.00 274.21 4421.30 4366.00 700.67 -7953.78 71.00 274.21 4453.86 4398.56 707.60 -8048.07 71.00 274.21 4486.42 4431.12 714.54 -8142.37 71.00 274.21 4518.98 4463.68 721.47 -8236.67 71.00 274.21 4551.54 4496.24 728.41 -8330.96 71.00 274.21 4584.10 4528.80 735.34 -8425.26 71.00 274.21 4616.66 4561.36 742.28 -8519.56 71.00 274.21 4649.22 4593.92 749.21 -8613.85 71.00 274.21 4681.78 4626.48 756.15 -8708.15 71.00 274.21 4714.33 4659.03 763.08 -8802.45 71.00 274.21 4746.89 4691.59 770.02 -8896.74 71.00 274.21 4779.45 4724.15 776.95 -8991.04 71.00 274.21 4812.01 4756.71 783.89 -9085.33 71.00 274.21 4844.57 4789.27 790.82 -9179.63 71.00 274.21 4877.13 4821.83 797.76 -9273.93 71.00 274.21 4909.69 4854.39 804.69 -9368.22 71.00 274.21 4942.25 4886.95 811.63 -9462.52 71.00 274.21 4974.81 4919.51 818.56 -9556.82 71.00 274.21 5007.37 4952.07 825.50 -9651.11 71.00 274.21 5039.93 4984.63 832.44 -9745.41 71.00 274.21 5072.49 5017.19 839.37 -9839.71 71.00 274.21 5105.05 5049.75 846.31 -9934.00 71.00 274.21 5137.60 5082.30 853.24 -1.Oe04 71.00 274.21 5170.16 5114.86 860.18 -1.Oe04 71.00 274.21 5202.72 5147.42 867.11 -1.Oe04 71.00 274.21 5235.28 5179.98 874.05 -1.Oe04 71.00 274.21 5267.84 5212.54 880.98 -1.Oe04 71.00 274.21 5300.40 5245.10 887.92 -1.Oe04 71.00 274.21 5332.96 5277.66 894.85 -1.Oe04 71.00 274.21 5365.52 5310.22 901.79 -1.Oe04 71.00 274.21 5398.08 5342.78 908.72 -1.Oe04 71.00 274.21 5430.64 5375.34 915.66 -1.Oe04 71.00 274.21 5463.20 5407.90 922.59 -1.Oe04 71.00 274.21 5495.76 5440.46 929.53 -1.1e04 71.00 274.21 5528.32 5473.02 936.46 -1.1e04 71.00 274.21 5555.30 5500.00 942.21 -1.1e04 71.00 274.21 5560.87 5505.57 943.40 -1.1e04 71.00 274.21 5593.43 5538.13 950.33 -1.1e04 71.00 274.21 5625.99 5570.69 957.27 -1.1e04 71.00 274.21 5658.55 5603.25 964.20 -1.1e04 71.00 274.21 5691.11 5635.81 971.14 -1.1e04 71.00 274.21 5723.67 5668.37 978.07 -1.1e04 71.00 274.21 5756.23 5700.93 985.01 -1.1e04 71.00 274.21 5788.79 5733.49 991.94 -1.1e04 71.00 274.21 5821.35 5766.05 998.88 -1.2e04 71.00 274.21 5853.91 5798.61 1005.81 -1.2e04 71.00 274.21 5886.47 5831.17 1012.75 -1.2e04 MapN MapE DLS TFO ~ ft ft ' deg/100ft deg 5958207.13 370390.70 0.00 0.00 5958215.60 370296.53 0.00 0.00 5958224.07 370202.37 0.00 0.00 5958232.53 370108.21 0.00 0.00 5958241.00 370014.04 0.00 0.00 5958249.47 369919.88 0.00 0.00 5958257.94 369825.72 0.00 0.00 5958266.40 369731.55 0.00 0.00 5958274.87 369637.39 0.00 0.00 5958283.34 369543.23 0.00 0.00 5958291.80 369449.06 0.00 0.00 5958300.27 369354.90 0.00 0.00 5958308.74 369260.74 0.00 0.00 5958317.20 369166.57 0.00 0.00 5958325.67 369072.41 0.00 0.00 5958334.14 368978.25 0.00 0.00 5958342.60 368884.08 0.00 0.00 5958351.07 368789.92 0.00 0.00 5958359.54 368695.76 0.00 0.00 5958368.00 368601.59 0.00 0.00 5958376.47 368507.43 0.00 0.00 5958384.94 368413.27 0.00 0.00 5958393.40 368319.10 0.00 0.00 5958401.87 368224.94 0.00 0.00 5958410.34 368130.78 0.00 0.00 5958418.80 368036.61 0.00 0.00 5958427.27 367942.45 0.00 0.00 5958435.74 367848.29 0.00 0.00 5958444.20 367754.12 0.00 0.00 5958452.67 367659.96 0.00 0.00 5958461.14 367565.80 0.00 0.00 5958469.60 367471.63 0.00 0.00 5958478.07 367377.47 0.00 0.00 5958486.54 367283.31 0.00 0.00 5958495.01 367189.14 0.00 0.00 5958503.47 367094.98 0.00 0.00 5958511.94 367000.82 0.00 0.00 5958520.41 366906.65 0.00 0.00 5958528.87 366812.49 0.00 0.00 5958537.34 366718.33 0.00 0.00 5958545.81 366624.16 0.00 0.00 5958552.82 366546.12 0.00 0.00 Albian 97 5958554.27 366530.00 0.00 0.00 5958562.74 366435.84 0.00 0.00 5958571.21 366341.67 0.00 0.00 5958579.67 366247.51 0.00 0.00 5958588.14 366153.35 0.00 0.00 5958596.61 366059.18 0.00 0.00 5958605.07 365965.02 0.00 0.00 5958613.54 365870.86 0.00 0.00 5958622.01 365776.69 0.00 0.00 5958630.47 365682.53 0.00 0.00 5958638.94 365588.37 0.00 0.00 ORIGINAL ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska InC. Date: 7/11/2007 Time: 15:48:23 Page: S Field: ColviAe River Unit Co-ordinate(NE),Reference: Well: Plan: CD4-322; True North' Site: Alpine CD4 Vertical (TVD)Reference: CD4-322wp0855.3 WeIL• Plan: CD4-322 Section (VS)Beference:- Well.(O.OON,O.OOE,274.60Azi) Wellpath: Plan: CD4=322 Survey Calculation Method: Minimum Curvature. ` 1)b: OraGe Survey MD ft 14400.00 14500.00 14600.00 14700.00 14800.00 14864.61 14900.00 15000.00 15100.00 15200.00 15300.00 15400.00 15500.00 15600.00 15700.00 15800.00 15900.00 16000.00 16100.00 16200.00 16300.00 16400.00 16500.00 16600.00 16700.00 16800.00 16900.00 17000.00 17100.00 17200.00 17300.00 17400.00 17481.38 17500.00 17600.00 17700.00 17800.00 17900.00 18000.00 18089.50 18100.00 18200.00 18221.57 18300.00 18400.00 18421.21 18457.96 18500.00 18544.07 18565.57 18600.00 18700.00 Incl Azim TVD Sys TVD N/S E/W deg deg ft ft tt ft 71.00 274.21 5919.03 5863.73 1019.68 -1.2e04 71.00 274.21 5951.59 5896.29 1026.62 -1.2e04 71.00 274.21 5984.14 5928.84 1033.55 -1.2e04 71.00 274.21 6016.70 5961.40 1040.49 -1.2e04 71.00 274.21 6049.26 5993.96 1047.42 -1.2e04 71.00 274.21 6070.30 6015.00 1051.91 -1.2e04 71.00 274.21 6081.82 6026.52 1054.36 -1.2e04 71.00 274.21 6114.38 6059.08 1061.30 -1.2e04 71.00 274.21 6146.94 6091.64 1068.23 -1.2e04 71.00 274.21 6179.50 6124.20 1075.17 -1.3e04 71.00 274.21 6212.06 6156.76 1082.10 -1.3e04 71.00 274.21 6244.62 6189.32 1089.04 -1.3e04 71.00 274.21 6277.18 6221.88 1095.97 -1.3e04 71.00 274.21 6309.74 6254.44 1102.91 -1.3e04 71.00 274.21 6342.30 6287.00 1109.84 -1.3e04 71.00 274.21 6374.86 6319.56 1116.78 -1.3e04 71.00 274.21 6407.41 6352.11 1123.71 -1.3e04 71.00 274.21 6439.97 6384.67 1130.65 -1.3e04 71.00 274.21 6472.53 6417.23 1137.58 -1.3e04 71.00 274.21 6505.09 6449.79 1144.52 -1.3e04 71.00 274.21 6537.65 6482.35 1151.45 -1.4e04 71.00 274.21 6570.21 6514.91 1158.39 -1.4e04 71.00 274.21 6602.77 6547.47 1165.32 -1.4e04 71.00 274.21 6635.33 6580.03 1172.26 -1.4e04 71.00 274.21 6667.89 6612.59 1179.19 -1.4e04 71.00 274.21 6700.45 6645.15 1186.13 -1.4e04 71.00 274.21 6733.01 6677.71 1193.06 -1.4e04 71.00 274.21 6765.57 6710.27 1200.00 -1.4e04 71.00 274.21 6798.13 6742.83 1206.93 -1.4e04 71.00 274.21 6830.68 6775.38 1213.87 -1.4e04 71.00 274.21 6863.24 6807.94 1220.80 -1.5e04 71.00 274.21 6895.80 6840.50 1227.74 -1.5e04 71.00 274.21 6922.30 6867.00 1233.38 -1.5e04 71.00 274.21 6928.36 6873.06 1234.67 -1.5e04 71.00 274.21 6960.92 6905.62 1241.61 -1.5e04 71.00 274.21 6993.48 6938.18 1248.54 -1.5e04 71.00 274.21 7026.04 6970.74 1255.48 -1.5e04 71.00 274.21 7058.60 7003.30 1262.41 -1.5e04 71.00 274.21 7091.16 7035.86 1269.35 -1.5e04 71.00 274.21 7120.30 7065.00 1275.56 -1.5e04 71.00 274.21 7123.72 7068.42 1276.28 -1.5e04 71.00 274.21 7156.28 7100.98 1283.22 -1.5e04 71.00 274.21 7163.30 7108.00 1284.72 -1.5e04 71.00 274.21 7188.84 7133.54 1290.16 -1.5e04 71.00 274.21 7221.40 7166.10 1297.09 -1.6e04 71.00 274.21 7228.30 7173.00 1298.56 -1.6e04 71.00 274.21 7240.26 7184.96 1301.11 -1.6e04 71.00 274.21 7253.95 7198.65 1304.03 -1.6e04 71.00 274.21 7268.30 7213.00 1307.09 -1.6e04 71.00 274.21 7275.30 7220.00 1308.58 -1.6e04 70.14 274.21 7286.75 7231.45 1310.96 -1.6e04 67.64 274.21 7322.77 7267.47 1317.81 -1.6e04 MapN MapE DLS TFO C ft ft degl10oft deg 5958647 .41 365494 .20 0.00 0.00 5958655 .87 365400 .04 0.00 0.00 5958664 .34 365305 .88 0.00 0.00 5958672 .81 365211 .71 0.00 0.00 5958681 .27 365117 .55 0.00 0.00 5958686 .75 365056 .71 0.00 0.00 Albian 96 5958689 .74 365023 .39 0.00 0.00 5958698 .21 364929 .22 0.00 0.00 5958706 .68 364835 .06 0.00 0.00 5958715 .14 364740 .90 0.00 0.00 5958723 .61 364646 .73 0.00 0.00 5958732 .08 364552 .57 0.00 0.00 5958740 .54 364458 .41 0.00 0.00 5958749 .01 364364 .24 0.00 0.00 5958757 .48 364270 .08 0.00 0.00 5958765 .94 364175 .92 0.00 0.00 5958774 .41 364081 .75 0.00 0.00 5958782 .88 363987 .59 0.00 0.00 5958791 .34 363893 .43 0.00 0.00 5958799 .81 363799 .26 0.00 0.00 5958808 .28 363705 .10 0.00 0.00 5958816 .74 363610 .94 0.00 0.00 5958825 .21 363516 .77 0.00 0.00 5958833 .68 363422 .61 0.00 0.00 5958842 .14 363328 .45 0.00 0.00 5958850 .61 363234 .28 0.00 0.00 5958859 .08 363140 .12 0.00 0.00 5958867 .54 363045 .96 0.00 0.00 5958876 .01 362951 .79 0.00 0.00 5958884 .48 362857 .63 0.00 0.00 5958892 .94 362763 .47 0.00 0.00 5958901 .41 362669 .31 0.00 0.00 5958908 .30 362592 .67 0.00 0.00 Top HRZ 5958909. 88 362575 .14 0.00 0.00 5958918. 35 362480 .98 0.00 0.00 5958926. 81 362386 .82 0.00 0.00 5958935. 28 362292 .65 0.00 0.00 5958943. 75 362198 .49 0.00 0.00 5958952. 21 362104 .33 0.00 0.00 5958959. 79 362020 .05 0.00 0.00 Base HRZ 5958960 .68 362010 .16 0.00 0.00 5958969 .15 361916 .00 0.00 0.00 5958970 .97 361895 .69 0.00 0.00 K-1 5958977 .61 361821 .84 0.00 0.00 5958986 .08 361727 .67 0.00 0.00 5958987 .88 361707 .70 0.00 0.00 Kuparuk D 5958990 .99 361673 .10 0.00 0.00 5958994 .55 361633 .51 0.01 67.26 5958998 .28 361592 .01 0.00 0.00 Kuparuk C 5959000 .10 361571 .77 0.00 0.00 LCU 5959003 .01 361539 .43 2.50 180.00 5959011 .37 361446 .53 2.50 180.00 OR161NAL • ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska InC. Date: 7/11/2007 Time: 15:48:23 Page: 6 Field: Colville River Unit Co-ordinate(NE) Refere nce: Well: Plan: CD4-322; True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-322wp08 55.3 Well: Plan: CD4-322 Section (VS) Reference: Well (O,OON,O.OOE,274.60Azi) Wellpath: Plan: CD4-322 Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl Azim TVD SysTVD NIS E/W MapN MapE DIS TFO Comment ft deg deg ft ft ft ft ft ft deg/100ft deg 18800.00 65.14 274.21 7362.82 7307.52 1324.54 -1.6e04 5959019.58 361355.29 2.50 180.00 18900.00 62.64 274.21 7406.82 7351.52 1331.13 -1.6e04 5959027.63 361265.87 2.50 180.00 19000.00 60.14 274.21 7454.71 7399.41 1337.57 -1.6e04 5959035.50 361178.45 2.50 180.00 19100.00 57.64 274.21 7506.37 7451.07 1343.86 -1.6e04 5959043.17 361093.19 2.50 180.00 19116.59 57.22 274.21 7515.30 7460.00 1344.88 -1.6e04 5959044.42 361079.27 2.50 180.00 Alpine A 19134.94 56.77 274.21 7525.30 7470.00 1346.01 -1.6e04 5959045.80 361063.94 2.50 180.00 Base Alp A 19200.00 55.14 274.21 7561.72 7506.42 1349.97 -1.6e04 5959050.63 361010.25 2.50 180.00 19300.00 52.64 274.21 7620.65 7565.35 1355.90 -1.6e04 5959057.87 360929.81 2.50 180.00 19387.87 ' 50.44 274.21 7675.30 7620.00 1360.95 -1.6e04 5959064.03 360861.29 2.50 180.00 7"x 8 3/4" Targets Map Map <---- Latitude ----> <--_ Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting -Deg Miu Sec beg Min Sec Dip. Dir. ft ft ft ft ft CD4-322wp06 T1 7240.30 1301.12 -16118.02 5958991.00 361673.00 70 17 44.563 N 151 7 12.405 W -Plan hit target Annotation MD TVD ft ft 319.30 319.30 KOP; 2.5 DLS, 265 TFO 519.30 519.05 Build 3 DLS, 60 TFO 819.30 815.65 Build; 3.5 DLS 2549.23 2060.51 Sail; 71 ° for 15909' 19387.86 7675.29 TD; 19388' MD, 7675' TVD Casing Points MD TVD Diameter .Hole Size Name ft ft in in 3591.92 2400.00 9.625 12.250 9 5/8" x 12 1 /4" 19387.87 7675.30 7.000 8.750 7"x 8 3/4" Formations MD TVD Formations Lithology Dip Angle `Dip Direction ft ft deg r deg 783.19 780.30 Base Permafrost 0.00 0.00 3009.29 2210.30 C-40 0.00 0.00 3638.91 2415.30 C-30 0.00 0.00 4759.95 2780.30 C-20 0.00 0.00 8046.27 3850.30 K-3 0.00 0.00 8752.67 4080.30 Basal K-3 0.00 0.00 8860.17 4115.30 K-2 0.00 0.00 9105.87 4195.30 Base K-2 0.00 0.00 13282.88 5555.30 Albian 97 0.00 0.00 14864.61 6070.30 Albian 96 0.00 0.00 17481.38 6922.30 Top HRZ 0.00 0.00 18089.50 7120.30 Base HRZ 0.00 0.00 18221.57 7163.30 K-1 0.00 0.00 18421.21 7228.30 Kuparuk D 0.00 0.00 18544.07 7268.30 Kuparuk C 0.00 0.00 18565.57 7275.30 LCU 0.00 0.00 19116.59 7515.30 Alpine A 0.00 0.00 19134.94 7525.30 Base Alp A 0.00 0.00 ORIGINAL ConocoPhillips Alaska, Inc. Anticollision .Report Company: ConoCOPhillips Alaska Inc. Date: 7/12/2007 Time: 09:54:46 Page: 1 Fyeld: Colville River Unit Reference Site: Alpine CD4 Co-ordinate(NE) Refe rence: Well: Plait: CD4-322; True North Reference Well: Plan:-CD4322 Vertical (TVD) Reference: CD4-322wp0$ 55.3 Reference Wellpath: Plan; CD4-322 Db: r Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-322wp08 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 19387.87 ft Scan Method: Trav Cylinder North Maximum Radius: 2135.16 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3591.92 2400.00 9.625 12.250 9 5/8" x 12 1 /4" 19387.87 7675.30 7.000 8.750 7"x 8 3/4" Plan: CD4-322wp08 Date Composed: 5/29/2007 Kuparuk target Version: 3 Principal: Yes Tied-to: From Well Ref. Point Summary 4______._~.__~___- Offset Wellpath -_______________> Reference Offset Ctr-Ctr No-Go Allowable Site. Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD4 CD4-17 CD4-17 V13 1039.78 1075.00 100.12 17.99 82.12 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 340.87 325.00 239.79 6.40 233.38 Pass: Major Risk Alpine CD4 CD4-211 CD4-211 V2 346.32 350.00 218.90 6.89 212.01 Pass: Major Risk Alpine CD4 CD4-213 CD4-213 V4 346.44 350.00 181.68 6.89 174.79 Pass: Major Risk Alpine CD4 CD4-214 CD4-214 V3 486.99 500.00 157.72 8.78 148.94 Pass: Major Risk Alpine CD4 CD4-215 CD4-215 V4 939.41 975.00 131.24 18.81 112.43 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 979.15 1000.00 70.18 17.30 52.88 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 978.19 1000.00 70.17 17.29 52.89 Pass: Major Risk Alpine CD4 CD4-318 CD4-318PB1 V3 979.15 1000.00 70.18 17.30 52.88 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 422.03 425.00 56.94 8.14 48.80 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 397.02 400.00 39.99 6.81 33.18 Pass: Major Risk Alpine CD4 CD4-320 CD4-320P61 V4 397.02 400.00 39.99 6.81 33.18 Pass: Major Risk Alpine CD4 CD4-321 CD4-321 V16 597.33 600.00 17.03 11.23 5.79 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 674.32 650.00 97.32 10.93 86.40 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 252.59 250.00 201.57 4.56 197.02 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 252.59 250.00 201.57 4.58 197.00 Pass: Major Risk Alpine CD4 Plan: CD4-07 Plan: CD4-07 VO Plan: 368.00 375.00 300.49 7.80 292.69 Pass: Major Risk Alpine CD4 Prelim: CD4-223 Prelim: CD4-223 V1 36.30 36.30 20.01 No Offset Stations Alpine CD4 TDed: CD4-16 Plan: CD4-16 V1 Plan: 1561.70 1625.00 93.64 25.25 68.39 Pass: Major Risk Alpine CD4 TDed: CD4-16 TDed: CD4-16 V9 1870.19 1950.00 66.86 31.78 35.08 Pass: Major Risk Prelim: Alpine CD5 Prelim: AW-4C Prelim: AW-4C VO Plan: 1 8861.73 1 6334.22 1964.92 620.38 1344.53 Pass: Major Risk Prelim: Alpine CD5 Prelim: AW-5C Prelim: AW-5C VO Plan: Out of range Site: Alpine C D4 Well: CD4-17 Rule Assigned: Major Risk Wellpath: CD4-17 V13 Inter-Sit e Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset.. TFO+A ZI TFO-HS Casing/HSilistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft fl ft 36.80 35.80 36.60 36.60 0.00 0.00 75.46 75.46 9.625 100.06 0.92 99.14 Pass 49.20 49.20 50.00 50.00 0.01 0.02 75.46 75.46 9.625 100.06 1.12 98.94 Pass 74.20 74.20 75.00 75.00 0.04 0.04 75.46 75.46 9.625 100.06 1.51 98.55 Pass 99.20 99.20 100.00 100.00 0.07 0.09 75.46 75.46 9.625 100.05 1.96 98.09 Pass 124.20 124.20 125.00 125.00 0.13 0.15 75.45 75.45 9.625 100.01 2.50 97.51 Pass 149.20 149.20 150.00 150.00 0.18 0.20 75.44 75.44 9.625 99.94 3.04 96.90 Pass 174.20 174.20 175.00 175.00 0.24 0.26 75.43 75.43 9.625 99.84 3.58 96.25 Pass 199.20 199.20 200.00 200.00 0.30 0.32 75.42 75.42 9.625 99.71 4.12 95.58 Pass 224.20 224.20 225.00 225.00 0.35 0.37 75.40 75.40 9.625 99.54 4.66 94.88 Pass 249.20 249.20 250.00 250.00 0.41 0.43 75.39 75.39 9.625 99.35 5.20 94.15 Pass 274.20 274.20 275.00 275.00 0.47 0.48 75.39 75.39 9.625 99.10 5.73 93.38 Pass 299.19 299.19 300.00 299.99 0.52 0.52 75.48 75.48 9.625 98.70 6.24 92.47 Pass 323.99 323.99 325.00 324.98 0.58 0.57 75.66 170.66 9.625 98.14 6.73 91.41 Pass 347.96 347.96 350.00 349.97 0.60 0.61 75.96 170.96 9.625 97.60 7.16 90.44 Pass 371.94 371.94 375.00 374.95 0.63 0.66 76.36 171.36 9.625 97.12 7.59 89.53 Pass GRAM ORIGINAL 8000 6000 TDed: CD4-16 TDed: CD4-16 400 CD4- 17 CD4-17 o ~,, 200 CD4-322 w 08 + `. CD 4-319 CD4-31 9 o L .~ ~ ~ CD4-318 CD4-318A 0 v~ -200 -4000 CD4-321 CD4-321 CD4-318 CD4-318PB 1 -6000 C D4-318 ...CD4- 318A -24000 -22000 -20000 -18000 -16000 -14000 -12000 -10000 -8000 -6000 West(-)/East(+) [2000ft/in] Closest in POOL ...,.., F-w ..s~"' Closest Approac h: Reference Well: CD4-322wp08 Plan Offset Well: CD4 -17 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Distance. Depth Angle TRUE Azi. ND E(+)/W(-) (274.6°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (274.6°) Comments POOL Min Distance POOL Min Distance (4711.1 ft) in POOL (4711.1 ft) in POOL (7108 - 7618.99 (7108 - 7618.99 NDss) to CD4-17 NDss) to CD4- (7108 - 7487.66 322wp08 Plan (71 4711.1 18236 71 274.2 7112.115 5958970 361880.1 15960.9 NDss) 17641 90.36 332.21 7434.08 5961092 366073.5 12086.13 7487.66 NDss) losest Approac h: Reference Well: CD4-322wp08 Plan Offset Well: CD4 -318A ~ Coords. - Coords. - ASP ASP -D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS istance. Depth Angle TRUE Azi. ND E(+)/yy(-) (274.6°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (274.6°) Comments POOL Min Distance POOL Min Distance (4933.22 ft) in POOL (4933.22 ft) in POOL (7108 - 7618.99 (7108 - 7618.99 NDss) to CD4-318A NDss) to CD4- (7108 - 7193.12 322wp08 Plan (7108 - 4933.22 -t~}J. 18236 71 274.2 7112.115 5958970 361880.1 15960.9 NDss) 20612 92.13 353.1 7156.055 5957094 366442.6 11238.85 7193.12 NDss) Closest Approac h: Reference Well: CD4-322wp08 Plan Offset Well: CD4 -321 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Distance. Depth Angle TRUE Azi. ND E(+)/~y(_) (274.6°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (274.6°) Comments POOL Min Distance POOL Min Distance (5268.07 ft) in POOL (5268.07 ft) in POOL (7108 - 7618.99 (7108 - 7618.99 NDss) to CD4-321 NDss) to CD4- (7108 - 7754.52 322wp08 Plan (7108 - 5268.07 18236 71 274.2 7112.115 5958970 361880.1 15960.9 TVDss) 18004 70.57 255.3 7100.16 5953737 362486.5 14853.03 7754.52 NDss) CD4-322wp08 PoolSummary.~ds 7/12/2007 10:46 AM Opxd.r. CenecePklNPC AI«kal«. GNJ Cart.<Ibn: -0.93 leb N.'. PN/A NNa CdMa Nver Un0 MaOn.Nc D.cUnallon: 31]U ° APP No: sN/A YN! C04J33wp0U qp: ° Ary Ne: JN/A RSG IX/A O.Ui.Y P.r 100 5)d.m (rv0) bler.nc.: Mean Sea lerN sNl.<. 1«.x« Original VS Plane: 274.60 Po..nl w.t ry.n: co4Jn x J]A{{.39 Vlew V5 Plane: 274.60 PAI NNgfF. ss.w Y: 595){3610 It UrM Sydem. API Rayed / iP5 S.cNOn (VJ)RNw.n<.: WFII Comments: V V O 0 O U t 0) 1 N N T Plan View _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 'o ---- 596 596 596 595 595 - -_---i 595 595 595 595 595 595 595 595 2000 1000 0000 9000 8000 7000 6000 5000 4000 3000 2000 1000 0000 4000 • 5000 6000 7000 8000 9000 o ~ 8 N S o o pg o ~ o o ~ o o S 8 ~ o ~ ~ g ~ S 8 g .- O n W P O .- N (h V h b n N 0` O ~ N M O Vertical Section along'"Vew V~Plane" '- '- '- ~ '- n' ~ N ~ ~' Combo Preview Page 1 of 1 (C D4-322wp08 Toolbox.xls) 7/12/2007 10:54 AM • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~D ~ 32 Z PTD# ~ ~' ~~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a .spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until. after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~CompanX Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev:7/l3/2007 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, NANUQ-KUPK OIL -120185 Well Name: COLVILLE RIV NAN-K CD4-322 Program SER Well bore seg ^ PTD#:2071010 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER / PEND GeoArea 890 Unit 50380 On/Off Shore On Annular Disposal ^ Administration 1 P_ermikfee attached_ - _ Nq - No longer required since $B 109.was approved._ 2 Lease number appropriate- _ . , _ - _ No . _ - - _ Correction made to 401:- surf_ in ADL 3$0077, well passes_thru ADL387208, TD in_ASRC NPRA02._ - 3 Uniquewell_nameandnumber______________________________________ Yes- __-__._._--_- ------------------------------------------------------------- 4 Well located in_a defined-pool. Yes - _ Colville-River Field, Colville River Unit Nanuq,Kuparuk Oil Pool, governed by Conservation Order No. 563. 5 Welltocated proper distance from drilling unitboupdary_ Yes - - Conservation Order No. 563 contains no spacing restrictions with respect-to drilling unit boundaries. - - .: - , . - 6 Well located proper distance from other wells_ Yes - - - .. -Conservation Order No. 563 has_no interwell_spacingnstrictions, - - 7 Sufficient acreage-available in_drilling unit- _ _ _ - - Yes - - - - Conservation Order No. 563 has_no interwell_spacingnstrictions, Wellbore-will be more than 500' from - - - _ , . - 8 If_deviated, is-wellbore platinc_luded - _ - , Yes external property line where ownership or landownershipchanges.. Well v~ill lie wiihin_the CRU, X3700}eet- - . 9 Operator only affected party___-_-._____,_________________________ Yes_ _____-fromthewesternboundaryofthe CRU.-___-____-_--_-,__________-_,___-,-_,--,-,- 10 Operator has-appropriate bond in force____..,_________________________ Yes_ _.._--------_-_.-.---_ 11 Permit can he issued __w_iithout conservation order_ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - Appr Date 12 Permit_can be issued without administrative_approval _ Yes _ _ -- - SFD 7!18!2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata apthorized by Injection Order # (put 10# in_comments)-(For_ Yes _ _ _ _ _ _ _ Colville-River Field, Colville River unit, Nanuq,Kuparuk Oil Pool, governed by Area Injection_Order 27 _ _ _ _ . _ _ _ 15 All wells-within114_mile area ofreyiewidentified(Forservicewellonly)_______________ Yes_ ______None...-________--__,-_.___.______--___._ ________--_-_ -------------- 16 Pre-produced injector: duration of preproduction less than 3 months_ (For_service well only) N_o, - _ - , _ -Pre-produced for short period for clean-up only. _ _ , - _ - 17 Nonconyen, gas_conforms to AS31.05,030Q.1.A),([.2.A-D) , .. _ . - _ _ _ _ NA- _ Engineering 18 Condu_ctarstring-provided___-_-._ _---_ - Yes_ ______________________,..- - -- 19 Surface casing-proiectsall_knownUSDWS____-______._,._-_____-- _--- NA, ______Naaquifers,AIQ1$Aconclusion_3._---_-________ - .--_-------------------- 20 CMTv_oladequake-tocirculate_onconducto[&surf_csg___________________ Yes- --____, ____--__---____ ___ __--_--__----____-_,-__-_--._--__-__- _- _ 21 CMT_v_oladequatetotie-in long string to surfcsg_________ __________________ No__ ______Ann_ulardisposalultimatelyplanned,-_--________,-,_-,-__ __--_--__--_---.--.- 22 CMTwillcoygr_allknown-productivehorizons______________________________ Yes- --_-._- 23 CasingdesynsadeguateforC,_T,B&permafrost---------------------- Yes- -----------------.----,-------------.--- ------------------------- 24 Adequate tankage, or reserve pit - - - - _ - _ - - _ - - _ - - Yes _ - _ _ Rig is_equipped with steel_pits. No reserve-pitplanned, All waste to,approvedannulus_or disposal well(s). - - . - 25 If,a-re-drill,has_at_0-403 for abandonment been approved______________________ NA__ _______--___-____--__----- -- -- 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ Proximity analysis performed, Traveling cylinder path calculated, Gyros possible in shallow su_rfaee, _ . - . _ _ - - 27 If,diverterrequired, does it meet regulations_ _ _ _ _ - _ - - _ - - NA - - _ - . - Diverter waiver requested, No problems with 14 prio[ wells.- , _ _ - _ - _ - _ _ _ - - Appr Date 28 Drilling fluid_ program sehematic_& equip listadequate_ - - - - _ Yes _ - - - - - .Maximum expected formation pressure 9,3 EMW.- Planned MW 9,6.- 9,8_ppg._ - , , - - - - _ - 7!1812007 TE M 29 BO_PES,-do they meet regulation-_--_____----.---------,_----- Yes -------- /// ~_~ ~O'r1i~ 30 BOPE_press rating appropriate; test to_(put prig in comments)_ _ - _ _ - - - Yes -----------------------_------------,-----------------,------ . - - _ _ - _ MASP calculated at 2705psi, 3500_psi_appropriate. CPAI usually_tests to 5000 psi. - - - _ - - 31 Choke_manifoldcompliesw/API_RP-53fMay 84)-.---______-__---___ Yes_ _-__-.-_------------------- ---------------------------------------------- 32 Work will occur without operation shutdown_------------------------- --- Yes_ ___-----_________._-----._- 33 Is presence ofH2Sgasprobable__________________________________ __ No__ -___-H2ShasnotbeenrepodedatCD4.-Righas_sensors-and alarms.__,________._.__-______-____ 34 Mechanical condition of wells within AOR verified (For service well only - _ _ _ - Yes _ _ _ - No AOR issues, - , _ _ _ _ - - _ _ - _ . - _ _ - - - ------------------ Geology 35 Permitean be issued wlo hydrogen_ sulfide measures _ _ , - , Yes _ _ _ - _ H2S not encountered in offset wells, However, rig will be equipped with_operational. sensors. 36 _D_ata_presented on potential overpressure zones- - - .. - - -- Yes - _ _ _ - -Expected r_eservoir_pressure is 9,3-ppg EMW; will be drilled with 9.6.9,8_ppg mud.- - . - _ . Appr Date 37 Seismicana(ysisofshallowgas-zones __________________ NA__ ______Noneencountedin,l4wellsdrilled-from pad.-________----__--_-_____-_-__-,__,__. SFD 711812007 38 Seabed condition suryey_(if off_•shore) - _ - - - - - . - - -~ NA -- 39 _C_ontactnamelphoneforweekly-progress reports[exp~oratoryonly~----------------- NA__ ____-_______--___-__ __________- ___-._ Geologic Engineering Public Date: Date Date Slant 71 de ree in ector in the western ortion of the ool, 3700' inside the western bounds of the CRU. ( 9 ) 1 p p ry Commissioner: Commissioner: Commissioner I~%~~'~ ~~~ d~ Well History File APPENDIX Information of detailed nature that is not • particularly gem~ane io the Well Pennitiing Process but is part of the history file. To improve the readability of the Well History file and to simplify Minding information, information of this nature is accumulated at the end of ttie file under APPENDIX. No special effort has been made to chronologically organize this category of information. i ~ 3 cd4-322.tapx Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov O1 10:25:15 2007 Reel Header Service name .............LISTPE Date . ...................07/11/O1 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................07/11/O1 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services scientific Technical services CD4-322 501032055100 ConocoPhillips Alaska Inc. Sperry Drilling Services O1-Nov-07 MWD RUN 2 W-0005159277 D. RICHARDSO D. BURLEY 24 11N 4E 2292 477 55.73 19.00 Page 1 ao~-to< # ~s~a ~ vac 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE BIT SIZE (IN) 8.750 cd4-322.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 3580.0 r~ u 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), GEOPILOT ROTARY-STEERABLE BHA (G P), AT-BIT GAMMA (ABG), AND ACOUSTIC CALIPER (ACAL). 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 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. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE 6. MWD RUNS 1,2 REPRESENT WELL CD4-322 WITH API#: 50-103-20551-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 19452'MD/7739'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 (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). Page 2 • cd4-322.tapx PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ALD HOLE SIZE INDICATOR-DERIVED (8.75~~ BIT) MUD WEIGHT: 9.65 - 10.1 PPG MUD SALINITY: 200 - 400 PPM CHLORIDES FORMATION WATER SALINITY: 23,000 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.......07/11/O1 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3551.0 19412.0 FET 3570.0 19398.5 NPHI 3570.0 19362.5 NCNT 3570.0 19362.5 PEF 3570.0 19376.0 RPS 3570.0 19398.5 RHOB 3570.0 19376.0 RPD 3570.0 19398.5 RPx 3570.0 19398.5 DRHO 3570.0 19376.0 FCNT 3570.0 19362.5 RPM 3570.0 19398.5 ROP 3591.0 19452.0 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 MwD 2 3551.0 19452.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Page 3 • • cd4-322.tapx Data Reference Point ..............undefined Frame Spacing....... .. ........60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3551 19452 11501.5 31803 3551 19452 FCNT MWD CNTS 639.07 3105.59 1199.27 31586 3570 19362.5 NCNT MWD CNTS 118585 194663 149213 31586 3570 19362.5 RHOB MWD G/CM 0.87 3.304 2.42278 31613 3570 19376 DRHO MWD G/CM -4.073 0.189 0.0355009 31613 3570 19376 RPD MWD OHMM 0.74 2000 8.08916 31658 3570 19398.5 RPM MWD OHMM 0.63 1792.92 7.20541 31658 3570 19398.5 RPS MwD OHMM 1.06 1887.47 6.73349 31658 3570 19398.5 RPX MWD OHMM 1.33 1732.96 6.52857 31658 3570 19398.5 FET MWD HOUR 0.23 210.75 0.863872 31658 3570 19398.5 GR MWD API 46.08 410.81 114.481 31723 3551 19412 PEF MWD BARN 1.86 14.05 2.94091 31613 3570 19376 ROP MWD FT/H 0.4 322.34 161.179 31723 3591 19452 NPHI MwD PU-S 4.87 57.26 33.1571 31586 3570 19362.5 First Reading For Entire File..........3551 Last Reading For Entire File...........19452 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/O1 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... Page 4 • cd4-322.tapx version Number. ........1.0.0 Date of Generation.......07/11/O1 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3551.0 19412.0 RPM 3570.0 19398.5 PEF 3570.0 19376.0 FET 3570.0 19398.5 RPx 3570.0 19398.5 NPHI 3570.0 19362.5 RPS 3570.0 19398.5 RPD 3570.0 19398.5 FCNT 3570.0 19362.5 DRHO 3570.0 19376.0 RHOB 3570.0 19376.0 NCNT 3570.0 19362.5 OP 3591.0 19452.0 $ LOG HEADER DATA DATE LOGGED: 08-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 19452.0 TOP LOG INTERVAL (FT): 3590.0 BOTTOM LOG INTERVAL (FT): 19452.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 44.9 MAXIMUM ANGLE: 73.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 121079 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Litho-Dens 224102 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3580.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (s): 34.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 400 Page 5 i i cd4-322.tapx FLUID LOSS (C3): 1.0 RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE : .530 167.0 MUD FILTRATE AT MT: 6.000 70.0 MUD CAKE AT MT: 2.600 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....undefin ed Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefin ed Absent value ................. .....-999 Depth units. .. .. ..... Datum Specification Block sub -type...0 Name service order units size N sam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MwD020 OHMM 4 1 68 20 6 RPM MwD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPx MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MwD020 PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3551 19452 11501.5 31803 3551 19452 FCNT MWD020 CNTS 639.07 3105.59 1199.27 31586 3570 19362.5 NCNT MWD020 CNTS 118585 194663 149213 31586 3570 19362.5 RHOB MwD020 G/CM 0.87 3.304 2.42278 31613 3570 19376 DRHO MWD020 G/CM -4.073 0.189 0 .0355009 31613 3570 19376 RPD MWD020 OHMM 0.74 2000 8.08916 31658 3570 19398.5 RPM MWD020 OHMM 0.63 1792.92 7.20541 31658 3570 19398.5 RPS MWD020 OHMM 1.06 1887.47 6.73349 31658 3570 19398.5 RPx MWD020 OHMM 1.33 1732.96 6.52857 31658 3570 19398.5 FET MWD020 HOUR 0.23 210.75 0.863872 31658 3570 19398.5 GR MWD020 API 46.08 410.81 114.481 31723 3551 19412 PEF MwD020 BARN 1.86 14.05 2.94091 31613 3570 19376 ROP MWD020 FT/H 0.4 322.34 161.179 31723 3591 19452 Page 6 • cd4-322.tapx NPHI MWD020 PU-S 4.87 57.26 33.1571 31586 First Reading For Entire File..........3551 Last Reading For Entire File...........19452 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/O1 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/11/O1 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library Reel Trailer Service name .............LISTPE Date . ...................07/11/O1 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library Physical EOF Physical EoF End Of LIS File 3570 19362.5 scientific Technical services Scientific Technical Services Page 7
