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202-248
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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory 0 7. Well Name: Puviaq 1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final • 310 -394 12/9/2010 N PRA Exploration 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 �gg � fluids, formation fluids and S hilt) FEB U ti3 0 any necessary water added Previous 9794 100 0 9894 totals (bbls): 2010 / 4th 0 0 0 0 2011 /1st 0 0 0 0 2011 / 2nd 0 0 185* 185 2011 / 3rd 0 0 0 0 2011 / 4th 0 0 0 0 • Total Ending Report is due on the 20th Volume 9794 100 185 10079 0 (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): *freeze protect and injectivity test volumes 1 hereby certify that the foregoing is truce JJJJ and correct to the best of my knowledge. // Signature: J "'' c.. t\ Date: �I (� - - 0 9 (2— Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 i- . orm 1u -4Li Mev. IZUU4 S JAN G 9 +"' 4 A i j- 1 nv5 rRA, rrt3iv5 UN RtvtITot brut buomlt in uupucate DATA SUBMITTAL COMPLIANCE REPORT 10/21/2011 Permit to Drill 2022480 Well Name /No. PUVIAQ 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 279 - 20008 -00 -00 MD 7900 TVD 7900 Completion Date 4/1/2006 Completion Status SUSP Current Status P &A UIC. REQUIRED INFORMATION Mud Log Yes Samples No Directional Surve No DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: 0 Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ED C Tf •X3756 Induction /Resistivity 112 7900 Open Formation tester, OH logs, Dipmeter. Magnetic Resonance Graphics TIFF, PDS, PDF plus XLS TXT data C Las &1 83 Sonic 3076 7877 Open DIPOLE Sonic Imager, Cal ,t,E*111-- DLIS and LAS with PDF & PDS /Graphics XE C Las 4484 Formation Micro Ima 3076 7877 Open FMI LAS & DLIS With PDF / & PDS Graphics ED C Las ''14485 Induction /Resistivity 50 7900 Open CMR, LWD, MDT, MCST, Mudlog Survey w /Graphics Xog Mud Log 2 Col 35 7900 Open 5/22/2003 /Cog Induction /Resistivity 25 Col 112 7900 Open 5/22/2003 MD EWR DGR ROP III ,tog Density 25 Col 112 7900 Open 5/22/2003 MD SLD CTN DGR /tog Sonic 5 Col 3100 7876 Open 5/22/2003 MD Dipole Sonic Imaging Tool - DSI P &S - Lower & Upper Dipoles Log ( Formation Micro Ima 5 Col 3100 7876 Open 5/22/2003 MD Fullbore Imaging Tool - FMI /Log See Notes 5 Col 3100 7876 Open 5/22/2003 MD CMR Combinable Magnetic Resonance og Formation Tester 5 Col 5947 7876 Open 5/22/2003 MD Modular Formation Dynamics Tester pt Report: Final Well R 35 7900 Open 5/22/2003 i: Report: Final Well R 7156 7318 Open 5/22/2003 Core Photos C Exc 14893�nalysis - Misc 7156 7317 Open 10/20/2011 Core Analysis by OMNI Labs DATA SUBMITTAL COMPLIANCE REPORT 10/21/2011 Permit to Drill 2022480 Well Name /No. PUVIAQ 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 279 - 20008 -00 -00 MD 7900 TVD 7900 Completion Date 4/1/2006 Completion Status SUSP Current Status P &A UIC N 'FED C Wrd 14894 "Report: Final Well R 35 7900 Open 10/20/2011 Final Well Report, Mudlog PDF, Mudlog reports HTML >" C Exc 14895 See Notes 0 7900 Open 10/20/2011 Misc reports( (LOTS of i them) XLS, TXT, DOC, ASC, ADT, EMF, PDF, DAT D C Dls 14896 Formation Micro Ima 3100 7876 Open 10/20/2011 Well Cores /Samples Information: - -- Sample ill Interval Set Name Start Stop Sent Received Number Comments VGore Chips 7156 7317 1119 Cores and /or Samples are required to be submitted. This record automatically created 1 from Permit to Drill Module on: 1/9/2003. `' Cuttings 120 7890 1119 ADDITIONAL INFORMATION Well Cored? D N Daily History Received? N Chips Received? �Y N Formation Tops b N Analysis 1DN Received? Comments: ill Compliance Reviewed By: ___ Date 1 ` t 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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory 0 7. Well Name: Puviaq 1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 310 -394 12/9/2010 NPRA Exploration 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 9794 100 0 9894 • totals (bbls): 2010 / 4th 0 0 0 0 2011 / 1st 0 0 0 0 2011 / 2nd 0 0 185* 185 2011 / 3rd 0 0 0 0 Total Ending Report is due on the 20th Volume 9794 100 185 10079 0 (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 0 Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances .„4,140.100EF 1 Oz 6 all Description(s): *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: '1'._ (1_,c,__ Date: (.1 (..,/7 ` `� Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 RBA`MS OCT 14 2011 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Ask IIIP "'SEAN PARNELL, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7 AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501 -3560 DIVISION OF OIL & GAS PHONE: (907) 269 -8800 FAX: (907) 269 -8938 CERTIFIED MAIL RETURN RECEIPT REQUESTED September 13, 2011 Michael J. Faust Conoco Phillips Alaska, Inc. P.O. Box 100360 ATO 1468 Anchorage, Alaska 99501 -0360 Re: Request for Extended Confidentiality - Puviaq No. 1 Well Dear Mr. Faust: By letter dated January 21, 2008, ConocoPhillips Alaska, Inc. (ConocoPhillips), as operator and on behalf of the working interest owners of the Puviaq No. 1 well, requested extended confidentiality for the reports and information generated from the well and filed with the Alaska Oil and Gas Conservation Commission (Commission), as required by state law. AS 31.05.035 requires operators to provide the Commission with certain reports and information on wells drilled within the state. The Commission must keep the well information confidential for 24 months following a 30 -day filing period. The data may be held confidential for a longer period the commissioner of natural resources finds that the required reports and information contain significant information relating to the valuation of unleased land in the same vicinity ...." Id.; see also 11 AAC 83.153. The Puviaq well was drilled on federal lease AA- 081854 within the NPR -A. The operator also files the reports and information on wells with the Bureau of Land Management. Under the NPR -A lease terms, "during the existence of [the] lease," the information remains confidential in accordance with the federal Freedom of Information Act (FOIA). Federal lease AA-081854 was relinquished on August 8, 2011 and the well information is no longer protected from disclosure under the federal lease or FOIA. Similarly, under 11 AAC 83.153(b)(1) "[ reeports or information for which extended confidentiality is requested or has been granted under AS 31.05.035 will not be eligible for extended confidentiality when the lease on which the well is drilled has expired." As a result, the well information for which ConocoPhillips has sought extended confidentiality is no longer eligible for extended confidentiality under either federal or state law. Thus, these reports and information are now subject to public records disclosure. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." Michael J. Faust, ConocoPhillaklaska, Inc 9/13/2011 Page 2 of 2 By copy of this letter, I am informing the Commission that no basis exists for extended confidentiality of this information. A person affected by this decision may appeal it, in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(c) and (d) and may be mailed or delivered to Daniel S. Sullivan, Commissioner, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1- 907 - 269 -8918, or sent by electronic mail to dnr.appeals@alaska.gov. This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, W.C. Barron ru PosYz9e Director co: rfied Foe —.. 1 I'ostr..ark cc: Barbara Fullmer ConocoPhillips Alaska, Inc. Rtatum Rece P Fe1 € rs e 1? (cm dursamer Reccquiseea} Dan Seamount, Chairman, AOGCC Restfoted oellvetY Tee Julie Houle, Resource Evaluation, DOG ra (t Y, io soment Required) Michael J. Faust -- 1 e° Conoco Phillips Alaska, Inc. sirf P.O. Box 100360 N 4 ATO 1468 _. ....._. � Anchorage, Alaska 99501-0360 i'. COMPLETE y PET E � E TI , ON v yv SENDER: COMPLETE THIS SECTION \�� \ ...> COMPLETE r � lNpEt,tvERr It Complete items 1, 2, and 3. Also complete A. Si... re item 4 if Restricted Delivery is desired. X arAgent IN Print your name and address on the reverse ❑Addressee so that we can return the card to you. B, Received by ( Printed Name) C. Date of Delivery ■ Attach this card to the back of the mailpiece, or on the front if space permits. gd5trt5..A D. Is delivery address different from item 1 0 es 1. Article Addressed to: if YES, enter delivery address below: 0 No Michael J. Conoco Phillips Alaska, Inc. - P.Q. Box 100360 s. 5e lice Type ATO 1468 DB Certified Mail 0 pOess Mail Anchorage, Alaska 99501 -0360 0 Registered Return Receipt for Merchandise ❑ insured Mail 0 C.O.D. 4, Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) ? DID 2780 B 0 D 4 �'_,. 7 — PS Form 3$11, February 2004 Domestic Return Receipt 102595 -02 -M -1540 J 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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory El 7. Well Name: Puviaq 1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 12 or Final ❑ 310 -394 12/9/2010 NPRA Exploration 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 IP any necessary water added Previous 9794 100 0 9894 totals (bbls): 2010 / 4th 0 0 0 0 2011 / 1st 0 0 0 0 2011 / 2nd 0 0 185* 185 2011 / 3rd Total Ending Report is due on the 20th Ala Volume 9794 100 185 10079 0 (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): *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /4-e Olik Date: 7 (4 (1.-xi- Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 I Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate i RE!.i EJ iP Ei.iC1 ; /.4o, 1P Alaska Oil & Gina Cent. Gommissi©rr ConocoPh ilhps Angnerage Box 100360 Alaska 99510 -0360 April 26,2011 Commissioner State of Alaska Alaska 011 and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Report of Plug and Abandonment Operations Puviaq #1 (Exploratory Test) PTD 202 -248 Sundry No. 310 -392 Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW X= 450,547.8 & Y= 6,105,700.17 ASP5 NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Its Well Completion Report for the work performed in plugging and abandoning its Puviaq #1 well located in the Westem NPRA. Please find enclosed the following information for your files: 1) Form 10-407 Well Completion Report 2) Wellbore Schematic 3) Daily Operation Summary 4) P&A Operational Photographs If you have any questions or require any further information, please contact me at 265 -6377 or Chip Alvord at 265 -6120. 7Si re om Brassfleld Senior Drilling E • ineer cc: CONFIDENTIAL — Puviaq #1 Well File Chip Alvord ATO -1570 1 • STATE OF ALASKA • , , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other 0 Abandoned 0 Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ID GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. Aband.: 4/14/2011 202 -248 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 100360, Anchorage, Alaska 99510 3/8/2003 50- 279 - 20008 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1713' FNL, 444' FWL Sec. 35, T16N, R1 OW, UM 4/8/2003 Puviaq #1 Top of Productive Horizon: 8. KB (ft above MSL): 15. Field /Pool(s): 1713' FNL, 444' FWL Sec. 35, T16N, R10W, UM GL (ft above MSL): Total Depth: 9. Plug Back Depth(MD +TVD): Exploratory 1713' FNL, 444' FWL Sec. 35, T16N, R10W, UM Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 450547.8 y- 6105700 Zone- 5 7,900' ADL AA081854/L32589 TPI: x- 450547.8 y- 6105700 Zone- 5 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 450547.8 y- 6105700 Zone- 5 N/A 18. Directional Survey: Yes ❑ No El 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: _ N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94 H -40 Surface 112' Surface 112' 30" 315 sx AS1 n/a 13 -38" 72 L -80 Surface 1,423' Surface 1,423' 16" 184sx ASLITE+296sx AS1 n/a 9 -5/8" 53.5 L -80 Surface 3,167' Surface 3,167' 12.25" 231 sx CI "G" + additives n/a 7" 26 L -80 Surface 7,891' Surface 7,891' 8.5" 450 sx CI "G" + additives n/a 24. Open to production or injection? Yes Non If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 6,150' 5,94015940' 6725'/6725' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period �► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate .•.- 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ID If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED RBCMS APR 2 7 20114fi Alaska Oil & Gas Cans. C4 ssion Ancngralge Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE 4f z?, / / Submit original only 6 • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Ei No If yes, list intervals and formations tested, Top Nanushuk 470' 470' briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1190' 1190' Top Torok 3602' 3602' Top HRZ 6622' 6622' Lower Cretaceous Unconformity 6889' 6889' Simpson Interval 7145' 7145' J2 7602' 7602' Formation at total depth: 7900' 7900' Jurassic/Kingak 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Chip Alvord Title: Drilling Manager , Signature: J I _ Phone: 907 265 -6120 Date: 4( Ito ( � INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1b: 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: 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 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • ConocoPhilhips Puviaq #1 Operations summary April 08, 2011 Set and rig up equipment with spill containment. Fire boiler, apply heat to tree. April 09, 2011 Prepare to remove BPV and VR plugs. FMC hand did not have the correct flange for wing valve. Continue to work on tarps and maintenance equipment. Prepare 10 bbls of diesel for injectivity test. April 10, 2011 Continue with maintenance. Pull BPV in tree. Pull VR plug on 3 -1/2" annulus. April 11, 2011 Open and clean out valves in triplex pump. RU wireline unit. Work on fixing back lashed spool on drum. April 12, 2011 RU and test 3 -1/2" tubing to 1,500 psi for 15 min — good. Test 3 -1/2" x 7" annulus to 1,500 psi for 15 min —good. R IH with CCL /tubing puncher, shoot 5,750' - 5,752' interval with 7 spf. ✓ POOH and confirm all shots fired. Displace 17 bbls of diesel with 9.4 ppg brine. Mix and pump 17 bbls of 10.7 ppg ASL cement and displace with 46 bbls of 9.4 ppg brine. WOC. April 13, 2011 RIH on wireline with tubing puncher. Tag cement at 5,130'. Pull up and perforate interval 2,450' — 2,452'. POOH and confirm all shots fired. RU lines and perform injectivity test on 9- 5/8" x 13 -3/8" annulus. Send results to town and receive injection limitations from AOGCC. Mix and pump 100 bbls of 10.7 ppg ASL cement down 3 -1/2" tubing taking returns in 3 -1/2" x 7" annulus. Good cement at surface. Shut down pump. Rinse and clean equipment. April 14, 2011 Inject 50 bbls diesel, 58 bbls rinse water and 57 bbls used brine into 9 -5/8" x 13 -3/8" annulus at 1 bbl /min, 150 psi. Mix and pump 82 bbls of 10.7 ppg ASL cement into 9 -5/8" x 13 -3/8" annulus. Reconnect lines, mix and pump 74 bbls of 10.7 ppg ASL cement down 7" x 9 -5/8" annulus. Rinse tanks and flush lines with 20 bbls water. April 15, 2011 Dig out hole. Cut tree off at 5' below tundra level. Dress top of 16" casing and weld marker plate on. Casing cut and marker plate welding witnessed by BLM's Shane Walker. April 16, 2011 Load hole with 10 sacks of gravel and top with excavated material. Make a 5' mound above tundra level. Clean area, move out and Toad all equipment in preparation for demob. • • Puviaq #1- 4/21/2011 P &A Schematic, Sheet 1 of 2 Exploration Well - CONFIDENTIAL Nabors 16E RKB 10.7 ppg ASL cement from 2452' WLM to surface in tbg & annulus @ 30' 10.7 ppg ASL cement from surface to 13 -3/8" shoe @ 1423' MD Elevation: 2 GL BPMSL 10.7 to ppg 9-5/8" hoe en 3167' MD ace 20" 112' MD @ Conductor @ Surface Casing @ J j (1) Landing Nipple @ 499' MD: 1423'MD/TVD $ $ hi Camco 'DS' nipple w/ 2.875" No Go Profile 13 -3/8" 72 # L - BOSS Cemented to surface C amco 'KBUG @ 3 1/2"x 1' w/ 2494' MD/TVD and latch dummy 4 � 4 Intermediate Casing 0 o @ , 316 ' MD 5 & 47#, L 80, 9.4 NaCI ppg brine from 5130' WLM (tag) to 2452' WLM BOSS & 40 # L - 80 BTC r 10.7 ppg ASL from 5752' WLM to TOC @ 5130' WLM (Tag) in tbg & annulus 10.0+ NaBr brine from PBTD of 7803' 3-1/2", .3# -- 80, MD/TVD to 5752' WLM D 8 (1) Gas Lift Mandrel @ +/ 5873' MD: Camco 'KBUG' , 3 -1/2" x 1", with Dummy Valve and Latch I Production Casing 7 �� , - 7 ", 6 #, 7891' -80 BT (1) PBR & SAB -3 Packer Assembly @ +l- 5940' MD -jr See Sheet 2 for Packer Assembly and Below Sheet 1 of 2 Puviaq #1 P &A Schematic prepared by TJB 4/21/2011 • • See Sheet 1 for Completion Assembly Above i i 10.0+ NaBr brine from PBTD of 09W.59: 7803' to 5752' WLM j % PBR & SAB -3 Packer Assembly @ +/- 5940' MD/TVD (2) Gas Lift Mandrels: CAMCO 'KBUG', 3 -1/2" x 1 ", with Dummy Valve and Latch @ 6061' & 6118' MD/TVD Production Tubing 3 -1/2 ", 9.3 #, L -80, EUE j j 3'W' Halliburton 'X' nipple with 2.813" ID 8rd Mod % i polished bore w /RHC plug latched in place @6141' MD/TVD Mule Shoe No perforations Tubing Tail set @ 6150' Baker FB -1 Permanent Packer © 6725' MD/ j - ■= TVD ism i (1) Landing Nipple: j Z 3 -1/2" Halliburton 'XN' nipple @ 6743' MD/TVD MIN Tubing Tail set © 6750' No perforations Float Collar @ 7803' MD/TVD 4 i Production Casing @ 7891' MD/TVD (est) 7 ", 26 #, L -80, BTC TJB 4/21/2011 TD 8 -1/2" Hole: Sheet 2 of 2 7900' MD II 0 . , • , .., _ Puviaq #1 cConocoPhillips Alaska, Inc. 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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic [J Service [J 6. Permit to Drill Number: 202 -248 ConocoPhillips Alaska, Inc Development El Exploratory 0 7. Well Name: Puviaq #1 2. Address: 4b. Well Status: Oil [j Gas 0 WAGO 8. API Number: P.O. Box 100360, Anchorage, Alaska 99510 GINJ 0 WINJ 0 WDSPL E3 50- 279 - 20008 -00 5a. Sundry Number: 5b. Sundry approval date: 9. Field: Wildcat Initial Disposal 0 Continuation 0 Final 1151 310 -394 12/9/2010 10 (h)(1) drilling mud, drilling (h)(2) drill rig wash fluids (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids and drill rig domestic waste approved substances (include days Beginning Dates: Ending cement- contaminated drilling water descriptions in block 12) disposal Dates: mud, completion fluids, occurred: formation fluids and any • necessary water added. Previous 9894 0 0 9894 27 03/26/03 04/20/03 Puviaq #1 totals (bbls): 2010/Q4 0 0 0 0 0 2011/Q1 0 0 0 0 0 2011/Q2 185 0 0 185 2 04/13/11 04/14111 Puviaq #1 YYYY /Q# Total 10079 10079 29 Report is due on the 20th Ending Volume of the month following the final month of the quarter. E (bbls): April 20 for the first quarter, July 20 for the second quay 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. - � D ate: ` � 4 Signature: - - Printed Title: Phone Name: Tom Brassfield Senior Drilling Engineer Number: (907) 265 -6377 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate CPAI Puviak #1 2011 Annular Disposal Injection Test and Log FLOW START END Cum BBLS TIME DIF TIME PRESSUR PRESSUR Pumped MW REMARKS Date SPM BPM E E Pumped START STOP (hrs) Vol 04/13/11 1.5 100 250 20 1730 18:30 1.00 20 6.8 diesel used for injectivity test 04/14/11 1.0 200 200 50 10:30 11:30 1.00 70 6.8 freeze diesel 04/14/11 1.0 150 150 58 11:30 12:30 1.00 128 9.0 rinse water /brine • 04/14/11 1.0 150 150 57 12:30 13:30 1.00 185 8.5 brine water /diesel II Page 1 of 2 y • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 13, 2011 4:31 PM To: 'Bill Penrose' Cc: Alexey Sachivichik; Brassfield, Tom J � Subject: RE: PUVIAQ #1 INJECTIVITY TEST e7 - 7 Z� Bill, Based on these rates and pressures the annulus appears to be in good shape for injecting waste fluids. The initial LOT after drilling out the 13 3/8" shoe was 16.4 ppg EMW. I am assuming the heaviest fluid to dispose of will be the 9.5 brine .... The max surface pressure for disposing waste fluids (9.5 ppg) is 400 psi . Please keep injection rate to 1.5 bpm or less. Injectivity for Puviaq #1 300 - -- - -- X60 • 200 • • ' 150 • • Seriesl 100 • 60 0 I 1 1 1 0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 BPrv1 Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bill Penrose [mailto:bill ©solstenxp.com] Sent: Wednesday, April 13, 2011 4:03 PM To: Schwartz, Guy L (DOA) Cc: Alexey Sachivichik; Brassfield, Tom J Subject: PUVIAQ #1 INJECTIVITY TEST 4/14/2011 Page 2 of 2 Guy, Here are the results of the injectivity test conducted today on the Puviaq #19 -5/8" x 13 -3/8" annulus. Diesel (6.8 ppg) was used for the test. Please provide us with rate and pressure limitations for use in disposing of permitted waste liquids. .25 bbl /min = 100psi .5 bbl /min = 150psi .75 bbl /min = 175psi 1 bbl /min = 200psi 1.5bbl /min = 250psi Regards, DC�P Peeit,4e Vice President / Drilling Manager . P 310 K Street, Suite 700 Anchorage, Alaska 99501 Main 907 - 279 -6900 Direct 907 - 264 -6114 Cell 907 - 250 -3113 4/14/2011 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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory IN 7. Well Name: Puviaq 1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 310 -394 12/9/2010 NPRA Exploration 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 9794 100 0 9894 totals (bbls): 2010 / 4th 0 0 0 0 2011 / 1st 0 0 0 0 2011 / 2nd 2011 / 3rd Total Ending Report is due on the 20th Volume 9794 100 0 9894 0 (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): I hereby certify that the foregoing is true and correct to the best of my knowledge. A Loak Signature: Date: 4 1It t (Z-4 k Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • Page l of Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 07, 2011 2 :21 PM To: 'Brassfield, Tom J' Cc: Alvord, Chip; Bill Penrose; Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Modification to Puviaq P &A procedure & Tom Zelenka with BLM (PTD 202 -248) Tom, You have approval to use the modified surface setup as requested below for taking returns ... assuming no wellhead pressure is seen initially on rig up. The chances of encountering any pressure are extremely low as the well was never perforated. Thanks for the heads up on Tom Zelenka possibly leaving early_ We may or may not be able to provide an inspector but as always notify us for witness and take pictures to document the work. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Brassfield, Tom J [mailto:TOM.J .Brassfield @conocophillips.com] Sent: Thursday, April 07, 2011 1 :46 PM To: Schwartz, Guy L (DOA) Cc: Alvord, Chip; Bill Penrose Subject: Modification to Puviaq P&A procedure & Tom Zelenka with BLM Guy, per our telephone conversation today; CPAI requests the following procedural modification to the Puviaq P&A: Since use of a choke manifold to check for and contain potential pressures has proven to be problematic ° due to its complexity, size and propensity for freezing, the following is proposed as the alternative: Instead of using a choke manifold, an additional block valve will be installed outboard of the existing valve on the annulus from which returns are to be taken. The valve will contain a needle valve and pressure gauge. The pressure gauge will be used to check for initial pressure, if any, and the block valve will be used to contain pressure, if any, while taking returns. The modification has been discussed and verbally approved by the BLM's onsite representative Tom Zelenka. Also, Tom Zelenka the onsite BLM representative has notified our CPAI representative that if the US government does not approve an interim budget; he may leave location before the Puviaq P&A (should start tomorrow) is completed. Thanks, Tom Tom Brassfield Staff Drilling Engineer 907/265 -6377 (w) 4/7/2011 Page 2 of 2 907/244 -5684 (c) 907/275 -7352 (pgr) 4/7/2011 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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory El 7. Well Name: Puviaq 1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal 0 or Continuation ❑ or Final ❑ 310 -394 12/9/2010 N PRA Exploration 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 9794 100 0 9894 totals (bbls): +;:. 4 2010 / 4th 0 0 0 0 f. ,I, / x 2011 / 1st ,, " ®,. 1 44, '`moo 2011 / 2nd , ;,,, 2011 / 3rd Total Ending ss..i Report is due on the 20th at Volume 9794 100 0 9894 (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): I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ,/ " tek cc -(,,,. ,,�) Date: f 1 it (Ls t Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 RBDAAS JAN 2:8 201 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • Tr Fc Lc [F LR I 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 Drilling Manager Ot_ Lk ConocoPhillips Alaska, Inc. p� `'� P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Exploration Field, Exploration Pool, Puviaq #1 Sundry Number: 310 -394 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of December, 2010 Encl. • • N ConocoPhillips Box 100360 'r = PC • F ! VE O Alaska 99510 -0360 DEC ; r. 2010 oas ans. Commission November 30, 2010 Anc orage Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry approval for annular disposal Puviaq #1 (Exploratory Test) Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW X= 450,547.8 & Y= 6,105,700.17 ASP5 NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a request to reactivate the annular disposal approval for the Puviaq #1 wellbore in the National Petroleum Reserve - Alaska. This request is being made to support the P&A efforts in 2011. Nabors 16E spud the well on 3/8/2003 and the rig was released on 4/15/2003. The attached Sundry form 10 -403AD is being submitted with the requested information. The original approved annular disposal sundry is also attached. If you have any questions or require any further information, please contact me at 265 -6377 or Chip Alvord at 265 -6120. S' cere U1'Xi r / 0 Tom Brassfield Senior Drilling ngineer cc: CONFIDENTIAL — Puviaq #1 Well File Chip Alvord ATO -1570 Leslie Senden ATO -1390 STATE OF ALASKA ('' �2 R - FIN/ED ALASKA. AND GAS CONSERVATION COMMISS et DEC' 0 1 2010 v ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ° i, za bas Urns. CommisS100 1. Operator Name: 3. Permit to Drill No: 202 -248 . Anc!wrage ConocoPhillips Alaska, Inc. 4. API Number: 50- 279 - 20008 -00 • 2. Address: 5. Well Name: Puviaq #1 • P.O. Box 100360, Anchorage, AK 99510 -0360 6. Field: NPRA Exploration 7. Publicly recorded wells 8. Stratigraphic description: a) Interval exposed to Previously Submitted a) All wells within one- open annulus: quarter mile: None b) Waste receiving Previously Submitted zone: b) water wells within None one mile: c) Confinement: Previously Submitted 9. Depth to base of 10. Hydrocarbon zones permafrost: above waste receiving plus /minus- 1000' TVD zone: None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: Varied from 6.9 ppg to 10.5 ppg 9894 bbls from 3/26- 4/20/2003 approx. 1210 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: <2000 bbls Diesel, brine, cement, wash -up fluids 16. Estimated start date: 15- Mar -11 17. Attachments: Well Schematic (Include MD and TVD) ❑ Cement Bond Log (if required) ❑ FIT Records w/ LOT Graph ❑ Surf. Casing Cementing Data ❑ Other El data submitted with original sundry for annular disposal — Re- iss. ' ( 3o3 - /ot) 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: �� tom. Cis.- Title: Drilling Manager Printed Phone / Name: Chip Alvord Number: 265 -6120 Date: ( ' Lo to Commission Use Only Conditions of approval: S J � . , re 4 � �J LOT review and ©A approval: /Z• No Subsequent form `` Approval required: /� � number: '�� Approved APPROVED BY 2 by: ' COMMISSIONER THE COMMISSION Date: RBLiiAv DEC 1 0101 / ORIGINAL ,Z.v.„ Form 10 -403AD Rev.6 /2004 INSTRUCTIONS ON REVERSE Submit in Duplicate • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re -enter suspended well _ Other _X Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ . Annular Disposal Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development_ 30' RKB +28' MSL feet 3. Address Exploratory _X 7. Unit or Property name P. O. Box 100360 Stratigraphic _ Anchorage, AK 99510 -0360 Service_ Exploration NPRA 4. Location of well at surface 8. Well number 1713' FNL, 444' FWL Sec. 35, T16N - R1OW, UM Puviaq #1 At top of productive interval 9. Permit number / approval number 1713' FNL, 444' FWL, Sec. 35, T16N - R1OW, UM 202 - 248 At effective depth 10. API number 50- 279 - 20008 -00 At total depth 11. Field / Pool 1713' FNL, 444' FWL, Sec 35, T16N - R1OW, UM Exploration 12. Present well condition summary Total depth: measured approx 4000' feet Plugs (measured) true vertical approx 4000' feet Effective depth: measured as above feet Junk (measured) true vertical as above feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 82' 20" 315 sx AS1 112' 112' Surface 1393' 13 3/8" 184 sx ASLITE + 296sx AS1 1423' 1423' Intermediate 3137' 9 5/8" 231 sx CI ^G" + additives 3167' 3167' Perforation depth: measured NA true vertical NA RECEIVED Tubing (size, grade, and measured depth MAR 2 6 2003 No tubing as of 3/26/03 Alaska & $ Packers & SSSV (type & measured depth) mil NA AnCitOrige 13. Attachments Description summary of proposal _X Detailed operations program _X BOP sketch _ I 14. Estimated date for commencing operation 15. Status of well classification as: March 26, 2003 16. If proposal was verbally approved Oil _ Gas _ Suspended _ \144/4' 3/ 2.4/1-00 Name of approver Da a approved Service _Being Drilled 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Brass field 265 -6377 Signed Title: Drilling Team Leader Date c3 / 2612 00 3 P au l M aao li n i TJB FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no Plug integrity _ BOP Test _ Location clearance _ "i ,'°t / OD Mechanical Integrity Test _ Subse • uent form required 10- 13 ` itch p►Hest PLt 4r,.t: 1-€ d tag fr? f f s“L ► ^ (- . Approved by order of the Commission / 4 Jr - Commissioner Date e)3 /G ‘/O3 Form 10 -403 Rev 06/15/88 • IJLJPLI CaJE - SUBMIT IN TRIPLICATE • • Note to File Puviaq 1 (PTD 2022480) (Confidential) December 7, 2010 Re: ConocoPhillips' Application for Sundry Approval for Additional Annular Disposal of Drilling Wastes within Well Puviaq 1 Request ConocoPhillips requests approval to resume disposal of waste fluids generated through drilling operations by injection into the annulus of well Puviaq No. 1 (Puviaq 1) to a volume limit of 35,000 barrels. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 13 -3/8" surface casing shoe is set in this well at 1,423' measured depth (- 1,393' true vertical depth subsea, or "TVDSS "), at the top of a 70 -foot thick interval dominated by shale and claystone. 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 this well to accept the proposed amounts of waste fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the intended disposal strata. 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 about 100 feet from the wellbore. Discussion CPAI's application was reviewed along with well records from Puviaq 1. These nearest well is Aklaq 6, which is located 5 miles to the west - northwest. The discussion that follows is based on well records, logs and the mud log from Puviaq 1. An index map is provided, below. The most likely injection strata in this well are assigned to the Nanushuk formation, and they lie within Section 35, T16N, R1OW, UM, which is located in the NPR -A. The 13 -3/8" surface casing shoe of Puviaq 1 lies at 1,423' measured depth (- 1,393' TVDSS), at the top of a 70 -foot thick interval that is dominated by claystone and shale and is likely continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for continued disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 9 -5/8" casing string, which is estimated to lie at about 2,667' measured depth (- 2,637' TVDSS). The most likely portion of the open annulus that will accept injected waste are several 1- to 6 -1/2 foot thick beds of silty sandstone and sandstone that lie between about 1,440' and 1,586' measured depth (- 1,382' and - 1,526' TVDSS), which is just below the surface casing shoe. The aggregate true vertical thickness of these thin receiving strata is about 23'. The receiving strata are separated by shale and claystone intervals. Beneath the strata is a 20' thick interval of shale and claystone Puviaq No.1 • • Increased Injection Volume Application December 7, 2010 Note to File Page 2 of 4 Confidential • that is likely continuous throughout the area. This interval, which lies between about 1,675' and 1,695' measured depth (- 1,645' and - 1,665' TVDSS), will provide lower confinement for any injected wastes. p o " 4 .n � a Aklaq 6 • Puviaq 1 • Proposed Disposal Operation Figure 1. Index Map In the vicinity of Puviaq 1, the base of permafrost is interpreted at about 1,195' measured depth (- 1,138' TVDSS), which is about 225' above the top of the most likely disposal injection strata. The shallow geologic section in the Puviaq 1 well contains methane gas. Records indicate that traces of methane were first measured at 200' measured depth ( -143' TVDSS). The more significant amounts of methane (arbitrarily placed at 20 units of gas on the mudlog) were encountered in the well at 550' measured depth ( -493' TVDSS). So, the most likely injection strata contain some methane gas. Supporting documentation to ConocoPhillips' annular disposal applications states: "No aquifers." This is correct. Log analysis calculations that are compliant with EPA guidance document (Survey of Methods to Determine Total Dissolved Solids Concentrations," KEDA Project No. 30 -956, Revised September 1989) indicate formation water salinities exceed 20,000 ppm total dissolved solids from the base of permafrost through the most likely disposal strata. Puviaq No.1 • • Increased Injection Volume Application December 7, 2010 Note to File Page 3 of 4 Confidential Correlation Depth Resis Porosity SP(N /A) <MD ResD(SEDP) RHOB(BD) -200 100 0.2 OHMM 200`1.65 G/CC 2.65 RHOB(BD) T` Ci ResS(SESP) ow Poro 1.8 G/CC 1.85 0.2 OHMM 200 NPOR Ell 60 0 GR <MD DTCP -10 API 240 140 US/FT 40 anti - Silt - Shale 1440 ---- 1 -1420 -' 1460 -1440 4.....„ 1480 r -1460 1500 1500 -1480 1520 i r -1500 \. 1540 ? -1520 1560 1540 - 1580 1560 1600 1600 . } . ,.? -1580 _ 1620 L -1600 "L,___ -.., 7 1 - ____ 1640 .�.� -1620 i 1660 t Y -1640 1680 -1660 c .-------- C— 1 700 1700 t� -1680 J .. --- te. , 1720 Figure 2. Most Likely Disposal Injection Strata Puviaq No.1 • • Increased Injection Volume Application December 7, 2010 Note to File Page 4 of 4 Confidential The shallowest oil indicators observed in Puviaq 1 occur at 5,940' measured depth (- 5,910' TVDSS), which is more than 4,200 true vertical feet below the most likely disposal strata. Injected Fluid vs Affected Radial Distance Puviaq 1 Wellbore (assumes 23' aggregate injection zone thickness and 28% porosity) 300 - 250 .0 200 E 0 w d U = 150 N_ 0 100 . • • • • N U d 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 3. Estimated Affected Area (Radial Distance in Feet from the Puviaq 1 Wellbore) The chart above provides an estimate of the affected area surrounding Puviaq 1. Well logs recorded in Puviaq 1 indicate about 23' of net sandstone and silty sandstone are present in the most likely disposal strata. Inspection of the neutron and density porosity logs suggests an average sand and siltstone porosity of 28% at this depth. Based on these values, the area most strongly impacted by the proposed additional annular injection activities will be limited to a radius of about 100 feet from the wellbore. The limited volume of rock that will be affected by this proposed additional disposal injection program contains methane gas, is situated beneath about 1,200' 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. The area that will be affected by this proposed additional injection operation lies inside CPAPAPC/Pioneer's lease holdings, more than 2 miles from a boundary denoting a change in ownership, so correlative rights will not be a concern. 1 reco -nd approval of this continued annular disposal operation to a volume limit of 35,000 barrels. OW 1 � Steve II avt - .Ca.c� c i JI Senior Petroleum Geologist Go.t. at j Lw A /b o • /' /2 /74 ) ur l,;6� Go 1 ,`7 d . 6 'e} "` r I 1 p,,, ,F 0, ( 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 Drilling Manager a0)-v aLt ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Exploratory Field, Exploratory Pool, Puviaq #1 Sundry Number: 310 -392 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair ,, DATED this 2 day of November, 2010. Encl. Page 1 of 2 • Schwartz, Guy L (DOA) From: Brassfield, Tom J [TOM.J .Brassfield @conocophillips.com] Sent: Tuesday, November 30, 2010 7:13 AM To: Schwartz, Guy L (DOA) Subject: RE: Puviaq #1 (PTD 202 -248) Guy, we can do! Thanks for the quick reply! Tom From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, November 29, 2010 4:45 PM To: Brassfield, Tom J Subject: RE: Puviaq #1 (PTD 202 -248) Tom, Looked at the procedure too. A couple of comments: 1) Before you get going might be good to also recheck the integrity of the tubing and IA. (A PT of 1500 psi would be ok). Could do this at step 3 or just before you do the injectivity test on the 9 5/8" X 13 3/8 ". 2) Tag the first cement Plug ( depth of 5300' md) just before punching the upper set of holes at 2450' and as per 20 AAC 25.112 (g)(1). This would be at step 12 or 13. That's all I could see... Call me if you have any questions on the 10-403 AD permit. The new form is on the website. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Monday, November 29, 2010 3:32 PM To: 'Brassfield, Tom Y Subject: Puviaq #1 (PTD 202 -248) Tom, In order to reactivate the Annular disposal on Puvaiq #1 a 10 -403AD form will need to be submitted. We have the supporting documentation from the original permit but since it has been inactive so long a new 10 -403AD will be required. You don't need to resend all the supporting information but any new info and total pumped into the AD ( See Box 11) . A injectivity test will be required before disposal operations can start. Regards, Guy Schwartz Senior Petroleum Engineer 11/30/2010 • • 1Piv • ConocoPhi l lips Box 100360 RECEIVED Alaska 99510 -0360 NOV 2 9 2010 November 19, 2010 atte r Ga : Cons. d crorn'�s+or� Anchorage Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry approval to P&A Puviaq #1 (Exploratory Test) Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW X= 450,547.8 & Y= 6,105,700.17 ASP5 NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a request to permanently plug and abandon the Puviaq #1 wellbore in the National Petroleum Reserve - Alaska. Nabors 16E spud the well on 3/8/2003 and the rig was released on 4/15/2003. Please note the following: • The wellbore is not perforated • Kill weight fluid in the tubing and the tubing by 7" annulus to 1510' MD/TVD with diesel from 1510' MD/TVD to surface. • Freeze protect diesel in both the 7 "x9 -5/8" annulus and the 9- 5/8 "x13- 5/8" annulus • Cement to surface on the 13 -3/8" casing • BPV installed in the tubing hanger. The attached Sundry form 10 -403 and back -up information describes the proposed P&A procedure for the existing wellbore and will be discussed with BLM personnel. We will also need to re- activate the 13 -3/8 " x 9 -5/8 " the 1 - m annular injection permit to dispose of onsite fluids as approved in 20 AAC 25.080. Current volume injected to date Is slightly less than 10,000 bbls of fluid with an additional 2,000 bbls maximum anticipated during the P&A. If you have any questions or require any further information, please contact me at 265 -6377 or Chip Alvord at 265 -6120. • • J Sincere z...e it" '11// Tom Brassfield Senior Drilling Engineer cc: CONFIDENTIAL — Puviaq #1 Well File Chip Alvord ATO -1570 Leslie Senden ATO -1390 STATE OF ALASKA • tig I 1 10 ALASKA OIL AND GAS CONSERVATION COMMISSION V ''� 56 e APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon in . Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory p • 202 -248 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50- 279 - 2008 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 15 Puviaq #1 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL AA0818541L32589 Exploratory ' 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): 7900' 7900' 6141' 6141' na na Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 112' 112' na na Surface 1393' 13.375" 1423' 1423' 5380 psi 1661 psi Intermediate 3137' 9.625" 3167' 3167' 5750 psi 3090 psi Production 7861' 7" 7891' 7891' 7240 psi 5410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" L -80 6150' Packers and SSSV Type: no SSSV Packers and SSSV MD (ft) and TVD (ft): FB -1 & SAB -3 packers 6725', 5940' no SSSV 12. Attachments: Description Summary of Proposal in 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p + Development ❑ Service ❑ 14. Estimated Date for 1- Mar -11 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned r Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield@ 265 -6377 Printed Name Chip Alvord Title Drilling Manager Signature Phone 265 -6120 Date z_0,,,_ ti(Z. --(Z0t • COMMISSION USE ONLY I Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 310 - 5q D. Plug Integrity 111 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ A r Ato � } Other: A i{- er^nr��- r luj, C l C�« r n� fL � �l.L ,Qn 2 • i rr'`- i / NOV 2 9 2010 ,/ aS u',3if & Gay Cans. Com siola L Subsequent Form Required: / / 07 p "� ' ti t. APPROVED BY Approved by r' "* 1 COMMISSIONER THE COMMISSION Date: ! // O / - S D 0 1 1010 if --/-3. /� 4 '�, � G RIGIN Form 10 -403 Revised 1/2010 A L 2,4_///394 SubFnit in Duplicate 0.,/,0 ( • ( • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re -enter suspended well _ Other _X Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ . Annular Disposal Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development _ 30' RKB +28' MSL feet 3. Address Exploratory _X 7. Unit or Property name P. O. Box 100360 Stratigraphic _ Anchorage, AK 99510 -0360 Service _ Exploration NPRA 4. Location of well at surface 8. Well number 1713' FNL, 444' FWL Sec. 35, T16N - R1OW, UM Puviaq #1 At top of productive interval 9. Permit number / approval number 1713' FNL, 444' FWL, Sec. 35, T16N - R1OW, UM 202 - 248 At effective depth 10. API number 50- 279 - 20008 -00 At total depth 11. Field / Pool 1713' FNL, 444' FWL, Sec 35, T16N - R1OW, UM Exploration 12. Present well condition summary Total depth: measured approx 4000' feet Plugs (measured) true vertical approx 4000' feet Effective depth: measured as above feet Junk (measured) true vertical as above feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 82' 20" 315 sx AS1 112' 112' Surface 1393' 13 3/8" 184 sx ASLITE + 296sx ASI 1423' 1423' Intermediate 3137' 9 5/8" 231 sx CI ^G" + additives 3167' 3167' Perforation depth: measured NA true vertical NA RECEIVED Tubing (size, grade, and measured depth MAR 2 6 2003 No tubing as of 3/26/03 Packers & SSSV (type & measured depth) Il NA Ane 13. Attachments Description summary of proposal _X Detailed operations program _X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: March 26, 2003 16. If proposal was verbally approved Oil _ Gas _ Suspended 3i ite 11-00S Name p am approver Date approved Service _Being Drilled 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265 - 6377 1 Signed Title: Drilling Team Leader Date G3 / r 6 /2 P au l M aao li n i TJB FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no Plug integrity _ BOP Test _ Location clearance _ , j �, F j OD ff r/ Mechanical Integrity Test _ r Subsequent form required 10- Ll- �{ ze7 r.�+L 1L1Q p bessu 4,4(.' -Fe J /. iz a ' 114�SLGY't- . Approved by order of the Commission � Commissioner Date e;'34‘/..3 \ < Form 10 -403 Rev 06/15/88 • D SUBMIT IN TRIPLICATE • • P &A Procedure: Puviaq #1 Revised 11/18/10 Prepare Puviaq #1 for Annular Disposal of Wastes NOTE: Notify AOGCC/BLM Inspectors before starting work. Discussion: Prior to commencing injection of Class II wastes, the AOGCC must re- activate the original Annular Disposal Permit issued for this well if the primary term of the permit has expired. As a prerequisite for re- activation of the permit, a step -rate injectivity test must be performed so that the State or Federal agency representative on site can determine the maximum injection rate and pressure allowable. The following is the procedure for the step -rate test. Considerations: A minimum of three, and ordinarily a maximum of five, rate - and - pressure -pair points are required. The stabilized rate and pressure are always included as the first point. At least three points are needed to reveal the character of a curve. Five points are usually enough to ensure that a large enough rate change exists between points to emphasize any water hammer effects that might be present. Procedure: 1. R/U diesel tank and pumping equipment to pump down the 9 -5/8" x 13 -3/8" annulus. 2. Pressure test surface lines to 2,000 psi. 3. Pumping diesel, conduct a four -point injectivity test down the annulus as follows: a) Establish minimum pump rate and gradually increase it to 0.5 bpm and hold until pressure stabilizes. b) Record first rate and pressure pair. c) Increase the pump rate in 0.5 bpm increments (check for changes in the slope of the pressure curve at stable rates). d) Plot pair points on a pressure- versus -rate graph and determine fracture extension pressure. 4. Forward the data to the Anchorage office for discussion with AOGCC representatives in town if one is not available on site. P &A Puviaq #1 1. MIRU camp and equipment. Do not commence well operations until camp operations have been established, personnel are settled in and all equipment and materials required for this job are onsite. TJB & WJP 11/18/10 • • 2. Rig up a testing manifold containing two adjustable chokes arranged in parallel. All bleeding off of well pressures and returns taken while pumping should be taken from the well, through the manifold and into appropriate tanks for the liquid being flowed. 3. Check all annuli for pressure. If any is found, document pressure and attempt to bleed off through the choke manifold. If it does not bleed off or if it re- builds, contact Anchorage office for an alternative plan. _ ?T 4, !, I A h ism p s 4. Rig up pressure control equipment to punch tubing above GLM #2. 5. MU a tubing punch, RIH and punch tubing at 5,850' (just above GLM #2). POH and RD. 6. Rig up pump and lines for pumping brine in the well. Pressure test lines to 1,000 psi. 7. Heat water and mix 60 bbls of 9.4 ppg NaC1 brine. 8. Establish circulation. Reverse out and recover 1,400' of diesel from the tubing (approx. 12 bbls). 9. Switch lines at the surface and pump brine down 3 -1/2" tubing until all diesel is displaced from the 3.5" x 7" annulus and returns are clean brine (calculated volume of diesel in the annulus is 37 bbls). 10. Mix 17 bbls of permafrost cement (to obtain 500 ft of cement plug) as: Density 10.70 ppg . e � � /..; x _ /7 da'c Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump the cement plug down the 3.5" tubing and displace with 46 bbl of brine until -r cement covers 500 ft of the annulus and 500' inside the tubing. Recover brine for re -use. 11. When the pump is shut down, immediately shut the annulus valve (to inhibit falling of the cement column) and disconnect cementing line. 12. Rig pressure control equipment to punch tubing baove GLM #1. - I . Ce t" 5 3�U✓ M 13. Punch holes in the tubing at 2,450'. Release unit from the project as soon as circulation through or above the GLM is established. 14. Mix 100 bbls of permafrost cement as: Density 10.70 ppg 3 s dg / Yield 4.51 cu ft/sk s l eg � � .ems Mix Water 21.316 gal /sk TJB & WJP 11/18/10 • • c t %` Pump the cement plug down the 3.5" tubing until cement returns are seen at surface. rface. 15. When the pump is shut down, immediately shut the annulus valve (to inhibit falling of the cement column) and disconnect cementing line. 16. Rig up pump and lines to bullhead down the 7" x 9 -5/8" annulus. Pressure test lines to 3,800 psi. 17. Heat all of recovered brine and use NaC1 to weight up to 9.4 ppg. Pumping brine down the 7" x 9 -5/8" annulus, establish a breakdown pressure and injection rate at a pressure not exceeding 3,800 psi (70% of the collapse rating of the 7" casing). Pump all brine away to chase diesel out of annulus ahead of cement. 18. Mix 74 bbls of permafrost cement (calculated annular volume to the 9 -5/8" shoe is 74 bbls): �3 Density 10.70 ppg • c z� 6a; 1 P ( Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump cement down the 7" x 9 -5/8" annulus to fill the 7" x 9 -5/8" annulus to the 9 -5/8" shoe at 3,167'. 19. When the pump is shut down, immediately shut the annulus valve (to inhibit falling of the cement column) and disconnect cementing line. 20. Rig up pump and lines to bullhead recovered fluids down the 9 -5/8" x 13 -3/8" annulus. Pressure test lines to 3,800 psi. 21. Pump remaining diesel recovered from the previous steps down the annulus followed by remaining brine. Then pump 82 bbls of permafrost cement (calculated annular volume to the 13 -3/8" shoe is 82 bbl): Density 10.70 ppg f(,,,, 1 Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump cement down the 9 -5/8" x 13 -3/8" annulus to fill the 9 -5/8" x 13 -3/8" annulus to the 13 -3/8" shoe set at 1,423'. 22. When the pump is shut down, immediately shut the annulus valve (to inhibit falling of the cement column) and disconnect cementing line. 23. Clear and clean lines and cementing equipment. 24. WOC at least 12 hours. TJB & WJP 11/18/10 • • 25. Meanwhile, rig down all mixing, pumping and related equipment and prepare them for moving to the FEX project. 26. Using excavator, excavate around the wellhead to a depth of five feet below tundra level. 27. After WOC period is finished and using a cutting torch and hydraulic jack hammer (for cement), cut all casing and tubing strings off to leave well severed 4' — 5' below tundra level. 28. Remove original guardrail, cellar, wellhead and severed casing /tubing and prepare for transport to Prudhoe Bay. 29. Top off all annuli and tubing in well with cement if necessary. BLM or AOGCC representative to witness. 30. Photographically document the condition of the top of the well before welding on the marker plate. 31. Weld a 1 /4" thick, 20" diameter steel marker plate over the top of the cut -off well casings. BLM or AOGCC representative to witness. Marker plate to have the following information bead - welded onto it: ConocoPhillips Co. Puviaq #1 API #50- 279 - 20008 -00 PTD #202 -248 32. Photographically document the welded -on marker plate. 33. Back -fill excavation with five yards of clean gravel brought out from Prudhoe Bay. Top excavation with original soil, mounding it over the well to compensate for settling as soil thaws. 34. Clean location, obtain site clearance approval from BLM or AOGCC representative on location and prepare all personnel, equipment and materials for demobilization. TJB & WJP 11/18/10 _• • • Puviaq #1, Network #10028348 Completion Schematic, S heet 1 of 2 Exploration Well - CONFIDENTIAL Nabors 16E RKB (1) Tubi ng Hanger with BPV installed: FMC Gen V Elevation: 28:2' / '0' / / /\ ' � \ '` : ` 20" Conductor ) / \ ) \ ) / \ A 112 MD d / � 4 141' Surface Casing q) ( (/ ( ) LmmngN¢MeA49 MD: 13&37 #D m D ) ( ®» — �) \ Camco 9-c 'DS' nipple w/ ±873 No-Go pal %e . \ , t / i �� � Camc 8"B Mandrel g2 /� � d mmyand � atch TOC behind g &8 cgest A / Z / z 2667' MD /TVD / / �/ / 9-5/8" x7 annulus FP with diesel to 1383' ) $ ) / M D% VD / \ 13-3/8" w "x9-5/8" v O/ annulus + Intermediate Casing nnulusFP with diesel 1400' @ 3167' MD / 3167' VD / ) 9 &47#, L±% / A / 1EO +Na+ppg brine from Dy 7803' BOSS &40 #wBOBTC ) 1510' \ \ uace \ ± \ &7 " \— diesel nn us 43 4 7 ' 6 ) 7 A©j \ \ . Production Tubing T Ce#mme G� of MD 312', 9.3#, y8,EUE ~ - 8RD Mod ; :- 1 Cam 'K UG',3 g 8", A Dummy Vmv and / 1 $ o #1 L %h / § 1Jba § f,0 6 i . - de ) \ t. � & Jfco' AA - 1)) ammo \ \ Production rawrixa \ mum! [ 2 # 8 7", L-80 B C Mod \ r _ ) (1) PBR & SAB-3 Packer Assembly @ +z 5940' MD � \ ) ■0 aia ( See Sheet 2 for Packer Assembly and Below Sheet 1 of 2 n • • See Sheet 1 for Completion Assembly Above 10.0+ Naar brine from PBTD of 7803' from 1 to MD/TVD & diesel � �' PBR & SAB -3 Packer ,�,. } #..,,,,�, ✓ Assembly ,.— —,;f @ +!- 5940' MD /TVD A te' . "" ' • (2) Gas Lift Mandrels: 0 Valve L @ 6061 & 6118' MD /TVD Production Tubing g 0 ,. 3 -1/2 ", 9.3 #, L -80, EUE e 0 3 -/z Halliburton 'X' nipple with 2.813" ID 8rd Mod ° ` polished bore w /RHC plug latched in O 0" place @6141' MD /TVD g • Tubing Tail set No perforations g @ 6150' 0 el PI • Ba ker FB -1 Permanent Packer @ 6725' MD/ ; ` a,° ., TVD = (1) Landing Nipple: P 3 -1/2" Halliburton `XN' nipple @ 6743' MD/TVD - Tubing Tail set @ 6750' No perforations 0 0 0 Float Collar @ 7803' MD /TVD « t 4` >'' Production Casing r; < >= A �_r 0 @ 7891' MD /TVD (est). 7 ", 26 #, L -80, BTC .: <.rvN TD 8 -1/2" Hole: Sheet 2 of 2 7900' MD 1 SINEE [11[F [IAEA 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 October 11, 2010 Ms. Betty Schorr Program Manager, Industry Preparedness Program Division of Spill Prevention and Response Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 -2617 Re: Permanent Abandonment of ConocoPhillips Alaska, Inc. Operated Well Puviaq 1 Dear Ms. Schorr: On September 24, 2010, ConocoPhillips Alaska, Inc. (CPAI) requested the Alaska Oil and Gas Conservation Commission (Commission) provide a letter to the Alaska Department of Environmental Conservation (ADEC) to verify 1) the inability of hydrocarbons to flow unassisted to the surface from the suspended Puviaq No. 1 (Puviaq 1) wellbore, 2) to verify that abandonment activities will not change that status, and to recommend a zero barrel per day spill response planning standard for routine abandonment operations carried out in compliance with Commission regulations. Puviaq 1 is a suspended well lined with properly- cemented, unperforated casing, plugged with cement, and filled with kill - weight fluid. Puviaq 1 was successfully pressure tested prior to release of the drilling rig. The Commission does not believe this well is capable of flowing. Regulation 20 AAC 25.110 establishes criteria that must be met in order for a well to be classified as suspended. This regulation requires, among other things, that the well: • is mechanically sound, • will not allow the migration of fluids, and • is secure, safe, and not a threat to public health. Based on inspection and review of records for the Puviaq 1 well, the Commission determined that it could properly be classified as suspended and therefore incapable of flowing hydrocarbons to the surface. Nothing in CPAI's proposed abandonment activities will alter this status. If ADEC requires a revised SRPS to conduct (90a- —acter • 1 abandonment operations on this properly- suspended well, the Commission recommends that it be set at zero barrels per day. Should you have any questions please contact Commissioner Cathy Foerster at 793 -1221. Sincerely, Dan T. Seamount, Jr. Chair, Commissioner cc: Tom Brassfield, CPAI • • `10-v • • ConocoPhillips Box 100360 Alaska 99510 -0360 i, A; .� SEP 2 4 2.010 September 24, 2010 AtziAlikiitot4ra.Crititnion Commissioner Mc ' State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Confirmation of Status and Recommendation for SRPS Puviaq #1 (Exploratory Test) Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW X= 450,547.8 & Y= 6,105,700.17 ASP5 NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R1OW Dear Commissioner: ConocoPhillips Alaska, Inc. (CPAI) may, upon receipt of all necessary permits and approvals, permanently plug and abandon the Puviaq wellbore in the NPRA during the 2010/2011 Winter season. The Puviaq welibore is currently approved as and classified by the AOGCC as a "suspended" welibore (See attached approved Sundry). The Puviaq wellbore has never been perforated and is incapable of flowing hydrocarbons to the surface in its current state. The activities that would take place in the Puviaq wellbore to abandon it pursuant to Commission requirements would not involve any activity that might change that status. As part of the initial permitting process for abandonment, CPAI requests that the Commission provide to the Alaska Department of Environmental Conservation a letter confirming the inability of hydrocarbons to flow to surface from this welibore and that abandonment activities would not change that status, and a recommendation for a zero barrel per day SRPS that should be applied for routine abandonment operations carried out in compliance with AOGCC regulations on a suspended wellbore such as the Puviaq wellbore. Please call me if further information is needed. incer- Tom Brassfield Senior Drilling Engineer cc: CONFIDENTIAL — Puviaq #1 Well File Chip Alvord ATO -1570 • SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 900 CONSERVATION COD`IMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. C. Alvord Alpine Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 10036Q Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, Puviaq 1 Sundry Number: 309 -310 Dear Mr. Alvord: 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, 1 ''mod Daniel T. Seamount, Jr. Chair DATED this day of September, 2009 Encl. • • RsEE"CF, 0 2 2009 Alaska Oil 81 bas Colts, Crfrnmissian Afrf:l `t¢ k-t ConocoPhillips Box 100360 Alaska 99510 -0360 September 1, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of suspension status 10-403 Sundry Puviaq #1 (Exploratory Test) Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W X= 450,547.8 & Y= 6,105,700.17 ASP5 NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a request for renewal of suspension status for the Puviaq #1 wellbore per 20 AAC 25.110. The well was visually inspected on 8/20/09 and the results submitted with a 10 -404 sundry. Attached is a wellbore schematic noting the condition of the wellbore. Please note the following: • The wellbore is not perforated • Kill weight fluid in the tubing and the tubing by 7" annulus to 1510' MD/TVD with diesel from 1510' MD/TVD to surface. • Freeze protect diesel in both the 7 "x9 -5/8" annulus and the 9- 5/8 "x13- 5/8" annulus • Cement to surface on the 13 -3/8" casing • BPV installed in the tubing hanger. CPA' requests renewal of the suspension because the well is being held for purposes of testing to assess reservoir productivity, prior to expiration of the extended lease term (August 31, 2019). Si erel Tom ,ass ield Senior Drilling Engi - er 0 • . RECEIVED STATE OF ALASKA SEP 0 ?0B9 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & b Om, (; milin a tis ion APPLICATION FOR SUNDRY APPROVAL 7ltr :hoc:in 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other in Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ extension of suspension Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory In 202 -248 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 279 - 20008 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Spacing Exception Requires? Yes ❑ No IN Puviaq 1 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL AA081854 / L32589 RKB 30', 28' MSL Exploratory 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7900' 7900' 6141' 6141' Casing Length Size MD TVD Burst Collapse Conductor 82' 20" 112' 112' Surface 1393' 13.375" 1423' 1423' Intermediate 3137' 9.625" 3167' 3167' Production 7861' 7" 7891' 7891' Perforation Depth MD (ft):. Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" _ L - 6150' Packers and SSSV Type: Packers and SSSV MD (ft) F8 - 1 and SAB - 3 pkrs @ 6725', 5940' no SSSV no SSSV 13. Attachments: Description Summary of Proposal in 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p Development ❑ Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operatb September 10, 2009 011 ❑ Gas ❑ Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: suspended 0 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield @ 265 -6377 Printed Na a Chip Alvord Title: Drilling Manager i Signature f'Yw/ J � �1 ..),1 jJi4A///4 . ,1 Phone 265 -6120 Date e 0/5 �( / Commission Use Only Sundry Nu er: r ✓�� Conditions of approval: otify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: c 7 /7 M / �+ APPROVED BY A. •roved by al � ; N •MMISSIONER THE COMMISSION Date: • • Puviaq #1, Network #10028348 Completion Schematic, Sheet 1 of 2 Exploration Well - CONFIDENTIAL Nabors 16E RKB @ 30' (1) Tubing Hanger with BPV installed: FMC Gen V Elevation: 28.2' GL' % 0 0 % BPMSL � 1 @112'MD Surface Casin j j (1) Landing Nipple @ 499' MD: 1423'MD/ VD f < -- Camco'DS' nipple w/ 2.875" No -Go Profile 13 - 3/8" 72 # L 80 BOSS / / 1 „ (1) Gas Lift Mandrel @ + / - 2494' MD /TVD TOC b 26 est @ K6 FP with 2667' t 1 83' w dummy and latch 67' MD /TVD 9 -5/8" x 7" annulus 1 11 MD/TVD Intermediate / 3167' nVD 13 -3/8 x to 1400' MD //TVDP with diesel 9 53.5 & 47#, L 10.0+ NaBr ppg brine from PBTD BOSS & 40 # L - BTC 0 r MD/TVD to 1510' MD/TVD & disel from 1510' to surface in tbg & 7 "x 3 - annulus i TOC estimated at 5300' MD Tubing Production 3-1/2", 9.3 #, L-80, EUE j 8RD Mod (1) Gas Lift Mandrel @ +l- 5873' MD: Camco 'KBUG' , 3 -1/2" x 1 ", with Dummy Valve and Latch Production Casing. @ 7891' MDITVD 7 ", 26 #, L -80 BTC -Mod r (1) PBR & SAB -3 Packer Assembly @ +1- 5940' MD 4.1111 0%; • siiip See Sheet 2 for Packer Assembly and Below Sheet 1 of 2 • • See Sheet 1 for Completion Assembly Above 10.0+ NaBr brine from PBTD of , 7803' from 1510' MD/TVD torfa &e diesel % rii „ %ii` % PBR & SAB -3 Packer Assembly ” 5940' MD/TVD (2) Gas Lift Valve CAMCO and 3-1/2" n r 6061' & 6118' MD/TVD i n h@ Tubing Production 3-1/2", 9.3#, L-80, EUE ■ 3-W Halliburton'X' nipple with 2.813" ID 8rd Mod i polished bore w /RHC plug latched in place @6141' MD /TVD Mule Shoe No perforations % Tubing Tail set @ 6150' r 0 , Baker FB - 1 Permanent Packer @ 6725' MD/ r - � (1) Landing Nipple: i w i 3-1/2" Halliburton `XN' nipple @ 6743' MD/TVD Tubing Tail set @ 6750' No perforations Float Collar @ 7803' MD /TVD Production Casing @ 7891' MD/TVD (est) 7 ", 26 #, L -80, BTC TD 8 -112" Hole: Sheet 2 of 2 7900' MD • • pr,,ML if 11 I -Y` \'` ); ! 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 Mr. C. Alvord Alpine Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Exploratory, Puviaq 1 Sundry Number: 309 -310 Dear Mr. Alvord: The Commission has corrected the field and pool in the above referenced sundry. Please note the conditions of approval set out in the previously received 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, Daniel T. Seamount, Jr. Chair DATED this c day of September, 2009 Encl. Page 1 of 2 1 Maunder, Thomas E (DOA) From: Brassfield, Tom J [TOM.J.Brassfield @conocophillips.com] Sent: Wednesday, September 16, 2009 7:21 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip Subject: RE: Suspended Well Extensions for CPAI Attachments: 4Spark 1A.jpg Tom, we've attempted to address these issues in the 403/404's submitted on the six NPRA wells inspected this year i,e,: BPV's installed VR plugs installed on the annulus valves D ° ? Tubing tail plugs isolating the intervals of interest Pressure Tests Kill weight fluids in the tubing & IA's Freeze protection at surface Estimated cement tops Good cement returns on the surface casing jobs CPAs has been very pro active for the last three years in performing visual inspections on our remote locations. We have seen no indication of any "safety" issues associated with the six wells submitted. It is not very practical to pull the VR plugs to check annulus pressures- see attached Spark 1A photo as an example. In response to Puviaq's future utility the following statement is made in the Puviaq 10 -403 submittal letter: "CPAI requests renewal of the suspension because the well is being held for purposes of testing to assess reservoir productivity, prior to expiration of the extended lease term (August 31, 2019) ". Regards, Tom From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, September 15, 2009 2:56 PM To: Alvord, Chip; Brassfield, Tom 3; Kanady, Randall B Cc: Aubert, Winton G (DOA); Regg, James B (DOA); Colombie, Jody J (DOA); Schwartz, Guy L (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: Suspended Well Extensions for CPAI Chip, Tom and Randy Sorry you all got missed on the original send. Please share with others in the CPAI organization as needed. Tom Maunder. PE AOGCC From: Schwartz, Guy L (DOA) Sent: Tuesday, September 15, 2009 2 :33 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Aubert, Winton G (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA); Colombie, Jody 3 (DOA) Subject: Suspended Well Extensions for CPAI 9/16/2009 Page 2 of 2 MJ /Perry, In regards to "remote pad" suspended well extensions; two issues came up in our engineering review of the recent wells submitted (Scout land Puviaq 1) and would like addressed in future 403 Sundry applications and the 404 report documentation. 1) At least one annulus pressure should be taken to verify that the well still has integrity. This may mean bringing a calibrated gauge to the remote site and installing it temporarily to get pressures. Commonly, all gauges are taken off and flanges bull- plugged for safety and environmental reasons. The regulations currently say to "get pressures if practical " and that is rather open ended. 2) Remote well -sites need to have a written plan for future utility to qualify for an extension of the suspended status. 20 AAC 25.110 (a) (2) states three possibilities for qualifying for the extension. Written detail for one of these qualifications should be included in the application for sundry. (Scout 1 clearly has a future utility as it will be flow tested but Puviaq 1 did not clearly state any future plans) For the suspended wells on "Active pads" the report should be very similar. As above, getting annulus pressures if at all practical is a necessity. A formal written plan for future utility is not as critical as it meets one of the listed criteria by default. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 9/16/2009 lap /launder, Thomas E (DOA) From: Brassfield, Tom J [ TOM. J.Brassfield @conocophillips.com] Sent: Thursday, September 10, 2009 2 :02 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Regg, James B (DOA); Kanady, Randall B Subject: RE: Remote Exploration Site Inspections -CPAI Attachments: BLM decision Puviaq extension 2009091016221401.pdf Tom, as requested! Tom From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, September 10, 2009 11:52 AM To: Brassfield, Tom 3; Kanady, Randall B Cc: Alvord, Chip; Regg, James B (DOA) Subject: RE: Remote Exploration Site Inspections -CPAI Tom and Randy, With regard to Puviak and Scout, an article about possible NPRA lease expirations on August 31 was carried in Petroleum News edition of August 23. It was also reported that negotiations were underway to extend some of the leases. In the September 6 edition, it was reported that the Moose's Tooth Unit was expanded and the Bear Tooth Unit formed. It was also reported that 43 leases were surrendered. Based on the map in the September 6 article, it appears that the Scout well is contained in the unitized areas. The new map does not show the Puviak area. Was the lease that contains the Puviak well extended to? If you have some documentation regarding the extensions, a copy would be appreciated. Thanks in advance. Tom Maunder, PE AOGCC From: Brassfield, Tom 3 [mailto:TOM.J. Brassfield @conocophillips.com] Sent: Wednesday, August 26, 2009 12:20 PM To: Regg, James B (DOA) Cc; Kanady, Randall B; Alvord, Chip; Maunder, Thomas E (DOA) Subject: RE: Remote Exploration Site Inspections -CPAI Jim, typically we do not leave pressure gauges on the wells (see statement below usually included in our well plans) as a mitigation measure. NO, we did not install gauges and check pressures during these visits. 1. Set BPV in tree. Close all valves and remove handles. Install flanges with /" plugs screwed into the flanges on all outer valves and a bull plug with 1 /2" plug in the valve on the wellhead (annulus valve). Thanks, Tom From: Regg, James B (DOA) [mailto:jim.regg @ alaska.gov] Sent: Wednesday, August 26, 2009 11:13 AM Remote Exploration Site Inspections -CPAI • Page 2 of 4 To: Brassfield, Tom J Cc: Kanady, Randall B; Alvord, Chip; Maunder, Thomas E (DOA) Subject: RE: Remote Exploration Site Inspections -CPAI Do you maintain pressure gauges on the wells, or were gauges installed during visits to check for pressures? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Brassfield, Tom J [mailto:TOM.J.Brassfield @conocophillips.com] Sent: Tuesday, August 25, 2009 2:41 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Kanady, Randall B; Alvord, Chip Subject: RE: Remote Exploration Site Inspections -CPAI Tom, will fill -out the10 -403 or 10 -404 ( ?) forms and forward as required; in the meantime: Rick Overstreet from the Drilling and Wells group and Leslie Senden w/ Environmental inspected the following wells by helicopter on 8/19 & 8/20, landing at each site: Well Name Comments from Inspection/Pictures Wellhead tarp in good shape, some free water around in cellar and Puviaq around wellhead, no sheen. Some distressed vegetation around the cellar. Scout 1 Wellhead tarp in good shape Carbon 1 Wellhead tarp in good shape Mooses Tooth C Wellhead tarp needs repair Spark 1 A Wellhead tarp needs repair Lookout 1 Tree mostly covered, should be re- wrapped next season. Distressed vegetation around the cellar. From a well integrity stand point nothing of note was seen. Generally, all wells were in good condition with the bird covers. Puviaq had some standing surface water in or around the cellar, but this water appeared to be from recent rainstorms and no sheen was noted in any of the areas. Based on field observations, Mooses Tooth C, Spark 1A, and Lookout 1 should have the bird covers replaced. 9/10/2009 Remote Exploration Site Inspects-CPAI Page 3 of 4 • Thanks, Tom From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, August 24, 2009 2:41 PM To: Brassfield, Tom 3; Kanady, Randall B Cc: Regg, James B (DOA) Subject: RE: Remote Exploration Site Inspections -CPAI Tom and Randy, Were you able to accomplish the inspections as planned? Can you provide a summary? Thanks in advance, Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Monday, August 10, 2009 3:38 PM To: Brassfield, Tom J; DOA AOGCC Prudhoe Bay Cc: Alvord, Chip; Kanady, Randall B; NS Env Studies Coord; Senden, Leslie; Maunder, Thomas E (DOA) Subject: RE: Remote Exploration Site Inspections -CPAI Checking schedules to see if we can accomodate your planned inspections. Will get back to you in day or so. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Brassfield, Tom 3 [mailto:TOM.J .Brassfield @conocophillips.com] Sent: Monday, August 10, 2009 2:40 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Alvord, Chip; Kanady, Randall B; NS Env Studies Coord; Senden, Leslie Subject: Remote Exploration Site Inspections -CPAI Tom, as we discussed; CPAI is planning to perform remote exploration site inspections on 8/19 & 8/20. Leslie and 1 are planning to meet the chopper at the KIC heli pad at 1000 hrs on Wednesday 8/19/09. The plan is as follows: Wednesday 8/19/09 Meet at the KIC heli pad @ 1000 hrs Visit Lookout #1, Spark 1A, Mooses Tooth C, Carbon #1, and Scout #1 Return to Alpine for the night Thursday 8/20/09 Lv Alpine for Puviaq- early as possible Return to Alpine for 1530 hrs flight to Deadhorse Chopper could fly back to Kuparuk with AOGCC inspector or? 9/10/2009 Remote Exploration Site Inspections -CPAI Page 4 of 4 • 40 Thanks, Tom Tom Brassfield Staff Drilling Engineer 907/265 -6377 (w) 907/244 -5684 (c) 907/275 -7352 (pgr) 9/10/2009 i? t.,�l gr`i'd 4 c! Ana United States Department of the Interior lk _b BUREAU OF LAND MANAGEMENT 4 RCH 3 ALASKA STATE OFFICE TAKE PRIDE 222 W. 7th Avenue, #13 ANCHORAGE, ALASKA 99513 -7599 http://www.ak.blin.gov • CERTIFIED MAIL . RECEIVED RETURN RECEIPT REQUESTED MAR 1 2008 AA -81854 3132 (932) mka ALASKA LAND MAR 5 2008 DECISION ConocoPhillips Alaska, Inc. • Attn: Land Manager P.O. Box 100360 Anchorage, Alaska 99510 -0360 { Anadarko Petroleum Corporation Attention: Land Manager — Alaska 1201 Lake Robbins Drive The Woodlands, Texas 77380 Pioneer Natural Resources 700 G Street, Suite 600 Anchorage, Alaska 99501 Oil and Gas Lease Renewal Your application for 10 -year renewal with discovery of oil and gas for lease AA- 081854 was received on December 18, 2007. This lease was originally issued for a 10 -year term effective September 1, 1999. The Bureau of Land Management has determined that a discovery of producible hydrocarbons was made in such quantities that a prudent operator would hold the lease for future development. Therefore, in accordance with 43 Code of Federal Regulations (CFR) Section 3135.1 -6(a), the term of this lease is renewed effective September 1, 2009, for a period of 10 years and so long thereafter as the lease is capable of producing oil or gas in paying quantities. Enclosed is the original lease form with the stipulations attached. The renewed lease carries the same terms and provisions of the original lease. Current bond coverage (WYB000291, MTB000041 and AKAAB084243) will extend to the renewed lease. 1 LE 93Q31-0 • i Any party claiming a property interest in lands affected by this decision may appeal the decision to the Interior Board of Land Appeals, Office of Hearings and Appeals, within thirty days of receipt of this decision. See DOI Form 1842 -1 and 43 CFR Part 4, copies enclosed, for instructions. The appellant has the burden of showing that the decision appealed from is in error. Failure to file the notice of appeal with the Bureau within the time allowed will result in dismissal of the appeal. In order to avoid dismissal of the appeal, there must be strict compliance with the regulations. Gam./ .y Robert Fisk Branch Chief. Branch of Energy and Minerals Enclosures cc: State of Alaska Department of Natural Resources Division of Oil and Gas Mr. Kevin Banks, Acting Director 550 West 7 Avenue, Suite 800 Anchorage, Alaska 99501 -3560 Alaska Oil and Gas Conservation Commission Mr. Dan Seamount, Commissioner 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Minerals Management Service Attn. George Hutchison, MS 357B1 P.O. 5760 Denver, Colorado 80217 -5760 • • 2 • • 18 PETROLEUM NEWS • WEEK OF SEPTEMBER 6, 2009 continued from page 1 , "Units are supposed to be UNITS Vim beneficial to both parties. The lessees get more time to explore exploratory work within the unit areas. their leases and the government It's a good deal all around, said Greg Noble, acting chief of BLM Alaska's ener- gear ToothLtwit Gob;iLL gets a commitment that further gy and minerals branch. - - - : ver t exploration will occur: "Units are supposed to be beneficial to - —Greg Noble, acting chief of BIM Alaska's both parties," he said. "The lessees get energy and minerals branch .r more time to explore their leases and the —co "t -I. la govemment gets a commitment that fur- choice within the expansion area," ther exploration will occur." .. _ While many leases were unitized, c Mooses Tooth Ron Noble's letter says. Y Failure to spud the well by the deadline ConocoPhillips and partners Anadarko and I _. will invalidate the unit expansion, the let - Pioneer Natural Resources let go 43 other i ter says. leases covering about 500,000 gross acres, Nati.o60t PCtrol.eu✓w company spokeswoman Natalie Lowman tserve ALOIEO S (NPR - r NPR - A production coming told Petroleum News on Sept. 2. t-PRA 01/.6 pas m.inits ConocoPhillips has been the most The surrendered leases didn't fit the c-,,,, oLL6c,as Leau. p ",. 14 company's strategic plans based on their ,,, SOH " °"` �N91A NM - active driller in the NPR -A, an Indiana- ] o <<s 4 i „ p ° „ °` - sized tract of North Slope land former potential for development, she said. i '-” What's more, many were in the very President Warren G. Harding set aside in remote northwest section of the NPR -A, The agreement gives ConocoPhillips a 1923 for its oil and gas potential. far to the west of existing production infra- Th surrendered leases didn't fit June 1, 2012, deadline to carry out the Most of the exploration, and discover - structure at the Alpine field. the company's strategic plans drilling and testing. Z ies, have been confined to the reserve's "We're really focused on Chukchi based on their potential for th sco northeast corner, closest to the existing exploration right now," Lowman added. development, she said. What's Greater Mooses Tooth expanded pipelines, roads and processing plants of s had more than 5506 mil- the central North Slope oil fields. ConocoPhillips more, many were in the very Noble also granted an expansion of the Still, NPR -A is considered a frontier lion in winning bids in a Chukchi Sea off- remote northwest section of t h e Greater Mooses Tooth unit, original where development dictates an accumula- shore lease sale in February 2008. formed in January 2008. t be either very large or reasonably NPR - A, far to the west of existing rY g y New Bear Tooth unit production infrastructure at the ConocoPhillips asked for the expan- close to infrastructure. sio on July 29, Noble approval letter The NPR -A's latest wave of leasing The BLM 's Noble signed two Aug. 25 Alpine field. says. began in 1999. Since then, ConocoPhillips letters creating a new Bear Tooth unit and The expansion adds four more leases to has surrendered leases on at least two expanding the existing Greater Mooses primary target and the upper Jurassic sand- the unit, increasing its size from 147,456 occasions. The company gave up 43 leas - Tooth unit. Both are in the northeast corner stone as the secondary target. acres to 164,014 acres. All the acreage is es in 2007 and 41 leases last year, of the NPR -A, west of the Colville River Under the unit agreement, federal land, but 40,238 acres or about a Lowman said. and the Inupiat Eskimo village of Nuigsut. ConocoPhillips must drill a well to the pri- quarter of the unit has been selected for But the company is marching toward ConocoPhillips applied for the Bear mary target in what's designated as Unit future subsurface conveyance to Arctic first production from the NPR -A in late Tooth unit on Aug. 19.11 takes in all or part Area A. The company also most test the Slope Regional Corp., the letter says. 2012 with its CD -5 Alpine West satellite of 23 leases covering 105,655 acres, all Scout 1 well to the secondary target in lieu In exchange for the expansion, development, which is in the permitting federal land. of drilling a well for Unit Area B. The sus- ConocoPhillips must spud an exploration phase. The production pad would sit Noble's letter says natural gas has been pended Scout 1 well, which sits on the well by the third quarter of 2015. The well roughly midway between the Alpine field discovered in the unit area. but no oil. It northern boundary of the Greater Mooses will target the upper Jurassic sandstone to the east and the Greater Mooses Tooth identifies the Cretaceous sandstone as the Tooth unit. was .spud in March 2014. and "will he located at the Unit Operator's unit to the west. • IN LAND i llna1ND - Over 1' Conoco bags Bear Tooth • r 48 q. Firm k eeps some expirin NPR -A l eases; one new unit, o ne exp By vthst� f f '.,r' Fo r P etro leum News - ..,,, ,,,._ F aced with a looming expiration date on dozens i a + i of federal leases, ConocoPhillips worked out a deal with the Bureau of Land Management to form Sear Tooth Kole „.. a new exploration unit called Bear Tooth and w expand an existing unit in the National Petroleum .'.., - Reserve- Alaska. . Rolling an individual lease into a unit has the tout 1 effect of extending its original 1.0-year tent, thus allowing ConocoPhillips to hang onto acreage it otherwise would have lost at the end ofAugust. Gt reater Mot T"a , In exchange for granting the company's unit requests, the BLM extracted promises from .t.1 ConocoPhillips to conduct more drilling and other Natiowa! Pte' ` see YIUB page 18 Rtser'e A1ASiPA( A) t ** - - * Lines of Business on the Slope * „ • Polyurethane /Polyurea Coatings fit' • Asbestos & Lead Abatement * • Oil Spill Response S ,jGs!`� ,a * ota �,o l, • Construction Management t) of Bristol Bay Native co? r CONSTRUCTION & ENVIRONMENTAL SERVICES PETROLEUM NEWS • WEEK OF AUGUST 23, 2009 79 continued from page 17 LEASES Cor oc Pi Pp) L i<:-i l . Ot l..ltc l •}, . rig iNil 1 1' 1 00• ic eral government began leasing land in the Y¢.a; 1 , ` - petroleum reserve more than a decade ago. " . .=:.k r �i` , •t drilling a total of 20 wells. and participat- ing in two others. a' In 2007 ConocoPhillips began dropping aglakbk 4: ' l rc,Fckv t. r rit.. Area leases in NPR -A. culling what a described NW NPRA I as acreage too far from infrastructure to be Sale Area I _ ' • ] economic to develop in areas where well .- i'S ‘ `:. , results were too small to be commercial. IIII ' But ConocoPhillips continued to pick .,.� s < up other acreage in NPR -A. #'.. ,ilvillu t.arr Unit its drilling M 2008 and 2009 was closer J — i ; ' - `j '_ - - I i e - ' to infrastructure. - -r In 2008. ConocoPhillips and its fre TRN quent NPR -A partner Anadarko � ,,. Nonr • 6 , — ' ! Petroleum, formed the first federal unit m r - t ik�,kP A ,_,: _ �IMi�� NPR -A, Greater Mooses Tooth. _ - t .� "'" After ConocoPhillips and .Anadarko's * 'a ■ ''' Al ine West CD -5 satellite in the Colville ? ' i : ^k,:q;, P ( ) I NE Nt'za Sala Area _. River unit has been developed, Colville and Mooses Tooth operator ConocoPhillips has _ said development of CD -6 and CD -7 NPR- MAPM ALASKA AKERS — . Pal � rl.� r , - A satellites would likely follows both of ,. •, •v.�, " € I which are in the Mooses Tooth unit. - _ .,:„.r 1 , . T.,,. t , Alpine West production is expected 10 i come online at the end of 2012. r .* Nz i t fon4f Petioleu rn .t.?S:,f ".'F= Al sl :d f NIP A .. —KAY CASHMAN ' Seventy -nine IVR -A Conoco e take from two to three months, MMS said. joint bid with that kind of uncertai . " e leases set to expire Aug_ 31 ee weeks Co • ust 27 companies partici- said during a teleconferen • mediately pated in Sale 211, , • - d with 53 in last following Sale 2 I 1 " • your tendency is. Scvtimty -nine leases operated by ConocoPhillips in the north- its ruling year's Western Gulf of Mexico . e `I can of " e to the lease sale by going ufort, and east sale area of the National Petroleum Reserve-Alaska are set 207. for example. - • u •robably saw some increase in to expire on Aug. 31. Interior Chris Oynes, MMS' associate • . - the amount o - ompany) bids. or u Mamemen1. Neither the U.S. Burea of Lund a nor nurt with for offshore ener gy, indica .1 "under- even the strength of the M. . , - - of g t_ uaauPiollips_ was n to ununarot 00 a proposal the s s of its corn current" stemmin • uncertainty over that undercurrent' puny submittedl earner this month to BLM on the expiring plan "to the Iiti_. 1 .ely was a major factor in The S115.46 million in apparent high acreage. BLM has not yet compktcd its response to that pro- environ- e. bids submitted in Western Gulf Sale 210 posnl, ConocoPhillips said and BLM confirmed. 's enern "It's very, very hard to make the agree - BI.M spokeswoman Sharon Wilson told Pcuokvm News 210 was ments between companies formulating a see LEASE SALE page 20 Aug . 20, that CunucoPhllips bus two options for a 10 - year :ompany see LEASES page 17 tins that nee sun- _ -.__ _. "._._ -I details "; PETROLEUM NEWS • WEEK OF AUGUST 23, 2009 `J continued from page 1 ConocoPhillips has been the most LEASES active explorer in NPR -A since the federal government began }� renewal on each of the 79 leases: Apply leasing land in the petroleum ` ! under "lease without a discovery," which carries a price tag of S100 per acre, or reserve more than a decade ago, r' apply as a "lease with discovery," in drilling a total of 21 wells, a ,fr• which case the S100 fee would be participating in two others. ../O waived. "There are other nominal , r ; administrative fees attached in both situ- Hunter A was drilled in 2002. some ations," Wilson said. 28 miles southwest of Nuiqsut. The expiring leases, purchased in the Petroleum News was unable to discover first NE NPR -A lease sale in 1999, the status of the well. - i' :' include the Trailblazer wells drilled by Noatak. drilled by ConocoPhillips in BP (ConocoPhillips was a partner and 2007 in partnership with Pioneer Natural f</ •��n� es), and the following wells, drilled by dial" in May later, with Anadarko, acquired the leas- Resources, was deemed "non - commer- ff Wb'a The Producers' Partner for Over 20 Years oY ex in part because of its I ConocoPhillips: Ow PAt distance from existng oilfield infra - 1a2,1'2 - • Puviaq 1 t�•�4,1? AO structure in the Colville River unit. V•i •�u` • Hunter A A \ 1/ where ConocoPhillips is looking at pro- • Noatak 1 to. d cessing its eastern NPR -A discoveries. • Scout 1 S,�s P Scout 1, which sits on the boundary .QS t) The Puviaq well, drilled by o the Mooses Tooth unit, was drilled in ConocoPhillips in the winter of 2003, is 2004, within 10 miles of discoveries that atiti - 00ta near the Ikpikpuk River, which is almost were made in 2000 and 2001. The well 80 miles from the village of Nuiqsut. was suspended, and the results were not The wildcat, in which Anadarko was a released. A IT �.� partner, took two seasons to drill and Trailblazer A -01 well was plugged test, with an ice pad put in one year and and abandoned; Trailblazer H -01 was " drilling and testing done the next. suspended.nA mita ,C3:0 - Rolligons were used to reach the well L Staying closer N ilfiastrllttu'e f site versus building an ice road. I_.) ASR C Energy Services The results of the Puviaq well have ConocoPhillips has been the most J u subsidiary of Arctic Slope Regional CorPOracio., :.. not been released. The well is in opera- active explorer in NPR -A since the fed - tional suspension. see LEASES *page 19 . i strati Owned . Alaskan Operated. • • -' - '-''' ,,, - , , ,„ , ,,, , al DA [ it Lid; SEAN PARNELL GOVERNOR GAS OIL AND A' 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. C. Alvord Alpine Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, Puviaq 1 Sundry Number: 309 -310 Dear Mr. Alvord: 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, ( Daniel T. Seamount, Jr. Chair DATED this? day of September, 2009 Encl. 4110 • Cr) c my) i'1 ' ' STATE OF ALASKA i 6� ALASKA OIL AND GAS CONSERVATION COMMISSION q APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other 0 Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ extension of ; suspension Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory 5 202 -248 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 279 - 20008 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Spacing Exception Requires? Yes ❑ No 0 • Puviaq 1 ° 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): a 0AA081854 / L32589 RKB 30', 28' MSL Exploratory • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7900' 7900' 6141' 6141' Casing Length Size MD TVD Burst Collapse Conductor 82' 20" 112' 112' Surface 1393' 13.375" 1423' 1423' Intermediate 3137' 9.625" 3167' 3167' Production 7861' 7" 7891' 7891' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" L -80 6150' Packers and SSSV Type: Packers and SSSV MD (ft) FB - 1 and SAB - 3 pkrs @ 6725', 5940' no SSSV no SSSV 13. Attachments: Description Summary of Proposal p 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p • Development ❑ Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operatil September 10, 2009 Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: suspended 0 • 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield @ 265 -6377 Printed Name Chip Alvord Title: Drilling Manager Signatu� t �v., / le- a 4Aifocd Phone 265 -6120 Date 9/ Ag Commission Use Only Sundry Numb r: Conditions of approval: otify Commission so that a representative may witness 3ft 3/40 • Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: R ' .SBR.. H x .02009 •' �� AP PROVED BY Approved by: OMMISSIONER THE COMMISSION Date: Fui m 10- 43 - evicted 00/2006 oRIGINAL / �, 3,� 4 ' Sub�dl In Du li le • • Puviaq #1, Network #10028348 Completion Schematic, Sheet 1 of 2 Exploration Well - CONFIDENTIAL Nabors 16E RKB @ 30' (1) Tubing Hanger with BPV installed: FMC Gen V Elevation. BPMSL2 GL' 16" Conductor O % @ 112' MD " ! Ariz (1) Landing Nipple @ 499' MD: Surface Casing @ 3' # 13 3/8" L BOSS r Camco 'DS' nipple w/ 2.875" No -Go Profile TOC behind 9 -5/8" csg est @ r Camco 'K UG G � 3- 1 /2 "x 1 ", w/ dummy MD/TVD latch 2667' MD /TVD 9 -5/8" x 7" annulus FP with diesel to 1383' 13 -3/8" x 9 -5/8" annulus FP with diesel Intermediate Casing to 400 @ 3167' MD / 316T TVD 10.0+ Naar brin 9-5/8", 53.5 & 47#, L-80, e from D PBTD of 7803' BOSS & 40 # L-80 BTC MD/TVD 0 s to 1510' t & 7 MD/TVD & 3-W diesel from 1510' annulus TOC estimated at 5300' MD Tubing Production 3-1/2", 9.3#, L-80, EUE 8RD Mod (1) Gas Lift Mandrel @ +/- 5873' MD: Cannco , 3 -1/2" x 1 ", with Dummy Valve and Latch Production Casing i @ 7891' MD/TVD 4 ; 7 ", 26 #, L -80 BTC -Mod (1) PBR & SAB -3 Packer Assembly @ +/- 5940' MD N ueur p ii�r N See Sheet 2 for Packer Assembly and Below Sheet 1 of 2 • See Sheet 1 for Completion Assembly Above 10.0+ NaBr brine from PBTD of ,,,,, r, 7803'from 1510' to�rfa &e diesel . % PBR Assembly @ +/- 5940' MD /TVD r.c5 (2) Gas Lift Mandrels: 3-1/2" x 1" with Dummy Valve and Latch @ 6061' & 6118' MD /TVD Production 31' Tubing /2 9 3 #, L 80,EUE 3 ' / ol shed bore nipple It ID latched in 8rd Mod polished @6141' MD /TVD Mule Shoe No perforations Tubing Tail set @ 6150' Baker FB -1 Permanent Packer @ 6725' MD/ TVD (1) Landing Nipple: 3 -1/2 H Tubbng Tail set nipple @ 6750' 6743 MD/TVD No perforations Float Collar @ 7803' MD /TVD « ' Production Casing @ 7891' MD/TVD (est) 7 ", 26 #, L -80, BTC TD 8 -1/2" Hole: Sheet 2 of 2 7900' MD !r f4-.i ‘,C v`p. i tr E_P 0 2 ZO -11.- ConocoPhillips Box 100360 Alaska 99510 -0360 September 1, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of suspension status 10 -403 Sundry Puviaq #1 (Exploratory Test) Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W X= 450,547.8 & Y= 6,105,700.17 ASPS NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a request for renewal of suspension status for the Puviaq #1 welibore per 20 AAC 25.110. The well was visually inspected on 8/20/09 and the results submitted with a 10 -404 sundry. Attached is a welibore schematic noting the condition of the welibore. Please note the following: • The wellbore is not perforated • Kill weight fluid in the tubing and the tubing by 7" annulus to 1510' MD/TVD with diesel from 1510' MD/TVD to surface. • Freeze protect diesel in both the 7 "x9 -5/8" annulus and the 9- 5/8 "x13- 5/8" annulus • Cement to surface on the 13 -3/8" casing • BPV installed in the tubing hanger. CPAI requests renewal of the suspension because the well is being held for purposes of testing to assess reservoir productivity, prior to expiration of the extended lease term (August 31, 2019). Si erel // Tom rass field Senior Drilling Engi - er • • cc: CONFIDENTIAL — Puviaq #1 Well File Chip Alvord ATO -1570 Leslie Senden ATO -1390 R • • TC. P 0 2 2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION' ,. .. REPORT OF SUNDRY WELL OPERATIONS remote site 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other inspection Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory 151 202 -248 / 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 279 - 20008 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 30', 28' MSL Puviaq 1 8. Property Des' ation: 10. Field /Pool(s): 4 , 1 , AA081854/ L32589 Exploratory . 11. Present Well Condition Summary: Total Depth measured 7900' feet true vertical 7900' feet Plugs (measured; Effective Depth measured 6141' feet Junk (measured) true vertical 6141' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 112' 112' Surface 1393' 13.375" 1423' 1423' Intermediate 3137' 9.625" 3167' 3167' Production 7861' 7" 7891' 7891' Perforation depth: Measured depth: none true vertical depth: none Tubing (size, grade, and measured depth) 3.5" , L -80 , 6150' Packers & SSSV (type & measured depth) FB - and SAB - pkrs Q 6725', 5940' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation -- Subsequent to operation -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 12 Development ❑ Service ❑ Daily Report of Well Operations _ 16. Well Status after work: CO GaCI WAG❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tom Brassfield @ 265 -6377 Printed Name Chip Alvord Title Drilling Manager Signature - / L i / � \ / 1 P 265 -6120 Date 91 f �(/! �L� ��� e4 .t i Y �U .� gl / nJ,d'[i Prepared by Sharon Allsup- e 263 -4612 f-3-0? Form 10 -404 Revised 4/2006 ROWS B ' 0 8 2009 rh a Ongi I Only • • �-� Remote Well Inspection Checklist Well Name r"i A V I CA I Suspended Abandoned ❑ Coordinates: 70. (0712.... - /SL . f / / f k" Date: ___Of2/(251_____ Yes No N/A 1. Area surrounding Wellhead • Impounded Water sVn\kk. Tcr■c\nn '® ❑ ❑ • Sheen present on ground water ❑ ❑ 2. Cellar Area • Fluid in cellar ❑ ❑ • Sheen present ❑ Er ❑ • Fluid level in cellar is..higher ❑ lower ❑ the same as J the level of the ground water outside the cellar. l�` 3. Wellhead and tree • Presently leaking ❑ J ❑ • Evidence of prior leaks ❑ 'r ❑ 4. Bird Cover • Complete and secure ❑ ❑ • Evidence of fluids on inside of cover ❑ ❑ Description of Tree and Wellhead: ( i.e. valve handles. Gages, needle valves, number of valves, etc.) Jr LA —E- r r E S, h Avvkcc yr 4 -P'ww t -s, ell/0 1 , r Description of Findings: Printed Name: I-es lie' cvy e vt Signature . '- Original to : Sharon Allsup -Drake ATO 1533 • IP Puviaq #1, Network #10028348 Completion Schematic, Sheet 1 of 2 Exploration Well - CONFIDENTIAL Nabors 16E RKB @ 30' [yl���] Elevation c.0 (1) Tubing Hanger with BPV installed: FMC Gen V 2Q '��i,. % / .2' G � ' Y/A BPMSL % 16" @112'MD Conductor (1) Landing Surface Casing Camco 'DS' n i p e w/ 5 ' No -Go Profile 13 - 3/8" 72 # L,80 BOSS (1) Gas Lift Mandrel @ + / - 2494' MD /TVD TOC b eh TOC 2667' @ r 9 -5/8" x 7 annulus FP with diesel to 1383' / dummy and latch 6' MD/TVD annu MD/TVD 13 3/8" x FP with diesel Intermediate Casing ` to 1400' MD /TVD 9-5/8 53. 5 & 47 #, L-80, 10.0+ NaBop5g bbrine from & d esel from BOSS & 40 # L 80 BTC 1510' to surface in tbg & 7 "x 3 - %" annulus Production Tubing TOC estimated at 5300' MD 3 -1/2 ", 8RD ModO, EUE (1) Gas Lift Mandel Camco 'KB G' , 3- +/ " 1 " 5 wth D ummy Valve and Latch E=223 mem Production Casing 097.1:467.eZe. @ 7891' MD /TVD , 7 ", 26 #, L -80 BTC -Mod ! (1) PBR & SAB -3 Packer Assembly @ +/- 5940' MD "111, - See Sheet 2 for Packer Assembly and Below Sheet 1 oft See Sheet 1 for Completion Assembly Above 10. 0+ NaBr brine from PBTD of r, ; , ® 7803'from 1510' MD/TVD torfa & diesel r ffy F PBR Assembly acker ;- @ +1- 5940' MD /TVD (2) Gas Lift CAMCO 'KB Mandrels: 'KBUG', x 1 ", with Dummy Valve and Latch @ 6061' & 6118' MD /TVD Production Tubing 3 -1/2 ", 9.3#, L-80, EUE 3 , pol shed bore w /RHC nipple with ID plug latched in 8 place @6141' MD /TVD Mule Shoe No perforations ` Tubing Tail set @ 6150' y Afig, Baker FB -1 Permanent Packer @ 6725' MD/ TVD (1) Landing Nipple: 3 -1/2" Halliburton 'XN' nipple @ 6743' MD /TVD / 0 i r Tubing Tail set @ 6750' No perforations Float Collar @ 7803' MD /TVD Production Casing @ 7891' MD /TVD (est) 7 ", 26 #, L -80, BTC TD 8 -1/2" Hole: Sheet 2 of 2 7900' MD 0 0 N otes: 70N :A -•'o 70N 1. Basis of Horizontal and Vertical Location are the Alpine 4 � "6 4 r " R • CT Monuments #19 and #12. ' 2. All distances are true, and are in U.S. Survey feet. 85N �Ir,f ` :�' 1 4 ' . *il # , TS114 :Wilrif J 1,70 60N 60N # ac I � � ■ p a AIJNE ' U �� . ' ` 556 I 00 d' 4)§ . 4 i P ����i 55N w KuDIAK �� ►�. � ►w r '� ' - .. S li . m I mo Kilometers K ;04P ►� A, ... 4. �� l Vicinity Map EDGE OF --,,,1/4, ICE PAD 0 -cPNK i llllllll llIrli °"'ii1II IIIIIIII V eNOP ��� C,0 Sco 0 • i - 0 1 G OW. -( 10 1°1 EDGE OF � ° ° -c0 \ 0 S ICE PAD PIPE E . Q n = n SHED CO NABORS 1 � wri fn aml 0 TO PA RSTR\P N . ■1 ------- � as 01 ® 50 �� 5'E PUVIAQ A Q ONE / Lat: 70°41'58.44"N N� Long: 154 °24'30.50 "W CJTTINGS PIT (Y) 6105Y) 6105 700.17 77' by 160' (X) 450547.80 444' FWL I (A 1713' FNL m' m BPMSL GROUND ELEV. = 26.0' o ���� ""��� \ � ICE PAD ELEV. =28.2' @ CONDUCTOR 1 49th % \ *� v0 • / • 0 m . . Anthony P. Hoffman i o I • 4 G," . No. LS -9020 .• - I Puviaq #1 K u u k p i k/ LC M F WELL CONDUCTOR AS -BUILT SURVEY A subsidiary of Ukpeegvik (dupietCorporation t LOCATED IN SEC 35, T16N, R10W, UMIAT MERIDIAN Alpine Office (907) 670 -4739 °:',0*:, r BARROW, ALASKA Anchorage, Alaska (907) 273 -1830 Alpine Survey Office DATE: 2/27/03 DRAWN BY: TH SHEET: 1/1 SCALE: 1" =200' CHECKED BY: W.O.No:03- 01 -20 -1 uvi aq 1 c ,accFhilli s Alaska, Inc. �, F '�' " This photo is cc ri ht onocoPh s 1asl Inc. an cannot be released or published withou t the express consent of CatocoPlillips Alaska, Ir�,c. '¢ , a • ■ . d 4 ,di �." r .xr � .' w - ., ,. ,.. , .. ..., ,, ..,,,,, „ .. .... .. .. . app ..,..". . , a .t ._ ..::, .: ..,„„„,„,,,,,:,,,,,,,— `9+ ... . . . ,, e ......... ,...„."..,_ ......„.....„..... . . ...., ... ,,..„ ,w., , , , .„,.„...-„,,,,,, 4. I r. ) ' . i R n ' , ,. , „ --------' .. 2, 6 1 j ,,,,, i\Nit i,N,,, *6 # 1 'emu, t u m ', iu « .m ?w. WY^v ..... +s' x '' 3 �° bu '�.:. �,� .ter 4 ti H i pp � t � ''''''''''.1 c: y z ionuu$'Itt}hps Alaska. Ill"' i Yus 1Ii to Is. >yrt Jtt bg r.'uu* 1'I dhps Alaska tug '''''.1 cautiot be released s ,« t ,r published u tfiu the express couseut 01 Q Alaska Inc °t IR ,ti.i,. r- 1 Cutttit'.tl PiiiLLIPS PtiYIAtl I , PTO 2112-2411 API ritl-'Lil1-2tltlti - t ) ti 17 13 fit 444 f 1VL SEC 31, `i IIG -Rita W 131 . t yyy. #y , y -: `..: ,. �1 € x , . '' �` e 4 w+ a. F . n. <frr F uvtal I ciou xoPlullips Alaska. Inc This photo is copyright by Coif co4hillips Alaska luc. and c:wuot be released or published without the express consent of �ouocoFLdhps Alaska. as Inc f ( f as a ' ems'._ .pe ^` S " °" !, �. a `^ q1 .1'."44:1417.• m ,. A a ` ' 4 war: ,'744,,,i'..„. # a u pt . ' � ,-4./414'.444 !'ii ,l tl ) m -; x 4 API $OE 279 Ul7 ` ., u s x :1713 FRI. ddd FWt SEC ' .' <TiC -RIO OM >y , I y' ■ 4 N. k 4 : „ 4 f • • 'AT' 0 ;)0i; raiels R.+ ;j 3. ConocoPhulhps Box 100360 Alaska 99510 -0360 September 1, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Well Inspection 10 -404 Sundry Puviaq #1 (Exploratory Test) Surface Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W X= 450,547.8 & Y= 6,105,700.17 ASPS NAD27 Target Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W Bottom Hole Location: 1713' FNL, 444' FWL, Sec 35, T16N -R10W Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a status update for the field inspection of the Puviaq #1 location performed on 8/20/09 as required by 20 AAC 25.110. Please find attached the following documents: • Remote Well inspection Checklist- please note that there was some identified "distressed" tundra as indicated in the attached pictures. The BLM has been notified and expressed no concerns. A third party consultant will be in the area next year and asked for any remedial recommendations. This inspection was a visual inspection and no pressure readings were taken. • The "as- built" plat • Photographs • A wellbore diagram • The 10 -404 Sundry The request for renewal of suspension status will be filed with a 10 -403 Sundry. Sincerel j /„. Tom Brass r d Senior Drilling Engin: -r • • cc: CONFIDENTIAL — Puviaq #1 Well File Chip Alvord ATO -1570 Leslie Senden ATO -1390 ,II r:' , - •- , , , - -, .., . * ' A. .,, ..... -,--'- ,,, ...f ,- '' . .'"•‘, ,,-: , co -144.\-i.-:-, : ' ‘. „ . , .... de' 44-1.41..- .,,,,, , ,.. _•.-,..„:,......4. - .r.fiv'. , A , -41'''''' 4"' 44'-.A.1'!. '':,t, ' 4 ' '4:-.4*- `.'• .- f N ,)f , , ,, ,*. , i! 4r, * 4 .i... .. •, . , , 4 - , A it, itsk , . , ..,.„,,, ,., 4 ' .. , ■ ' 1 .... ' - -t- "' "...t4.4t-t", 54 - • '! ,..., , qt. k4t - AS* . - • 4111( .,. V ....„ . , - . _ . „ ... -,, Iv ., 0. .•. , ' ., .,..,•,-„ • , , . •,,,,,,.. ,,,,,... ,: . ..,- ....,' ' ' fati,- h. ..1 ,...i ...” , i ' ,,, .. ...,. . . At .. be released or d cannot . ' -.- - to•";"- ...,:"..- 1...77.-" - Inc. an k a, • s A ask a, Alas pnc. oP11111iP 1611 1 coiloc°F hillips cohilliPs, I . r . g ht by , g . ,1c011)3_, ,„ consent of Curl° This photo is copyr ., the expres • ,t,_ut ..---- 1,,,..d without E i • 2011j 243/ - jirej published . , 11-V 1 r e ` 1 A d V .. a . . 4, i ° 'fir � ". ?t" t a � r 5, na �. .�? 0.r cu Ca mDcoFhillips 1 ask as Inc. • p hctc i cc right cna coFhillipa 1 ask a, Inc. ari aruiat r le as ¢' • r publ ithcut t he pr -consent c c ccFhillip Alaska, Inc. _ . . ,. - -R wh...--- : mom'° � � �' �D9pa `° — „, ' "--- ..- , . - .,, l'.. 0 4?". o'''''' ' - ...'' : 4 ' x P ti - . , . .„ ,..„,, , s , - ' P , ' � ' , - - ..s. -,,,,, ,,,,,, ...„..,.., ,,.., :.,_-, w -, #44 „,..,......„.....'?..„ .. ......, 44,, -.,...4 „ « �., ,, k. .04 or" � * mom Tr w r , 0 - Cw CarDacoPhillip Al ask a, Inc. — I 1' • s photo i s copyright by ConocoPhillips Ala,-1 a, Inc. aria cannot released r 1 a or ''; ` .,: r ub lishe d without the express consent of CcnacoPhilli s lash a, Inc . Q)Con000Phillips Alaska, Inc This photo is copyright by ConocoPhillips Alaska, Inc. and cannot be released or published without the express consent of ConaooPhillips Alaska, Inc. Puviaq well Page 1 of 1 • McMains, Stephen E (DOA) To: Wharton, Paul K Subject: RE: Puviaq well Confirm receipt of your email. Will place this email in well file pending DNR decision about extended confidentiality. From: Wharton, Paul K [ mailto: PauI .K.Wharton ©conocophillips.com] Sent: Tuesday, July 14, 2009 2:01 PM To: McMains, Stephen E (DOA) Cc: Brown, David W.; Snyder, Frank C; Brassfield, Tom 3 Subject: Puviaq well Steve: This will confirm our conversation today, that the Puviaq Well is held in confidential status by AOGCC pending DNR's action on our request for confidentiality, and that under the Order of the Commissioner dated April 14, 2006 the status of the well is Suspended; and nothing is required from ConocoPhillips unless you get back to us. Regards, Paul Paul K. Wharton Staff Landman ConocoPhillips Alaska, Inc. ATO 1482 700 G. Street (zip for street address 99501) P.O. Box 100360 Anchorage, Alaska 99510 -0360 tel. (907) 263 -4076 fax (907) 263 -4966 email: Paul .K.Wharton @conocophillips.com 7/14/2009 • Erec S. Isaacson Vice President Exploration & Land P.O. Box 100360 Anchorage, AK 99510 -0360 IPPV Phone 907.263.4556 ConocoP Alaska, Inc. RECEIVED -111 ? R 7I Ufa January 21, 2008 Aiasit # °;; w , C pli. ,rZAldlielQ Via hand delivery Ahhvrngq Tom Irwin, Commissioner State of Alaska Department of Natural Resources 550 West 7 Avenue, Suite 1400 Anchorage, AK 99501 Re: Request for Extension of Confidentiality for Well Data Under A.S. 31.05.035 and 11 AAC 83.153 ConocoPhillips Alaska, Inc. ( "ConocoPhillips "), as operator for and on behalf of the working interest owners ( "Lessees ") of the well described on Attachment A -1 hereto (the "Well "), requests extended confidentiality for the reports and information generated from the Well and filed with the Alaska Oil and Gas Conservation Commission as required by state law (the "Well Data "). The Well is located on federal lands located within the NPR -A subject to Department of Interior, Bureau of Land Management ( "BLM ") lease AA- 081854 ( "Puviaq Lease) and not adjacent to any state lands. Please refer to the plat attached hereto as Attachment A -2. The Lessees request extended confidentiality for the following reasons, which are discussed in more detail below: (1) the Well Data is important to the Lessees in evaluating acreage in future federal oil and gas lease sales in the NPR -A; (2) the Well Data constitutes trade secret information, which is protected from public disclosure under federal law and state law; (3) the BLM, which is the federal lessor and administrator of the leases on which the Well is located, has not determined that the Well Data should be disclosed to the public; (4) unleased federal acreage in the Teshupuk Lake area (within T16N, 08W, UM and elsewhere) is within eight miles of the Puviaq Well location; (5) the primary terms on adjacent BLM leases will expire on August 31, 2009; and (6) the Lessees have petitioned the BLM to extend the term of the Puviaq Lease to an additional ten year term under the applicable provisions of federal law. • Commissioner Irwin Request for Extended Confidentiality Page 2 January 21, 2008 1. The Well Data is important to the Lessees in evaluating acreage in future federal oil and gas lease sales in the NPR -A. The Well Data contains significant proprietary and sensitive information relating to the valuation of unleased lands within the NPR -A. The remote nature of the NPR -A lands and the existing restrictive stipulations require long lead times for exploration and development of the lands within the NPR -A. Each new well, when strategically placed for drilling based on data obtained from proprietary seismic surveys and other sources, provides new valuable information about the prospectivity and value analyses of both leased and unleased lands in the area. Forced disclosure of Well Data to the public by the Commissioner, which Well Data was obtained at the sole risk and at substantial expense of the Lessees, will be detrimental to the Lessees' competitive position in the NPR -A. 2. The Well Data constitutes trade secret information, which is protected from public disclosure under federal law and state law. The Well Data constitutes "trade secrets," which are protected from disclosure under both federal and state law. See, e.g., State v. Arctic Slope Regional Corp., 834 P.2d 134, 138 (Alaska 1991). In State v. ASRC, the Supreme Court of Alaska addressed the question of the validity of the provision in AS 31.05.035 that allows the Department of Natural Resources ( "DNR ") to review otherwise confidential data as part of the process to obtain extended confidentiality. The court in that case, however, expressly did not opine on the question of whether such trade secret data could or should be disclosed to the public without compensation, and in fact, specifically distinguished its decision from other decisions that addressed the public disclosure question. 834 P.2d at 144. Other courts have invalidated requirements in state laws that require the trade secret data to be disclosed to the public. For example, as cited in State v. ASRC, the Supreme Court of Wisconsin invalidated such a requirement in Noranda Exploration, Inc. v. Ostrom, 335 N.W. 2d 596 (Wisconsin 1983). Similarly here, where the DNR has the authority to recognize and protect trade secret data from lands that the state of Alaska does not own or manage, the DNR should find that extended confidentiality is warranted based on the facts of the situation. 3. The BLM, which is the federal lessor and administrator of the leases on which the Well is located, has not determined that the Well Data should be disclosed to the u p blic. The Well Data was generated from a well drilled on federal lands under a federal oil and gas lease issued and administered by the BLM. Federal statute 5 USC 552(b)(9) exempts "geological or geophysical information and data, including maps, concerning wells" from the right of public inspection and disclosure provided in the Freedom of Information Act ( "FOIA ") at 5 USC 552(a). The NPR -A lease terms under which Lessees leased the lands on which the Wells were drilled states as follows: During existence of this lease, information obtained under this [section 5] shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552) ( "FOIA "). • Commissioner Irwin Request for Extended Confidentiality Page 3 January 21, 2008 Paragraph 2, Section 5, NPR -A Lease Form, a copy of which is attached hereto as Attachment B. The BLM has not determined that the Data should be made available to the public under FOIA. The BLM furthermore has not determined that the criteria used by the DNR in determining whether to agree to extended confidentiality are reasonable, appropriate, or applicable to wells drilled within the NPR -A. The public interest considered for federal purposes extends much farther than the state of Alaska, and the federal and state interests may not be and often are not the same. The Alaska Oil and Gas Conservation Commission's authority over federal lands for environmental and conservation purposes cannot impermissibly conflict with federal law, and the DNR's authority here is similarly limited. To disclose the Well Data to the public before the BLM has determined that it may be disclosed to the public and without the express written agreement and concurrence from the BLM creates a direct and impermissible conflict with federal law and policy. The Commissioner should grant extended confidentiality for the Well Data as requested in this letter. 4. Unleased federal acreage in the Teshupuk Lake area (within T16N, 08W, UM and elsewhere) is within eight miles of the Well location. There is currently unleased acreage approximately eight miles from the Well. Please see Attachment A -2 hereto. Although current Department regulations provide for extended confidentiality within three miles of unleased acreage (11 AAC 83.153(a)), the lease size allowed on these federal lands is substantially larger than the largest lease allowed on state lands (5,760 acres maximum per AS 38.05.180(m) versus 60,000 acres maximum size per 42 U.S.C. §6506a(h)). There is nothing in the history of the three mile provision that evidences any consideration that leases larger than those that the State of Alaska Department of Natural Resources manages on state lands might exist on other lands. Even the lease size generally found in the area of the NPR -A where the Well is located (11,520 acres, which is half of a township) is six miles long along its long axis. Clearly the three mile provision found in 11 AAC 83.153(a) is inappropriate in evaluating the larger lease sizes in the NPR -A. 1 Unless the Commissioner determines that the provisions of 11 AAC 83.153(a) do not apply at all to non -state lands, it must be presumed that the regulation at 11 AAC 83.153(a) does not use the defmition of "land" as provided in the underlying statutory authority of the Alaska Land Act. There is no defmition for use of the word "land" in the regulation, but AS 38.05.965(21) defines "land" as used "in this chapter [the Alaska Land Act, AS 38.05]" as "all land, including shore, tide, and submerged land, or resources belonging to or acquired by the state." To impose that definition on the provision allowing extended confidentiality for wellbores within three miles of unleased "land" would raise substantial additional legal issues for federal lands, including the Puviaq Lease, that are more than three miles from any state land whether leased or unleased. Should the Commissioner interpret the term "land" in 11 AAC 83.153(a) to mean only "state lands," the Lessees reserve all rights to raise all claims, points on appeal, and legal theories implicated by that interpretation. • Commissioner Irwin Request for Extended Confidentiality Page 4 January 21, 2008 5. The primary terms on certain adjacent leases will expire on August 31, 2009. The primary term on certain adjacent BLM leases will expire on August 31, 2009. Please refer to the plat attached as A -2. Although the adjacent BLM leases may be extended by various means allowed under federal law before the end of the primary term, it is presently unknown whether the primary term of any of the adjacent leases will be extended. If the adjacent leases expire by their own terms on August 31, 2009, then the Puviaq Lease will be adjacent to and within the three miles of unleased lands as contemplated under 11 AAC 83.153(a). The Commissioner should extend the confidential status of the Well Data. 6. The Lessees have petitioned the BLM to extend the term of the Puviaq Lease for an additional ten year term under the applicable provisions of federal law. The Lessees have petitioned the BLM to extend the term of the Puviaq Lease, which would otherwise expire on August 31, 2009, for an additional ten year term beyond its primary ten year term. The BLM will continue to hold the Well Data confidential during the extended term, and the Commissioner should grant extended confidentiality to the Well Data in order to avoid a direct conflict with federal law concerning this Well Data obtained from federal lands. The Lessees request that the DNR find that the Well Data should be granted extended confidentiality until such time as the Well Data is actually made public by the BLM if and when a final lawful order of the BLM or Department of Interior determines that the Well Data should be disclosed to the public. If you have any questions or require any additional information, please call me or Paul Wharton at 263 -4076, and we will arrange a meeting to review this matter in more detail. Very truly yours, Erec S. Isaacson �' Vice President Exploration & Land • • Commissioner Irwin Request for Extended Confidentiality Page 5 January 21, 2008 cc: United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7 Avenue #13 (701 C Street) Anchorage, Alaska 99513 -7599 Attn.: Robert Fisk, Deputy State Director, Division of Energy and Minerals Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Attn.: John K. Norman, Chair State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7 Ave., Suite 800 Anchorage, AK 99501 -3510 Attn.: Kevin Banks, Acting Director Anadarko Petroleum Corporation 1201 Lake Robbins Drive The Woodlands, Texas 77380 P.O. Box 1330 Houston, TX 77251 -1330 Attn: Steven Dodds, Land Supervisor, Alaska Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Attention: Pat Foley, Manager of Land and External Affairs • • Commissioner Irwin Request for Extended Confidentiality Page 6 January 21, 2008 Attachment A -1 Extended Confidentiality Requested for the following Well Well Name Lease No. Permit to Drill API Number Status j Puviaq AA- 081854 202 -248/ 303 -116 50- 279 - 20008 -00 Plugged and suspended Surface and bottomhole location: 1,748'FNL, 339' FWL, Sec. 35, T 16N, RIOW, UM Attachment A -2 4� Plat of Puviaq Well Location v �` FEx ) . y ;, Pt. Poles . v )' � ADL390857 ,C �' 1 ` 9 -30-14 ' 9- 13 0 -t4 5 T �, X , � _.. FEX - 1 - ; 2 -28 -14 \c 2 _ J 1 621 N " h' y A.A085533 M085577 — ADL390859 _' � '� ■ EX PETRQk CANADA 11 / c \N kEX APC, CPAI, PIONEER `; , 30-14 \ -- 3 30- 9 -30 -14 )� (- : I I 08 -31 -09 N\` ;N • C c 8851 AA08 6 AA081 3 , AKFF [14622 ( 14622 CANADA, APC, CPAI, PIONEER APC,, � ' , PIONEER �d nah _ e�w � t EX X ` <\ 1‹.\ i J % 30-14 9 -30• PUVIAQ 1 APC, 08 -31 -09 '; CPAI, / /p/�(FF 014637C PIONEER „ , AF, y Meadows N (�,go) , �- -- � .__ r" 08 -31 -09 4 PUVIAQ 1 r J 85517 AA085575 M081854 AA081852 FEX, APC, CPAI, PIONEER APC, CPAI, PIONEER ___R-/ PETRO- CANADA 9-30-14 08 -A AKFF 015512 , ; VV -1 ng.dis -09 , Q APC CPA , ' 10 ER �'� ill AA085574 gN AA081851 F92389 VET ' ' 4 : `� APP LOG SON) ON ` CANADA, APC I, PIONEER �wPROX S LOG Ox ,11noy) .•C ii �'1, p41,41,41; 1 30-12 C(� 0 -14 08 -31 -09 08- 31-09 EX Pailll „1 III ConocoPhillips 35573 AA1818`0 AA081848 Aft , _ imm — iiiim — PC 1V APC, CPAI, PIONEER Puviaq 1 SCALE IN MILES PAI PIONETI Well Location 08 -31 -09 08 -31 -09 1 -14 -08 07082101A02 XHIBIT B NITED STATES • Serial No. DE MENT OF THE INTERIOR . BUl; AU OF LAND MANAGEMENT AA- 081854 ALASKA STATE OFFICE OFFER TO LEASE AND LEASE FOR OIL AND GAS The undersigned (reverse) offers to lease all or any of the lands in Item 2 that are available for lease pursuant to the Mineral Leasing Act of 1920, as amended and supplemented (30 U.S.C. 181 et seq.), the Mineral Leasing Act for Acquired Lands of 1947, as amended (30 U.S.C. 351 -359), the Attorney General's Opinion of April 2, 1941 (40 Op. Atty. Gen. 41), or the Naval Petroleum Reserve Production Act of 1976 (42 U.S.C. 6501 et seq.), as amended. READ INSTRUCTIONS BEFORE COMPLETING 1. Name ARCO Alaska Inc. (78 %) and Anadarko Petroleum Corporation (22 %) P.O. Box 100360 P.O. Box 1330 Anchorage, Alaska 99510 Houston, Texas 77251 Street City, State, Zip Code 2. This application/offer /lease is for Public Domain Lands in the National Petroleum Reserve - Alaska (NPR -A) Legal description of land requested: *Tract No.: 991 -L- 275.. *Sale Date (m/d/y): May / 05 / 1999 • *SEE INSTRUCTIONS BELOW PRIOR TO COMPLETING PARCEL NUMBER AND SALE DATE T. R. Meridian State County • T16N, RIOW Umiat Portion S r/z (Sections 24 -26, 33 -36) and Portion N 1 (Section 13) Total acres applied for 5,117 Amount remitted: Filing fee $ Rental fee $ 15,351.00 Total $ DO NOT WRITE BELOW THIS LINE 3. Land included in lease: T. R. Meridian State County T16N, RIOW Umiat • Portion S 1 /2 (Sections 24 -26, 33 -36) and Portion NV2 (Section 13) Total acres in lease 5,117 Rental retained $ 15,351.00 This lease is issued granting the exclusive right to drill for, mine, extract, remove and dispose of all the oil and gas (except helium) in the lands described in Item 3 together with the right to build and maintain necessary improvements thereupon for the term indicated below, subject to renewal or extension in accordance with the appropriate leasing authority. Rights granted are subject to applicable laws, the terms, conditions, and attached stipulations of this lease, the Secretary of the Interior's regulations and formal orders in effect as of lease issuance, and to regulations and formal orders hereafter promulgated when not inconsistent with lease rights granted or specific provisions of this lease. NOTE: This lease is issued to the high bidder pursuant to his/her duly executed bid or nomination form submitted under 43 CFR Part 3130 and is subject to the provisions of that bid or nomination and those specified on this form The parties agree (1) that this lease form replaces the previous lease form executed by the parties for this lease; (2) that this lease will be deemed to have been issued pursuant to this lease foram; (3) that this lease will be deemed to have been executed as of the original date each party executed the previous lease form; and (4) that time effective date of this lease is September 1, 1999. THE UNITED STATES OF AMERICA Type and primary term of lease: by [ 1 Noncompetitive lease (ten years) [ 1 Competitive lease (ten years) [ X1 Other Competitive NPR -A Lease (ten years) 1 , (Signing Officer) Sr. Leasable Minerals Adjudicator ' ° 1 7 MOO (Title) (Date) EFFbCTIVE DATE OF LEASE September 1, 1999 AK- 3130 -1 (April 1999) 4' (a) Unle,sig!ed certifies that (1) offeror is a citizen of the r` ates; an association of such citizens; a municipality; or a corm ganized under the laws of the United States or of any State or 'herritory thereof; (2) all parties holding an interest in the offe npliance with 43 CFR Part 3100 and the leasing authorities' r is not considered a minor under the laws of the State in which di re lands covered by this offer are located. (b) Undersigned agrees that signature to this offer const...s acceptance of this lease, including all terms, conditions, and stipu...uons of which offeror has been given n rtide, and any amendment or separate lease that may include any land described in this offer open to leasing at the time this offer was filed but omitted for any reason from this lease. The offeror further es that,Ilkityffer cannot be withdrawn, either in whole or in part. This offer will be rejected and will afford offeror no priority if it is not properly completed and executed in accordance with the regulations, or if it is not accompanied by.: requtt d"ayments. 18 U.S.C. Sec. 1001 makes it a crime for any person knowingly and willfully to make to any Department or agency of the United States any false, fictitious or fraudulent statemt�als or Itp'iteie tations as to any matter within its jurisdiction. cn y 1 „a'i'ry. NOTICE r The Privacy Act of 1974 and the regulations at 43 CFR 2.48(d) provide that you be furnished with the following information: , C , ' AUTHORITY: 50 Stat. 900; 25 U.S.C. 500 737 j PRINCIPAL PURPOSE: The primary uses of the records are (1) to determine your qualification to receive an oil and gas lease; and (2) to provide information concerning oil and gas leases for administrative and public use. ROUTINE USES: BLM and the Department of the Interior (DOI) may disclose your information on this form: (1) to members of the public who have a need for the information that is maintained by BLM for public record; (2) to the U.S. Department of Justice, court, or other adjudicative body when DOI determines the information is necessary and relevant to litigation; (3) to appropriate Federal, State, local or foreign agencies responsible for investigating, prosecuting violations, enforcing or implementing this statute, regulation, or lease; and (4) to a congressional office when you request the assistance of the Member of Congress in writing. EFFECT OF NOT PROVIDING THIS INFORMATION: If you do not furnish all the information required by this form, your application may be rejected. Duly executed this day of ,19 SEE ATTACHED SIGNATORY PAGE(S) (Signature of Lessee or Attorney -in -fact) LEASE TERMS Sec. 1. Rentals - Rentals shall be paid to the proper office of lessor in advance of each lease year. Annual rental Sec. 5. Documents, evidence, and inspection - Lessee shall file with proper office of lessor, not later than 30 days after rates per acre or fraction thereof are: effective date thereof, any contract or evidence of other arrangement for sale or disposal of production. At such times and in such form as lessor may prescribe, lessee shall furnish detailed statements showing amounts and (a) Noncompetitive lease, $1.50 for the first 5 years; thereafter $2.00; quality of all products removed and sold, proceeds therefrom, and amount used for production purposes or unavoidably lost. Lessee may be required to provide plats and schematic diagrams showing development work and improvements, (b) Competitive lease, $1.50; for the first 5 years; thereafter $2.00; and reports with respect to parties in interest, expenditures, and depreciation costs. In the form prescribed by lessor, (c) Other, see attachment; or for NPR -A: $5 for Area A; $3 for Area B; lessee shall keep a daily drilling record, a log, information on well surveys and tests, and a record of subsurface as specified in the detailed statement of sale. investigations and furnishcopies to lessor when required. Lessee shall keep open at all reasonable times for inspection by any authorized officer of lessor, the leased premises and all wells, improvements, machinery, and fixtures thereon, If this lease or a portion thereof is committed to an approved cooperative or unit pima which includes a well and all books, accounts, traps, and records relative to operations, surveys, or investigations on or in the leased lands. capable of producing leased resources, and the plan contains a provision for allocation of production, royalties shall Lessee shall maintain copies of all contracts, sales agreements, accounting records, and documentation such as billings, be paid on the production allocated to this lease. However, annual rentals shall continue to be due at the rate invoices, or similar documentation that support costs claimed as manufacturing, preparation, and/or transportation costs. All such records shall be maintained in lessee's accounting office for future audit by lessor. Lessee shall specified in (a), (b), or (c) for those lands not within a participating area. maintain required records for 6 years after they are generated or, if an audit or investigation is underway, until released of the obligation to maintain such records by lessor. Failure to pay annual rental, within 30 days after receipt of a Notice of Delinquency shall cause this lease to terminate. Rentals may be waived, reduced, or suspended by the Secretary upon a sufficient showing by lessee. During existence of this lease, information obtained under this section shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552). Sec. 2. Royalties - Royalties shall be paid to proper office of lessor. Royalties shall be computed in accordance with regulations on production removed or sold. Royalty rules are: Sec. 6. Conduct of operations - Lessee shall conduct operation in a manner that minimizes adverse impacts to the land, air, and water, to cultural, biological, visual, and other resources, and to other land uses or users. Lessee shall take (a) Noncompetitive lease, 121/2%; reasonable measures deemed necessary by lessor to accomplish the intent of this section. To the extent (b) Competitive lease, 121/2%; consistent with lease rights granted, such measures may include, but are not limited to, modification to siting or design (c) Other, see attachment, or for NPR -A: 161/2% for Area A; 12.5% for Area B of facilities, timing of operations, and specification of interim and final reclamation measures. Lessor as specified in the detailed statement of sale. reserves the right to continue existing uses and to authorize future uses upon or in the leased lands, including the approval of easements or rights -of -way. Such uses shall be conditioned so as to prevent unnecessary or Lessor reserves the right to specify whether royalty is to be paid in value or in kind, and the right to establish unreasonable interference with rights of lessee. reasonable in mum values on products after giving lessee notice and an opportunity to be heard. When paid in value, royalties shall be due and payable on the last day of the month following the month in which production Prior to disturbing the surface of the leased lands, lessee shall contact lessor to be apprised of procedures to be occurred: When paid in kind production shall be delivered, unless otherwise agreed to by lessor, in merchantable followed and modifications or reclamation measures that may be necessary. Areas to be disturbed may require condition on the premises where produced without cost to lessor. Lessee shall not be required to hold such inventories or special studies to determine the extent of impacts to other resources. Lessee may be required to production in storage beyond the last day of the month following the month in which production occurred, nor shall complete minor inventories or short term special studies under guidelines provided by lessor. If in the conduct of lessee be held liable for loss or destruction of royalty oil or other products in storage from causes beyond the operations, threatened or endangered species, objects of historic or scientific interest, or substantial unanticipated reasonable control of the lessee. environmental effects are observed, lessee shall immediately contact lessor. Lessee shall cease any operations that would result in the destruction of such species or objects. Minimum royalty in lieu of rental of not less than the rental which otherwise would be required for that lease year shall be payable at the end of each lease year beginning on or after a discovery in paying quantities. This minimum Sec. 7. Mining operations - To the extent that impacts from mining operations would be substantially different or royalty may be waived, suspended, or reduced, and the above royalty rates may be reduced, for all or portions of this greater than those associated with normal drilling operations, lessor reserves the right to deny approval of such lease if the Secretary determines that such action is necessary to encourage the greatest ultimate recovery of the operations. leased resources, or is otherwise justified. Sec. 8. Extraction of helium- Lessor reserves the option of extracting or having extracted helium fromgas production An interest charge shall be assessed on late royalty payments or underpayments in accordance with the Federal Oil in a manner specified and by means provided by lessor at no expense or loss to lessee or owner of the gas. Lessee shall and Gas Royalty Management Act of 1982 (FOGRMA) (30 U.S.C. 1701). Lessee shall be liable for royalty include in any contract of sale of gas the provisions of this section payments on oil and gas lost or wasted from a lease site when such loss or waste is due to negligence on the part of the operator, or due to the failure to comply with any rules, regulations, order, or citation issued under FOGRMA Sec. 9. Damages to property - Lessee shall pay lessor for damage to lessor's improvements, and shall save and hold or the leasing authority. lessor harmless from all claims for damage or harm to persons or property as a result of lease operations. Sec. 3. Bonds - A bond shall be filed and maintained for lease operations as required under regulations. Sec. 10. Protection of diverse interests and equal opportunity - Lessee shall pay when due all taxes legally assessed and levied under laws of the State or the United States; accord all employees complete freedom of Sec. 4. Diligence, rate of development, unitization, and drainage - Lessee shall exercise reasonable diligence in purchase; pay all wages at least twice each month in lawful money of the United States, maintain a safe working developing and producing, and shall prevent unnecessary damage to, loss of, or waste of leased resources. Lessor environment in accordance with standard industry practices; and take measures necessary to protect the health and reserves the right to specify rates of development and production in the public interest and to require lessee to safety of the public. subscribe to a cooperative or unit plan, within 30 days of notice, if deemed necessary for proper development and operation of area, field, or pool embracing these leased lands. Lessee shall drill and produce wells necessary to protect leased lands from drainage or pay compensatory royalty for drainage in amount determined by lessor. • . eserves the right to ensure that production is sold at reasons! . to prevent monopoly. If lessee Sec.12. Delivery of pram . time as all or poninns of this lease are returned to lessor, lessee shall place a pipeline, or owns controlling interest in a pipeline or a ee .g operating a pipeline, which may be affected wells in conditioi.= suspension or abandonment, reclaim the and as specified by lessor and, within a accessible to oil derived from these leased lands, lessee shall comply with section 28 of the Mmerai reasonable period of time, remove equipment and improvements not deemed necessary by lessor for preservation of let of 1920. producible wells. shall comply with Executive Order No, 1 1246 of September 24, 1965, as amended, and regulations and Sec, 13. Proceedings in ease of default - If lessee fails to comply with any provisions of this lease, and the orders of the Secretary of Labor issued pursuant thereto. Neither lessee nor lessee's subcontractors shall noncompliance continues for 30 days after written notice thereof, this lease shall be subject to cancellation unless n segregated facilities. During the performance of this lease, the Lessee must comply fully with paragraphs or until the leasehold contains a well capable of production of oil and gas in paying quantities, or the lease is nigh (7) of 41 CFR 60- 1.4(a) with respect to employment discrimination on the basis of race, color, religion, committed to an approved cooperative or unit plan or corrnnunitization agreement which contains a well capable national origin, and must incorporate the requirements set forth in those paragraphs m every subcontract of production of unitized substances in paying quantities. This provision shall not be construed to prevent the chase order, as provided by that regulation, exercise by lessor of any other legal and equitable remedy, including waiver of the default. As such remedy of waiver shall prevent later cancellation for the same default occurring at any other time. Lessee shall be subject 11. Transfer of lease interests and relmquishment of lease • As required by regulations, lessee shall file with to applicable provisions and penalties of FOGRMA (30 U.S.C. 1701). r any assignment or other transfer of an interest in this lease. Lessee may relinquish this lease or any legal .vision by filing in the proper office a written relinquishment, which shall be effective as of the date of filing, Sec. 14. Heirs and successors -in- interest - Each obligation of this lease shall extend to and be binding upon, ect to the continued obligation of the lessee and surety to pay all accrued rentals and royalties. and every benefit hereof shall inure to, the heirs, executors, administrators, successors, beneficiaries, or assignees of the respective parties hereto. 'lam INSTRUCTIONS r+ Gp A. General rri (i7 1. The front of this form is to be completed only by parties filing for a noncompetitive lease. The BLM will complete front of form for all other types of leases. )�, } t1 2. Entries must be typed or printed plainly in ink. Offeror must sign Item 4 in ink. 3. An original and two copies of this offer must be prepared and filed in the proper BLM State Office. See regulations at 43 CFR 1821.2 -1 for office locations. 4. If more space is needed, additional sheets must be attached to each copy of the form submitted. B. Special: Item 1 - Enter offeror's name and billing address. Item 2 - A single tract number and Sale Date shall be the only acceptable description. Item 3 - This space will be completed by the United States. PAPERWORK REDUCTION ACT STATEMENT The Paperwork Reduction Act of 1990 (44 U.S.C. 3501 et seq.) requires us to inform you that: 1. This information is being collected pursuant to the law. 2. This information will be used to create and maintain a record of oil and gas lease activity. 3. Response to this request is required to obtain a benefit. EFFECT OF NOT PROVIDING INFORMATION - If all the information is not provided, the offer may be rejected. See regulations at 43 CFR 3130. • AK- 3130 -1 (April ? • C > Mr SPECIAL STIPULATION(S) FOR LEASE AA- 081854, o rn ; "Il Standard Lease Stipulation Numbers 1 -24, 26 -28, 30, 32, 34 -38, 40 -44, 46 -48, 51, 53, 55 -79, as identified and delineated in the Final Record of Decision and Detailed Statement of Sale, pertain to all leases created from the National Petroleum Reserve- Alaska Sale 991, and are herein incorporated by reference and made a part of this lease. The following Special Stipulation(s) is /are specifically delineated in the Record of Decision and Detailed Statement of Sale as pertaining to this tract, and is /are hereby made a part of this lease. This /these is /are a direct quote(s) from the Detailed Statement of Sale document. All references to Exhibit A pertain to Exhibit A of the Detailed Statement of Sale. No part of this lease is identified as Exhibit A.: I. The "Special Caribou Stipulations," Numbers 25, 29, 33, 49 -50, 52, 54, are identified on each specific tract in Exhibit A hereof. They pertain to some of the tracts in both Area A and Area B. III. The "No Permanent Oil and Gas Facilities" and "No Permanent Oil and Gas Facilities within 1/4 mile of Fish - Bearing Lakes Stipulations," Number 39, are identified on each specific tract in Exhibit A hereof. They pertain to some of the tracts in both Area A and Area B. V. Sensitive Area Consultation Required. • • • SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA- 0 8/2557 C ARCO ALASKA, INC. ' : -,M cno March 9, 2000 Lessee's Signat . e Date st James M. ' ud Attomey -in -Fact ARCO Alaska, Inc. Lessee's Name (Print or Type) & Title Company Name THE IGNITED STATES OF AMERICA ) ) ss. STATE OF ALASKA ) This certifies that on the 9th day of March, 2000, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared James M. Ruud, to me known and known to me to be the . person described in, and who executed the foregoing lease, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. o m " " '11614 d' Public Notary (Pu uuublic -z-7= �� My Commission expires: 6 -8 -2003 2003 . ... • SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA- 08/� - ANADARKO PETROLEUM CORPORATION c l 70 :Act 1 /'/ .. _ ` March 7, 2000 = ,°r Lessee's Signat T= Date co ^+ Todd L. Liebl ; r Agent and Attorney -in -Fact Anadarko Petroleum Corporation Lessee's Name (Print or Type) & Title Company Name THE UNITED STATES OF AMERICA ) ) ss. STATE OF ALASKA ) This if ia. 'oh the 7th day of March, 2000, before me, a notary public in and for ine State of Alaska, duly commissioned and sworn, personally appeared Todd L. Liebl, to me known and known to me to be the person described in, and who executed the foregoing lease, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein. mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. q , �p�' �� h 11' z ` l (i t ` g r A/ . s �e °` \581011 `"t ,, . ° s ' '. � "F-�' / + _47'14__ INIAN My Commission expires:June 8, 2003 l "jfef 4 : r if -E 9 S V. 4 .� : is'5� 4�i11iIk. + . 1 FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS 333 W. 7"' AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Paul Mazzolini Exploration Team Leader ConocoPhillips Alaska Inc. P O Box 100360 Anchorage, AK 99510 Re: Application for Sundry Approval for Puviaq #1 (202 -248 / 30A-116) Request for extension of Temporary Shutdown status Dear Mr. Mazzolini: On March 28, 2006, ConocoPhillips Alaska Inc. ( "ConocoPhillips) submitted an Application for Sundry Approval to the Alaska Oil and Gas Conservation Commission ( "Commission ") requesting an extension of Temporary Shutdown status for exploratory well Puviaq #1 until July 8, 2008. The application is denied pending demonstration by ConocoPhillips that the criterion of Paragraph (d) of Commission Regulation 20 AAC 25.072 applies. Paragraph (d) of Commission Regulation 20 AAC 25.072 states: "If well operations are not resumed within 12 months, the operator shall immediately proceed to abandon or suspend the well. Upon application of the operator, the commission will extend the 12 -month period, if the operator shows that operational circumstances beyond the operator's control prevent resumption within the 12 -month period." The Commission first granted Puviaq #1 Temporary Operational Shutdown status on April 16, 2003, as recorded on Sundry Application 300 -116. The Commission extended the Temporary Shutdown status on January 18, 2005. ConocoPhillips' justification for continued Temporary Operational Shutdown status does not appear to meet the criterion that circumstances beyond the operator's control prevent resumption of operations in this well. Accordingly, ConocoPhillips' request for continued Temporary Operational Shutdown status for Puviaq #1 is hereby DENIED. The status of this well will be changed to Suspended, effective April 1, 2006. However, the Commission will reconsider the Puviaq #1 Page 2 of 2 Request for Extension of Temporary Shutdown • April 14, 2006 application, if ConocoPhillips is able to demonstrate that the criterion of Paragraph (d) of Commission Regulation 20 AAC 25.072 applies. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Cow ) nless reconsideration has been requested. 1 O E :i Anc r o ge, Alaska and dated April 14, 2006. or lerman I an T. Seamount, Jr. Cat P. oerster Chairman Commissioner Commissioner If ' 0 • RECEIVED STATE OF ALASKA MAR 2 8 2006 A LASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVA ska Oil & Gas Cono.. Commission 20 AAC 25.280 Anchorztio 1. Type of Request: Abandon ❑ Suspend 111 Operational shutdown ❑ Perforate ❑ Waiver ❑ Annular Dispos.❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension 0 Other ❑ Change approved program ❑ Put Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Explora --' El 202 -248 / 303 -116 3. Address: Stratigraphic ❑ Se ce ❑ 6. API Number: P. O. Box 100360, Anchorage, AK 99510 50 - 279 - 20008 - 7. KB Elevation (ft): 9. Well Na e and Number: 30' RKB & 28' MSL Puviaq 1 8. Property Designation: 10. Field /Pools(s): AA081854 / L32589 Exploration 11. PRESENT WELL r ONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): (Effective Depth MD (ft): Effective Depth • (ft): I Plugs (measured) (Junk (measured): 7900' 7900' 6141' 61- ° Casing Length Size ■ D TVD Burst Collapse Structural Conductor 82' 202 112' 112' Surface 1393' 0.375" 6 1423' 1423' � I Intermediate 3137' \625" '167' 3167' Production 7861' 7" 7:91' 7891' Production � \ Liner ( Perforation Depth MD (ft): P orati. I -pth TV (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A ' • 3.5" L -80 6150' Packers and SSSV Type: an' S SV MD (ft): FB -1 and SAB -3 pkrs, no SSSV / pkr @ 6725' and 5940' 12. Attachments: Description Summary of Proposal ❑ 11. Well ■ = er proposed work: Detailed Operations Program ❑ BOP etch ❑ Ex•lorato 0 Development ❑ Service ❑ 14. Estimated Date for / 15. el -tatus after proposed work: Commencing Operations: 2/1, Oil ❑ Gas ❑ Plugged El Abandoned ❑ 16. Verbal Approval: D ,te: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 17. I hereby certify that the foregoing is true - d ••rrect to the best of my knowledge. Contact Tom Brassfield 265 Printed Name P. Mazzolini Title Exploration Drilling Team Leader Signature 7 _/T , ., Phone 263 -4603 Date °3/2.7 ! mod 4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -_:= t $ BFI: NOV 2 8 2007 Subsequent Form Required: BY ORDER OF Approved by: COMMISSIONER THE COMMISSION Date: /fir 3.3/• 04 R Form 10 -403 Revised 12/2003 1 \ 1 blsW:skiLs ON REVERSE Sub i nipato Paul Mazzolini • it Exploration Team Leader Drilling & Wells • ' M P. 0. Box 100360 11P►'- Anchorage, AK 99510 -0360 C onocoPhullips Phone: 907 - 263 -4603 March 27, 2006 John K. Norman, Chairman State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for Puviaq #1 (202 -248 / 303 -116) Request for extension of Temporary Shutdown status ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to request an extension of Temporary Shutdown status for the exploration well Puviaq #1. The Puviaq #1 well was temporarily shutdown on April 15, 2003. Circumstances prevented the completion of the program approved on the Permit to Drill for the Puviaq #1 well dated January 6, 2003, and operational shutdown was approved by the AOGCC on April 16, 2003. On January 28, 2005, the AOGCC extended the Temporary Shutdown status to April 1, 2006. Due to the remote location of the Puviaq #1 well, the limitations on mobilization and demobilization of a rig to the site, and the resulting limited drilling season, ConocoPhillips Alaska, Inc. ( "CPAI ") will not return to the Puviaq #1 well location in 2006. CPAI continues to analyze construction of a "fit for purpose" rig specifically designed to allow timely and efficient access to and work at remote locations such as the Puviaq #1 well location. The construction of the "fit for purpose" rig may allow CPAI to work at the Puviaq #1 well during the winter drilling season of 2007 or 2008. Therefore, pursuant to 20 AAC 25.072, CPAI, as operator of the Puviaq #1 well, hereby requests an extension of the Temporary Shutdown status of the Puviaq #1 well until July 1, 2008. If you have any questions regarding this matter, please contact me at 263 -4603. rVe, it ,- - P. Mazzolini Exploration Team Leader CPAI Drilling PM /skad • • Paul Mazzolini Exploration Team Leader Drilling & Wells rip • P. O. IPAV AnchoraBox ge, AK 100360 99510 -0360 6nocoPhilI ps Phone: 907 - 263 -4603 March 27, 2006 John K. Norman, Chairman State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for Puviaq #1 (202 -248 / 303 -116) Request for extension of Temporary Shutdown status ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to request an extension of Temporary Shutdown status for the exploration well Puviaq #1. The Puviaq #1 well was temporarily shutdown on April 15, 2003. Circumstances prevented the completion of the program approved on the Permit to Drill for the Puviaq #1 well dated January 6, 2003, and operational shutdown was approved by the AOGCC on April 16, 2003. On January 28, 2005, the AOGCC extended the Temporary Shutdown status to April 1, 2006. Due to the remote location of the Puviaq #1 well, the limitations on mobilization and demobilization of a rig to the site, and the resulting limited drilling season, ConocoPhillips Alaska, Inc. ( "CPAI ") will not return to the Puviaq #1 well location in 2006. CPAI continues to analyze construction of a "fit for purpose" rig specifically designed to allow timely and efficient access to and work at remote locations such as the Puviaq #1 well location. The construction of the "fit for purpose" rig may allow CPAI to work at the Puviaq #1 well during the winter drilling season of 2007 or 2008. Therefore, pursuant to 20 AAC 25.072, CPAI, as operator of the Puviaq #1 well, hereby requests an extension of the Temporary Shutdown status of the Puviaq #1 well until July 1, 2008. If you have any questions regarding this matter, please contact me at 263 -4603. " Pck-.41 P. Mazzolini Exploration Team Leader CPAI Drilling PM /skad • • 't Confidential NOTE to FILE Puviaq #1 PTD 204 -248 Sundry Application 306 -118 Request: CPAI is requesting a 1 -year extension of Temporary Shutdown Status for the referenced well. Recommendation: I recommend that the 1 -year extension be granted with the condition that CPAI develop a work plan to evaluate this well in the next winter drilling season. Performing such work will establish a completion date for the well and begin the 25- month confidentiality period. If CPAI fails to do the work, then I recommend that the well be considered suspended with an effective date of April 16, 2006. Discussion: Until this year, this well was one of the most distant recently drilled from established infrastructure and CPAI's representation of not having the required equipment was valid. As noted by my colleagues, FEX is presently drilling one well relatively close ( -15 miles) to Puviaq and it is likely that FEX will do additional work next winter drilling season. With other operations in the area, some economies of scale could be realized that would allow CPAI to evaluate Puviaq. It is uncertain whether a rig would be necessary to evaluate Puviaq. The well was drilled to TD, casing cemented and tubing and a packer installed. It would seem that the well is equipped to be flow tested without the need of a rotary rig. It would not make operational sense to have put the prospective interval above the packer and behind the tubing. CPAI has done "rigless" testing on other wells in NPRA and that would seem doable here. When time is running short in the season, the strategy has been to equip the wells so that evaluation and abandonment operations can be conducted without needing a rig. I agree with my colleagues that CPAI should not be allowed to "sit" on this unevaluated well. Although the determined information will remain confidential for some period, accomplishing the work will make the information available and fulfill the reason for drilling the well in the first place. If CPAI does not accomplish the work, adopting a suspended date of April 16, 2006 will honor the prior extensions of the operational shut -down. Adopting such a date will start the 25 -month confidentiality period giving a potential release date of May 16, 2008. Since there appears to be unleased acreage near the well, it is likely that CPAI will request extended confidentiality, however the well will not remain in the "limbo" status of the past 3 years. c9 -M't� Tom Maunder, PE Sr. Petroleum Engineer April 4, 2006 • • CONFIDENTIAL NOTE TO FILE Puviaq No. 1 PTD 204 -248 Sundry Application 306 -118 Request ConocoPhillips Alaska, Inc. (CPAI) requests a one -year extension of Temporary Shutdown Status for the referenced well. Recommendation Denying the one -year extension requested by CPAI is my preferred recommendation, but due to the sensitivity of the issue I could support granting the extension request this year. If CPAI's request is approved they should be informed that future extensions would not be granted unless they provide much stronger supporting rationale or future work commitments. Discussion The commission has the authority to grant temporary shutdown extensions under 20 AAC 25.072(d) "if the operator shows that operational circumstances beyond the operator's control prevent resumption within the 12 -month period." CPAI has not made a showing that circumstances beyond their control are preventing them from resuming work on the subject well. In their letter dated March 27, 2006, and submitted with the above referenced Sundry Application they state "Circumstances prevented the completion of the program approved on the Permit to Drill for the Puviaq #1 well... ". They did not attempt to make the claim that these circumstances were beyond their control, simply that there were circumstances. Later in the letter they state "CPAI continues to analyze construction of a "fit for purpose" rig specifically designed to allow timely and efficient access to and work at remote locations such as the Puviaq # 1 well location." CPAI has made no showing that the lack of a "fit for purpose" rig is a circumstance that is beyond their control, on the contrary it is a situation that would appear to be completely within their control, nor have they demonstrated that operations can not continue on the subject well in the absence of such a rig. CPAI should not be allowed to sit on this well indefinitely but should be encouraged to continue operations to properly evaluate this well. By denying this request CPAI may be spurred into action and the well data will become available to other operators sooner, which .y lead to increased bidding activity the next time this area is offered. David S. '.t'•y Reservoir Engineer April 3, 2006 • CONFIDENTIAL NOTE TO FILE Puviaq No. 1 PTD 2042480 Sundry Application 306 -118 Request ConocoPhillips Alaska, Inc. ( "CPAI") requests their third one -year extension of Temporary Shutdown status for Puviaq No. 1. Recommendation Grant the one -year extension again until April 1, 2007. That date will mark the end of the fourth year since Temporary Shutdown status was granted. If there is no progress toward continuing operations in the well by that date, strongly consider changing status of Puviaq No. 1 to suspended. Discussion This remote, exploratory well was drilled in the NPR -A, south of Smith Bay and Cape Simpson. Records for the well are kept locked in one of the cabinets within the confidential room as a courtesy to CPAI, which has expressed strong concern about proper security for this information. At the operator's request, the Commission granted Temporary Operational Shutdown status on April 16, 2003, as recorded on Sundry Application 303 -116. The well is secure. Temporary shutdown status does not start the clock on release of well data. As such, this status can be manipulated to hold data confidential for an indefinite period of time. Paragraph (d) of 20 AAC 25.072 states: "If well operations are not resumed within 12 months, the operator shall immediately proceed to abandon or suspend the well. Upon application of the operator, the commission will extend the 12 -month period, if the operator shows that operational circumstances beyond the operator's control prevent resumption within the 12 -month period." The Application for Sundry Approval (306 -118) and cover letter submitted March 28, 2006 by CPAI requesting extension of Temporary Shutdown status are essentially the same as submitted last year. The comments contained in the attached Note to File by Tom Maunder, written last year, are as applicable today as they were at that time. CPAI's rationale for not continuing operations in the well is: "Due to the remote location of the Puviaq #1 well, the limitations on mobilization and demobilization of a rig to the site, and the resulting limited drilling season..." However, FEX is now conducting ice -road supported drilling operations in the general area, expecting to finish one well and possibly spudding a second well this winter (see Petroleum News, March 5, 2006). CPAI's assertion that continued work on Puviaq 1 cannot be accomplished doesn't appear to meet the criteria "operational circumstances beyond the operator's control prevent resumption within the 12 -month period." It is in the best interest of the State of Alaska and the Federal Government that operations continue in this well. I recommend one more extension of Temporary Shutdown status to allow proper planning of continued operations, and then at this time next year, require the operator to either resume operations wi in 12 months or change the well status to suspended. Steve Davies Petroleum Geologist • • CONFIDENTIAL NOTE TO FILE Puviaq #1 PTD 204 -248 Sundry 305 -015 ConocoPhillips Alaska (CPAI) drilled this well in late 1 quarter 2003. The well reached TD and a long string was set and cemented in early April. With the available drilling season ending and the need to remove the drilling rig, CPAI requested an operational shutdown (OSD) via sundry (303 -116). The sundry was approved April 16, 2003. In compliance with the regulations, CPAI submitted Form 404 on May 22, 2003 including a daily summary of operations, logs (electric line and mud), core data and annular disposal information. I have reviewed the well fife and find that the submitted information is complete and the CPAI has complied with the information submittal requirements for a well in OSD. CPAI's current application is somewhat delinquent since it is submitted nearly 2 years after OSD was originally approved. 20 AAC 25.072 (d) specifies that if well operations are not resumed within 12 months that the operator shall immediately proceed to abandon or suspend the well. The regulation allows and extension of 12 months if it is demonstrated that circumstances beyond the operator's control prevented resumption of operations. It is possible to consider the well suspended, however wells considered suspended usually have been perforated or plugged back. This is not the case with this well. Puviaq is the most distant exploration well recently drilled in NPRA. In order to accomplish the project CPAI staged the rig on an icepad near the location at the end of the 2002 - drilling season. Following the successful drilling of the well, the rig was demobed from the area. Due to the long distance from infrastructure and limited equipment choices CPAI has not been able to return to the well to resume operations. Their latest application states that operations in 2006 might be possible pending construction of a "fit- for - purpose" rig. At this time, the actual wellbore is secure. The last casing string was cemented as planned, there are no perforations and the tubing, IA and OA have been freeze protected. The tubing and IA were successfully pressure tested prior to rig release. I recommend approval of CPAI's request. This well is the only penetration for many miles and is considered a rank wildcat. Evaluation of the potential of the well is not presently possible and it is in the state's best interest that such evaluation occurs. CPAI has indicated that they are working on options to allow such evaluation and it is possible that they may be able to re -enter the well next year. 4 b-m4 41/V ?txxx/v41? Tom Maunder, PE Sr. Petroleum Engineer 1 • • (2) "velocity survey" means a survey, the primary purpose of which is to determine velocity of seismic waves through formations penetrated by a well by measuring travel times of seismic pulses from or near the surface to geophones placed at various depths in the well. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 AS 31.05.035 20 AAC 25.072 TEMPORARY SHUTDOWN OF DRILLING OR COMPLETION OPERATIONS. (a) If circumstances prevent the continuation of the program approved on a Permit to Drill (Form 10 -401), or if an operator wishes to change drill rigs, the operator shall apply to the commission for approval to shut down drilling or completion operations temporarily. Based on the information received under this subsection, the commission will decide whether to approve the temporary shutdown of drilling or completion operations. The request for operation shutdown must be submitted on an Application fnr Sundry Approvals (Form 10 -403), providing a full justification for the shutdown, a description of the proposed condition of the wellbore upon shutdown of drilling or completion operations, the approximate date when drilling or completion operations will resume, and a proposed program for securing the well during the period of shutdown. An Application for Sundry Approvals is not required for planned shutdowns of well operations, if those shutdowns are described in the approved Permit to Drill. (b) The operator shall file with the commission, within 30 days after operation shutdown, a complete well record on a Report of Sundry Well Operations (Form 10 -404), including a summary of daily well operations as described in 20 AAC 25.070 (3) and a copy of all logs run in the well as required by 20 AAC 25.071 (b)(6). The commission will, in its discretion, waive the requirements of this subsection if drilling or completion operations are to be resumed within 60 days after operation shutdown. (c) Shutdown of well operations does not establish a completion, suspension, or abandonment date for a well. (d) If well operations are not resumed within 12 months, the operator shall immediately proceed to abandon or suspend the well. Upon application of the operator, the commission will extend the 12 -month period, if the operator shows that operational circumstances beyond the operator's control prevent resumption within the 12 -month period. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 \ J 5 — c IS S Pkalli)( L 1, 5 0 (Q 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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory CI 7. Well Name: Puviaq #1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAGE 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008-00 3. (Check one box only) 5a. Sundry Number 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final CI 303 -102 3/26/2003 Exploration 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 totals (bbls): 2003 / 2nd 4631 100 0 4731 7 3/25/2003 3/31/2003 Puviaq #1 2003 / 3rd 5063 100 0 5163 20 4/1/2003 4/20/2003 Puviaq #1 2003 / 4th 0 0 0 0 2004 / 1st 0 0 0 0 IP Total Ending Report is due on the 20th Volume 9694 200 0 9894 27 (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): I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: `��— , �---, Date: '1// G /o `/ Printed Name: ` � C --, -, ` S Title: ' c , k l , k l— _,.A C ; Phone Number: Lt. S 6S 5 0 Form 10 -423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • /IV\ 11 LI\ - v'\ /11 n 711, rc? s Tuff Tr s I 9 , 'a FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS 333 W. 7"' AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 4 a Paul Mazzolini Exploration Drilling Team Leader ConocoPhillips Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 Re: Puviaq #1 Sundry Number: 305 -015 Dear Mr. Mazzolini: 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. Please provide at least twenty -four (24) hours 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 • . is ay or weekend. A person may not appeal a Commission decision to Su.erior r ess rehearing has been requested. . Norm. a i DATED this day of January, 2005 Encl. • Paul Mazzolini Exploration Team Leader Drilling & Wells P. 0. Box NOV Anchchorage, , AK AK 99510-0360 ConocoPhillips Phone: 907 - 263 -4603 January 24, 2005 REC D Commissioner I State of Alaska r a ` 005 Alaska Oil & Gas Conservation Commission JAN 4� < 333 West 7 Avenue Suite 100,,sl� tlil �� Anchorage, Alaska 99501�s Subject: Application for Sundry Approval for Puviaq #1 (202 -248 / 303 -116) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to request an extension of Temporary Shutdown status for the exploration well Puviaq #1. The Puviaq #1 well was temporarily shutdown on April 15, 2003. Circumstances prevented the completion of the program approved on the Permit to Drill for the Puviaq #1 well dated January 6, 2003, and operational shutdown was approved by the AOGCC on April 16, 2003. The remote location of the Puviaq #1 well, the limitations on mobilization and demobilization of a rig to the site, and the limited drilling season have prevented ConocoPhillips Alaska, Inc. ( "CPAI ") from returning to the Puviaq #1 well location. CPAI is currently evaluating the possibility of constructing a "fit for purpose" rig specifically designed to reach remote locations such as the Puviaq #1 well location. The construction of the "fit for purpose" rig may allow CPAI to re -visit the Puviaq #1 well during the first quarter of 2006. Therefore, pursuant to 20 AAC 25.072, CPAI, as operator of the Puviaq #1 well, hereby requests an extension of the temporary shutdown status of the Puviaq #1 well until April 1, 2006. If you have any questions regarding this matter, please contact me at 263 -4603 or Tom Brassfield at 265 -6377. Sincerely, P. Mazzolini Exploration Team Leader CPAI Drilling `� 0R N!AL ..: . , - • 0 STATE OF ALASKA 2 7-c3°5 1 ALASKA OIL AND GAS CONSERVATION COMMISSION �' ti APPLICATION FOR SUNDRY APPRO`` - 7'" ` ` 20 AAC 25.280 ���jj S ;ll44LL J aryjt, 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver ❑ Annular Dispos.❑ Alter casing Repair well ❑ Plug Perforations 0 Other III g p g ❑ Stimulate ❑ Time Extension Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory El 202 -248 / 303 -116 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, AK 99510 50 279 - 20008 - 00 7. KB Elevation (ft): 9. Well Name and Number: 30' RKB & 28' MSL Puviaq 1 8. Property Designation: 10. Field /Pools(s): AA081854 / L32589 Exploration 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): 7900' 7900' 6141' 6141' Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 112' 112' Surface 1393' 13.375" 1423' 1423' Intermediate 3137' 9.625" 3167' 3167' Production 7861' 7" 7891' 7891' Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3.5" L -80 6150' Packers and SSSV Type: Packers and SSSV MD (ft): FB -1 and SAB -3 pkrs, no SSSV pkr @ 6725' and 5940' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/1/2005 Oil ❑ Gas ❑ Plugged 0 Abandoned ❑ 16. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield 265 - 6377 Printed Name P. Mazzolini Title Exploration Drilling Team Leader Signature (— Pc ,Q_ cifie ,e2__L, Phone 263 - 4603 Date o ///4 /2.0e> 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ` PBDNIS BFI.. AN 3 1 2005 Other: Ajoip t O V G k '" ` t .. -- � � L\ I% — d G Subsequ -- -. q ' - -. , ►, • ki Ic b csx 4 - toe , Vr QccAtov.. Q l�ka p c S lreQoc a0o3 1aoo / oRiGhlAL B Y ORDER OF Approved by COMMISSIONER THE COMMISSION Date:/ Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in uplicate • 1 CONFIDENTIAL NOTE TO FILE Puviaq #1 PTD 204 -248 Sundry 305 -015 ConocoPhillips Alaska (CPAI) drilled this well in late 1 quarter 2003. The well reached TD and a long string was set and cemented in early April. With the available drilling season ending and the need to remove the drilling rig, CPAI requested an operational shutdown (OSD) via sundry (303 -116). The sundry was approved April 16, 2003. In compliance with the regulations, CPAI submitted Form 404 on May 22, 2003 including a daily summary of operations, logs (electric line and mud), core data and annular disposal information. I have reviewed the well file and find that the submitted information is complete and the CPAI has complied with the information submittal requirements for a well in OSD. CPAI's current application is somewhat delinquent since it is submitted nearly 2 years after OSD was originally approved. 20 AAC 25.072 (d) specifies that if well operations are not resumed within 12 months that the operator shall immediately proceed to abandon or suspend the well. The regulation allows and extension of 12 months if it is demonstrated that circumstances beyond the operator's control prevented resumption of operations. It is possible to consider the well suspended, however wells considered suspended usually have been perforated or plugged back. This is not the case with this well. Puviaq is the most distant exploration well recently drilled in NPRA. In order to accomplish the project CPAI staged the rig on an icepad near the location at the end of the 2002 - drilling season. Following the successful drilling of the well, the rig was demobed from the area. Due to the long distance from infrastructure and limited equipment choices CPAI has not been able to return to the well to resume operations. Their latest application states that operations in 2006 might be possible pending construction of a "fit- for - purpose" rig. At this time, the actual wellbore is secure. The last casing string was cemented as planned, there are no perforations and the tubing, IA and OA have been freeze protected. The tubing and IA were successfully pressure tested prior to rig release. I recommend approval of CPAI's request. This well is the only penetration for many miles and is considered a rank wildcat. Evaluation of the potential of the well is not presently possible and it is in the state's best interest that such evaluation occurs. CPAI has indicated that they are working on options to allow such evaluation and it is possible that they may be able to re -enter the well next year. 4a' Tom Maunder, PE Sr. Petroleum Engineer 1 (2) "velocity survey" means a survey, the primary purpose of which is to determine velocity of seismic waves through formations penetrated by a well by measuring travel times of seismic pulses from or near the surface to geophones placed at various depths in the well. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 AS 31.05.035 20 AAC 25.072 TEMPORARY SHUTDOWN OF DRILLING OR COMPLETION OPERATIONS. (a) If circumstances prevent the continuation of the program approved on a Permit to Drill (Form 10 -401), or if an operator wishes to change drill rigs, the operator shall apply to the commission for approval to shut down drilling or completion operations temporarily. Based on the information received under this subsection, the commission will decide whether to approve the temporary shutdown of drilling or completion operations. The request for operation shutdown must be submitted on an Application fnr Sundry Approvals (Form 10 -403), providing a full justification for the shutdown, a description of the proposed condition of the wellbore upon shutdown of drilling or completion operations, the approximate date when drilling or completion operations will resume, and a proposed program for securing the well during the period of shutdown. An Application for Sundry Approvals is not required for planned shutdowns of well operations, if those shutdowns are described in the approved Permit to Drill. (b) The operator shall file with the commission, within 30 days after operation shutdown, a complete well record on a Report of Sundry Well Operations (Form 10 -404), including a summary of daily well operations as described in 20 AAC 25.070 (3) and a copy of all logs run in the well as required by 20 AAC 25.071 (b)(6). The commission will, in its discretion, waive the requirements of this subsection if drilling or completion operations are to be resumed within 60 days after operation shutdown. (c) Shutdown of well operations does not establish a completion, suspension, or abandonment date for a well. (d) If well operations are not resumed within 12 months, the operator shall immediately proceed to abandon or suspend the well. Upon application of the operator, the commission will extend the 12 -month period, if the operator shows that operational circumstances beyond the operator's control prevent resumption within the 12 -month period. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 y4 -© 5 LA `t Its - 0 ' 1 0C i Lk il 0 Cam, 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: 202 -248 ConocoPhillips Alaska, Inc. Development ❑ Exploratory El 7. Well Name: Puviaq #1 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAGE 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20008 -00 3. (Check one box only) 5a. Sundry Number 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation of Disposal 0 303 -102 3/26/2003 Exploration 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 totals (bbls): 2003 / 2nd 4631 100 0 4731 7 3/25/2003 3/31/2003 Puviaq #1 2003 / 3rd 5063 100 0 5163 20 4/1/2003 4/20/2003 Puviaq #1 2003 / 4th 0 0 0 0 2004 / 1st 0 0 0 0 III Total Ending Report is due on the 20th Volume 9694 200 0 9894 27 (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): I hereby certify that the foregoing is true and correct to the best of my knowledge. r- Signature: Illw _ — Date: \ ( (o Y Printed Name: \ -- , -- 4 } 1 ` ti ' ts- ■- S Title: c tJ -- V e.—...... L.-e-c..( Phone Number: 7 -6S 6 3 a Form 10 -423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate )■,_ • ‘.„) _ isk ConocoPhillips Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 -3539 Re: Confidential Data Well # 50 279 - 20008 - 00 Dear Commissioners: The data enclosed with this letter is proprietary, confidential data that is required by statute AS 31.05.035 to be held confidential by the Alaska Oil and Gas Conservation Commission ( "AOGCC "). Although all data submitted under the protection of AS 31.05.035 is important, the confidentiality of this data is of the utmost importance to ConocoPhillips Alaska, Inc. Due to the location of the well and the high cost of obtaining the data, any error or breach resulting in any disclosure would cause irreparable harm to ConocoPhillips' competitive position. We ask that the AOGCC give particular attention and sensitivity to the confidentiality procedures so that all possible care and diligence will be accorded the safekeeping and continuing confidentiality of this data. Please direct any question or inquiries to Greg Wilson (263 4748) or Andy Andreou (265 132). t ly yours, Af • .r • • . arrard cc: Sarah Palin, Lisa Weepie, Librarian, AOGCC RECEIVED MAY 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage 7‹, -t., c-- r b_ X9-8 Annular Disposal during the second quarter of 2003: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S -10 9972 100 0 10072 388 21204 31664 March April 3S -21, 3S -08, 3S -23 2003 2003 1C -22 21553 100 0 21653 0 27044 48697 March May 1C -190, 1C -174, 1C -178, 1C -19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 AO a -3.40 2003 2003 CD2 -46 31393 100 0 31493 371 0 31864 April May 2003 CD2 -51, CD2 -12 iii 2003 3S -16 31006 100 0 31106 357 0 31463 April May 2003 3S -23, 3S -17, 3S -06, 3S -16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen lA 2002 1C -19 31325 100 0 31425 0 0 31425 May 2003 June 2003 1C -184, 1C -170, 1C -172 3S -08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S -24, 3S -03, 3S -19 CD2 -19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2 -58, CD2 -52 CD2 -41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2 -20 3S -17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S -19 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date IIIP Well Name Volume _ Volume Volume Volume Status of Annulus _ CD2 -17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2 -08, CD2 -48, CD2 - 46 CD2 -32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2 -19, CD2 -41, CD2 - 23 CD2 -50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2 -41, CD2 -38 1D -11 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1D -103 1C -18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1C -104 f 0 • li ConocoPhilhi s p 1 1 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 -3539 Re: Confidential Data Well # 50- 279 - 20008 -00 Dear Commissioners: The data enclosed with this letter is proprietary, confidential data that is required by statute AS 31.05.035 to be held confidential by the Alaska Oil and Gas Conservation Commission ( "AOGCC "). Although all data submitted under the protection of AS 31.05.035 is important, the confidentiality of this data is of the utmost importance to ConocoPhillips Alaska, Inc. Due to the location of the well and the high cost of obtaining the data, any error or breach resulting in any disclosure would cause irreparable harm to ConocoPhillips' competitive position. We ask that the AOGCC give particular attention and sensitivity to the confidentiality procedures so that all possible care and diligence will be accorded the safekeeping and continuing confidentiality of this data. Please direct any question or inquiries to Greg Wilson (263 4748) or Andy Andreou (265 132). 4 ei t r, ly yours, 1 • • .s . .. arrard cc: Sarah Palin, Lisa Weepie, Librarian, AOGCC ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: A. Andreou, AT01312 TO: AOGCC ConocoPhillips Alaska, Inc. Mr. R. Crandall P.O. Box 100360 Anchorage AK 99510 -0360 RE: Puviaq 1 DATE: 05/23/03 Delivery: Hand carried Transmitted herewith is the followin:: Puviaq 9 cartons dried cuttings samples oNFfl 2 boxes core samples P hiiiips Alaska, Inc Please check off each item as received, sign and return one of the two transmittals enclosed to address below. "On behalf of itself and [Anadarko Petroleum Comapny], ConocoPhillips Alaska, Inc. submits the attached data for the Puviaq 1 Well. We request that this data be held confidential. CC: A. Andreou, G. Wilson Receipt: Date: _.c/ Z� 3 Return receipt to: Phillips Alaska, Inc. ATTN: A. Andreou ATO 1312 700 G. Street Prepared by: A. Andreou Anchorage, AK 99501 ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: A. Andreou, AT01312 TO: AOGCC ConocoPhillips Alaska, Inc. Mr. R. Crandall P.O. Box 100360 Anchorage AK 99510 -0360 RE: Puviaq 1. DATE: 05/23/03 Delivery: Hand carried p / Transmitted herewith is the followin ' : Puviaq c�� oof- ; rr�,4.t Go.c elP�5 o.1% A 1 Page containing Formation Tops 1 Paper Print CMR Log 1 Paper Print DSI Log � CONFIDENTIAL 1 Paper Print MDT Log 1 Paper Print VSP Log ConocoPhillips Alaska, Inc. 1 Paper Print FMI Log 1 Paper Print LWD GR -RES (2" : 100') � J , i , � 4 , ,f J 1 Paper Print LWD GR -RES (5" : 100') c: :� /��„/ ,.,- . < <, . ,z_ . , „ � �,,z;c (z 1 Paper Print LWD GR -RHOB -NPHI (2 ":100') f 'fN, `' 1 Paper Print LWD GR- RHOB -NPHI (5 ":100') �` " ' r, "�" f- "' r' �> 1 Paper Print Mudlog (2 ":100') s L 7 1/Copy Mudlogging End of well report ✓ 1 Core Photographs 1/ It 4 1+CD containing FMI image logs and data ✓{ 1 tD containing DSI Image log and data V (N `' 3 1 "CD containing CM R, VSP, Mudlog, LWD, Survey Image Logs and Data. V /S j . Gv� /Jr 5 7 J o% 8 O/�� igYa 5:4 r / �wn Suti�L�y /� 5 r . z, c Please check off each item as received, sign and return one of the two transmittals enclosed to address below. On behalf of itself and [Anadarko Petroleum Comapny], ConocoPhillips Alaska, Inc. submits the attached data for the Puviaq 1 Well. We request that this data be held confidential. CC: A. Andreou, G ilson Receipt: _ - �� Date: .(%- o c� Return receipt to: Phillips Alaska, Inc. ATTN: A. Andreou ATO 1312 700 G. Street Prepared by: A. Andreou Puviaq 1 • ConocoPhillips API 50- 279 - 20008 -00 Compiled by: May 20th, 2003 Greg Wilson Staff Geologist ConocoPhillips - Alaska, Inc. (Formation Tops Measured Depth* Top Nanushuk 470 Base Permafrost 1190 Top Torok 3602 Top HRZ 6622 Lower Cretaceous Unconformity 6889 Simpson Interval 7145 J2 7602 Total Depth 7900 * Straight Hole (MD = TVD) KB = 57.4 GL = 28.2 • AOGCC Memorandum Date: 2/27/2003 To: Puviaq #1 Well File (PTD 202 -248) From: Jim Regg, Petroleum Engineer Subject: Spill Drill Notification I received a call from Mr. Jeff Smith, ConocoPhillips Alaska Inc (CPA) at 10:04 am today. Contact number for Mr. Smith is 907 - 659 -7000 pager #669. He said CPA was holding a spill drill and providing notification to test their communications. Here's what I was told: Scenario: Blowout at Puviaq #1 (PTD 202 -248) Description: Well flowing mud and gas; not currently under control; rig evacuated; no current estimate of volume spilled (estimator from Alpine currently traveling to Puviak); work ongoing to regain control of the well Mr. Randy Thomas (cell — 907 -244 -5295; pager — 907 - 275 -4773) also provided notice of drill to AOGCC inspection staff (Mr. John Crisp) and engineering staff. I a 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Suspend ❑ Operational shutdown 0 Perforate ❑ Variance ❑ Annular Dispos. ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Other ❑ Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory 0 202 -248 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, AK 99510 50 279 - 20008 - 00 7. KB Elevation (ft): 9. Well Name and Number: 30' RKB / 28' AMSL Puviaq 1 8. Property Designation: 10. Field /Pool(s): ADL AA081854 / ALK L32589 Exploratory 11. Present Well Condition Summary: Total Depth measured 7900 feet Plugs (measured) true vertical 7900 feet Junk (measured) Effective Depth measured 6141 feet true vertical 6141 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 112' 112' Surface 1393' 13.375" 1423' 1423' Intermediate 3137' 9.625" 3167' 3167' Production 7861' 7" 7891' 7891' Liner RECEIVED Perforation depth: Measured depth: None MAY 2 3 2003 True Vertical depth: None Tubing: (size, grade, and measured dept 3.5 ", 9.3 #, L -80 @ 6150' & 3.5 ", 9.3 #, L -80 from 6725' l) & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker SAB -3 packer © 5940, Baker FB -1 packer © 6726' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A Subsequent to operation: N/A 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run No Exploratory al Development ❑ Service ❑ Daily Report of Well Operations Yes 16. Well Status after proposed work: Oil ❑ Gas ❑ WAG ❑ GINJ ❑ WINJ❑ WDSP❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact 303 -116 Printed Name P. Mazzolini Title Exploration Drilling Team Leader Signature 3 te y)10,,r Phone 263 -4603 Date 05- / / 2 2 /200_3 Form 10-404 Revised 2/2003 [,br i �di i L 0RIGINALLIT G IN DUPLICATE MOMS BFL MAY 2 7 2003 • . • Notes: ,oY A - - 0 1 1 \ 7GN . _ K • 1. Basis of Horizontal and Vertical Location are the Alpine 'r _ r Monuments #19 and #12. / 7 • \ \ 2. All dist are true, and are in U.S. Survey feet. 6511 , r �, / • { - _ . t '- ITE \ ,-7 / ,, -: _ 1- { KS `,,, 60N -, / f' _ ' ., (` a' E \ ' v� ir� ,,/ . ♦� l P: "4 , / / 1 Lo '41 e I w KJomafers ' i Vicinity Map EDGE OF ICE PAD , .45 0 - - __ i F,AK f :, IV , . �f ,,/� � I Irli, ���'�'�SN e G �I�li nl ii,,, / CSr1�x c...\ o - f —\— 11 11 111111 • EDGE 0 F ---0"— 0°-C) S 1.G ? p0 Q )N ICE PA[ P IPE J * Q U SHED Ill ISE � prJ cs \,, TO 1\\ R' -' -. i -, 5oa PUVIAQ ONE 1 'i% 5 E NAD27 Datum 1 3 Lat. 70 °41'38 44 "N Long: 154 °24'30.50 "W CUTTINGS PIT (Y) 610 '77' by 1 60' (x) 400547.80 1 444' PWL (n 1 '1713' FNL n m BPMSL GROUND ELEV. = Mi Z z 4 . , V-- i _ � W P Br L7 r ♦♦ • A. • 49t1 ♦ • 0 • u An.hc.ny P FictfrrI 1 n ,- i Puviaq #1 K u u k p i k/ LC M F (7A WELL CONDUCTOR AS -BUILT SURVE'r A su. hsrd: arpofUkpeugvrk ln"upielCorporation LOCATED IN SEC 35, T161'1, 010'1•/, UMIAT MERi[1i:=J'i Alp.,e Of fic, - (907) 670 BARROW, .ALA`' KA n r A_ho. e. Aresk.3 (907) 273 - 1830 . Alpine Survey Office DATE: 2/27/03 DRAWN BY. TH I SHEET 1 i l SCALE. 1" =200' CHECKED BY. 1 '1/ 0 Idc GE -GI 1 0 .7 if I DENT IAL • ConocoPhillips Alaska Page 1 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code ©de Phase Description of Operations 1/17/2003 10:00 - 00:00 14.00 MOVE MOB MOVE Start fork lift and move to shop. Dig out hydraulic house. Dig out Peak truck. 1/18/2003 06:00 - 22:00 16.00 MOVE MOB MOVE Finish digging out rig truck. Change tire on loader. Remove snow from around camp units and misc rig equipment. Preheat truck. Start and move to shop. 1/19/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Dig out truck #2. Prheat and start. Engine problem - glycol in oil. Dig out from around truck shop, drill pipe and BOPS. 1/20/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Start removing snow from insulated panels. Remove panels. Change oil in rig up truck. 1/21/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Remove insulated panels. Remove metal racks from roof tops. Load Peak water and rig mats at Lonely. Transport to Puviaq. 1/22/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Remove snow and pick up insulated panels from outer perimeter of rig pad. Work on loading ramp at Puviaq. 1/23/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Remove snow from pad and pick up insulated panels. Remove snow and prep camp for transport from Lonely to Puviaq. 1/24/2003 06:00 - 21:00 15.00 MOVE MOB MOVE Remove snow and insulated panels from around rig. Lay Herculaite and mats for SDU. Set generator building for SDU. 1/25/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Remove snow and insulated panels. Set units for SDU. Clean up debris from around rig. 1/26/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Remove snow from sub. Move 1 section of sub to pad. Set mats and part of the camp. 1/27/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Remove snow from panels. Berm SDU. Fill radiator with glycol. Inspect and start engine. Plug in kitchen unit and start warm up. 1/28/2003 06:00 - 22:00 16.00 MOVE MOB MOVE Stack camp units. Pull wire and plug in. Insulate building breaks. 1/29/2003 06:00 - 00:00 18.00 MOVE MOB MOVE Set and stack camp units. Insulate building breaks. Pull power cables and plug in. Install outside steps. Prep SDU for water. 1/30/2003 06:00 - 22:00 16.00 MOVE MOB MOVE Berm gray water and fuel tanks. Set stair tower on end of camp. Take on 3000 gal water in SDU. Pressure test lines. Unload groceries. 1/31/2003 06:00 - 00:00 18.00 MOVE MOB MOVE Set and berm incenerator. Turn on water in camp. Connect sewage lines. Shovel snow from truck shop. Dig out telecom buildings. 2/1/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Dig out welding / truck shop. RU incenerator. Shoveled out substructure and set on new pad. Assist NSTC with communication hook up. 2/2/2003 00:00 - 18:00 18.00 MOVE MOB MOVE Removed dnow from insulated panels. Remove snow from sub base and pull out. Stacked and pinned rig floor to sub. Removed snow from around derrick and wind walls. PJSM before all tasks. 2/3/2003 06:00 - 18:00 12.00 MOVE MOB MOVE Moved matting boards from side of pipeshed. Dig out rig water tank. Remove snow from drilling line spool and set on new pad. 2/4/2003 06:00 - 00:00 18.00 MOVE MOB MOVE Remove snow and insulated panels from alleyway. Run stringup line for sub raising line. 06:00 - 18:00 12.00 MOVE MOVE MOVE Dig rig equipment out of snow at summer pad. Remove snow and insulated panels from alley way. Run string -up line for sub base. Dig out and install 10' x 6' cellar. (3 1/2 hrs to dig hole w/ small trackhoe) 18:00 - 00:00 6.00 MOVE MOVE MOVE String sub base raising line. 2/5/2003 00:00 - 12:00 12.00 MOVE MOB MOVE Run string up line in ODS sub base. Remove snow from legs. Dig out derrick sections. 12:00 - 00:00 12.00 MOVE MOB MOVE Sring up sub lines. Connect power to electrical shop. Clean shop. Limited outside work due to wind and blowing snow. 2/6/2003 00:00 - 00:00 24.00 WAITON WOW MOVE Fuel equipment. NPRA training. Work on procedures. Straighten electrical shop. 2/7/2003 00:00 - 12:00 12.00 MOVE MOB MOVE Clear snow from pad. Dig rig out after blow. Set Herculite and mats around cellar for sub base. 12:00 - 00:00 12.00 MOVE MOB MOVE Remove snow from around derrick sections. Set mats for sub base. Set Printed: 4/30/2003 4:20:52 PM C]NFIDENTIA ConocoPhillips Alaska Page 2 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code C Phase Description of Operations 2/7/2003 12:00 - 00:00 12.00 MOVE MOB MOVE sub base and cross beams over hole.Installed pipe rack for rig floor. Offload rollagons. 2/8/2003 00:00 - 12:00 12.00 MOVE MOB MOVE Pull tugger off and install pipe rack spreader. Install tugger. Continue to dig out drawworks. Pull drawworks out. Dig A -leg out and move to drill pad. 12:00 - 00:00 12.00 MOVE MOB MOVE Clean snow from around derrick and move to pad. PU insulated panels. Set mats for shop. Cleaned pad. Remove now from around drawworks. 2/9/2003 00:00 - 12:00 12.00 MOVE MOB MOVE Dig out drawworks and set on sills. Set traction motor and brake cooling skids with drawworks. Assemble drawworks. Clear snow from around pipe shed. Assemble truck shop. PU mats and herculite 12:00 - 19:00 7.00 MOVE MOB MOVE Aseemble drawworks, traction motors and drillers console. Installed shop door. Disassemble pipe shed and pulled removed sub beams needed for rig floor 19:00 - 00:00 5.00 WAITON WOW MOVE Halted crane work due to high winds and poor visablility. Plowed snow to prevent snow build up. Assembled shop interior. 2/10/2003 00:00 - 12:00 12.00 MOVE MOB MOVE Clean snow from shop and and parts house. Hang motor for shop door. Set misc rig parts on docks. Limited crane use do to hight wind. 12:00 - 00:00 12.00 MOVE MOB MOVE Finish install shop door. Installed support and spreader beams for rig floor. Installed bridge crane rails. Removed rig mats from under pipe shed. Removed snow from pad. PJSM before every task 2/11/2003 00:00 - 00:00 24.00 MOVE RURD RIGUP Clear snow aroud sub, build matt board ramps to set drawworks, set drawworks w/2 trucks, set hydra - matic, set floor plates & hang knee brces, set rot table, set & pin a -legs, set floor plates, put knee braces on. Removesnow from around support bldgs area. 2/12/2003 00:00 - 12:00 12.00 MOVE MOVE RIGUP Rig up /dig out & move C- sections, bolt down drawworks, dig out snow around derrick section, move snow from off driller side doghouse. Installed spreaders on doghouse iknee braces. Set in rig floor plates. 12:00 - 00:00 12.00 MOVE MOVE RIGUP Pulled out lay down machine, picked up insulated panels & pulled rig mats. Finish cleaning out dog house, layed herculite and set rig mats for support building. Pulled all equipment off roof tops of the support buildings. Set off side dog house on sub. Finish installation of lights on runway, demobe lonely airstrip, 3 -1/2 loads remaining @ Lonely. 2/13/2003 00:00 - 12:00 12.00 MOVE MOB RIGUP Rig up /dig out utility hallways, move & spot choke house, pull shaker house off. Move lower unit to rig and restack and pin shakers, set in and pin. 12:00 - 00:00 12.00 MOVE MOB RIGUP Pulled pits & set, pump room & set, pulled SCR units & set, p/u insulated panels & rig mats, pulled motor unit and set. Set rig mats for support units. 2/14/2003 00:00 - 12:00 12.00 MOVE RURD MOVE Rig up /set in motors, boilers & hot well. Dig out derrick, set mats for utility hallway, cover drawworks w /visqueen & get heat going on drawworks. Put heater on rig cold start & start. Load dewatering tank on low boy. 12:00 - 00:00 12.00 MOVE RURD MOVE Dig snow out of derrick sections, set & berm tioga heater on end of boiler room. Set utilidor buildings in front of rig. Pick and pin bottow derrick section to starting derrick legs. Set pit liner for diesel tanks. Set exhaust stack for #2 boiler. Set de -water house. Two otter personnel flights 2/15/2003 00:00 - 12:00 12.00 MOVE RURD MOVE Dig out & rig up derrick section, load on lowboy w /crane, spot crane & install drk section, lay out herculite for fuel tanks & set tanks. Berm & set rig tioga heater for pump room. String electrical lines in motor room. Move pipe shed section to get to bridle lines, set bridle lines in shop. Printed: 4/30/2003 4:20:52 PM • ConocoPhillips Alaska Page 3 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code C o d e Phase Description of Operations 2/15/2003 12:00 - 00:00 12.00 MOVE RGRP MOVE Install a -leg bolster, remove top drive rails from derrick section. Dig out remaining derrick pieces from snow, set fuel transfer house. Installing floor covers in motor room. Hook up tioga to utilidor, install lights in pump room. Connect drawworks chain, pull wires in pump room & utilidor buildings. Put heat on crown section, blocks and bridle lines. Change out bolts on top derrick section. Unload and transport three CASA loads from airport. 2/16/2003 00:00 - 12:00 12.00 MOVE RURD MOVE Rig up, put bolts in & tighten on a -leg spreader, r/u crane & lift derrick, move derrick stands. Install crown section & bolt up. R/U crane & gin poles on drk. Lift drk & set on stand. Put heat on service loop. Continue warming up pump room, motors, pits & dewatering house. Work in boiler room & motor room installing floor plate & lines. Hook up suitcases, load derrick board on mat board & move to position by rig. 12:00 - 00:00 12.00 MOVE RURD MOVE Finish bolting A -leg bolster beam. String up bridle lines. Raise and pin a -legs. Install and bolt in iron roughbneck on rig floor. Set in off side doghouse. Install middle section of back floor windwalls. Continue heating up rig. Installing plates in motor and pump rooms. Hooking up electric lines in pump room. 2/17/2003 00:00 - 12:00 12.00 MOVE RURD MOVE Rig up /install back floor windwalls & top cap. R ?U crane to install crown, spot crown for crane & install crown. Set in & M/U electrical and hyd service loop on outside of drk w /crane.M /U landing w /blower on drk. Hook up lines starting in boiler room & work toward sub. Start pulling electrical lines. Chipping ice in rig, install floor grating. R/U fluid transfer lines. Heating up rig components, Locate and set standpipe by drk. Set drlg line chute & back of sub. 12:00 - 00:00 12.00 MOVE RURD MOVE Pull elec wires from utilidor to rig, get lights to choke house and dewater house, pull elect wires from choke house to pump room and plug in. Install floor plates in pump room, Run gray water discharge lines. Plow snow for access to lift stations. Clean up summer pad. Rig up portable hydraulic unit to string up drlg line. String rig up line for drlg line in derrick. Three everetts air fueling flights into Puviaq. 2/18/2003 00:00 - 12:00 12.00 DRILL RIRD RIGUP rIG UP, CONTINUE STRINGING UP BLOCKS, FILL BOILER HOT WELL W /H20, CONTINUE HOOKING UP STEAM, AIR & H2O LINES. DRIG OUT & STRING BLOCK HANGING LINE, UNSPOOL OLD TUGGER & HANG DS TUGGER SHEAVE, HOOK UP CHARGE PUMP SUCTION LINES. CONTINUE WORKING ON CROWN, HOOK UP #1 PUMP MUD LINE, WORKING ON #2. PULL WIRE FOR DEWATER AND INJECTION PUMP. SET IN INTERCONNECT BETWEEN DEWATER AND PITS, SET DRLG LINE CHUTE ON SUB ROOF CAP. 12:00 - 00:00 12.00 DRILL RIRD RIGUP HOOK UP LINES IN PIT, START INSTALLING POP OFF LINES IN PUMP ROOM. SET HANDRAILS AROUND TOP OF PITS, PUT #2 CAT ON LINE. PLUG IN DERRICK LIGHTS, PULL ELECTRICAL WIRES AND HOOK TO DRAWWORK MOTORS. SET DRILLERS CONSOLE AND PLUG IN. CHIPPING UP ICE IN SUPPORT MODULES, THAW OUT DRAWWORKS TRACTION MOTORS AND BRAKES. SET & PIN DS DOGHOUSE WINDWALLS. CONTINUE R/U TUGGER, TONG & DERRICK RIDING LINES IN DERRICK. INSTALL CROWN LIGHTS AND RUN POWER TO DERRICK. START PUTTING C- SECTION TOGETHER. TWO EVERETTS AIR FLIGHTS, TWO CASA AND ONE OTTER FLIGHTS. Printed: 4/30/2003 4:20:52 PM rONPFTNTIAI 411 ConocoPhillips Alaska Page 4 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/ 8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code code Phase Description of Operations 2/19/2003 00:00 - 05:00 5.00 MOVE RURD RIGUP Continue R/U, pin c- section together, stand up c- section on mat & cross chain, move & spot c- section at pin pocket on derrick. Chipping ice in entrance's & walkways, work on pump mud lines. 05:00 - 08:00 3.00 MOVE RURD RIGUP Hook up power & air to drawworks, dig out under & hook up lines. 08:00 - 09:30 1.50 MOVE RURD RIGUP Clear rig floor & finish setting in floor plates, remove & lay down iron roughnbeck cradle, working in pump room installing mud lines & vent lines. 09:30 - 12:00 2.50 MOVE RURD RIGUP Pull insulated mat, pick up trash on summer pad, start derrick inspection, work on getting boiler ready to fire. 12:00 - 18:00 6.00 MOVE RURD RIGUP Shovel out gashouse, waterhouse & stair tower, cleaning up summer pad. Remove roughneck carrier from rig floor, shover out under sub. Set floor plates on rig floor. Spool up drilling line on drum and slip extra drlg line, pin monkey board. Welder repaired drain on drawworks oil pan. Plumbing in dewaterhouse, hooking up lines in pits and pump room. 18:00 - 00:00 6.00 MOVE RURD RIGUP Put oil in drawworks, PJSM on raising derrick, Raise derrick high enough to pin c- section to derrick and continue raising derrick, Install floor - plate - rig U airtubbers, hook up air to rig floor. 2/20/2003 00:00 - 04:00 4.00 MOVE RURD RIGUP Rig up, set swivel on rig floor w /crane. Plumb air to rig floor volume tanks, cut tugger & tong lines free in derrick, work on mud pumps, clean snow from windwalls, install tugger line on tuggers. 04:00 - 08:00 4.00 MOVE RURD RIGUP P/U & install windwalls, work on pinning c- section, work on mud pump and lines. 08:00 - 12:00 4.00 MOVE RURD RIGUP Dig snow out f /under sub, install spreader in derrick, work on mud pumps. 12:00 - 18:00 6.00 MOVE RURD RIGUP Finnish pinning spreader in derrick, hang back windwalls on derrick, install gen poll spreader, remove transport cradle on centerfuge in dewatering house, replace bulbs in dewater pit & injection room, change out unions inb pits, chip ice in dewater house & injection room, insulate & install floor plates. work on installing spear in hydromatic, preping mud ditch in pits, install floor plates in pits, insulate roof caps on pits, pull floor sections, prepare to raise floor. Cleaning up summer stack pad. Hook up glycol lines for drawworks, plumb in lines for kickers to rig floor. 18:00 - 00:00 6.00 MOVE RURD RIGUP Install back windwalls, install spreader brace on lower derrick section. Bridle down, lay lines over back of derrick, prep sub base for raising. Prepare to set top drive on floor. UD bridle yoke off of floor. 2/21/2003 00:00 - 03:00 3.00 MOVE RURD RIGUP Unpin & tie back spreader bar in c- section. Tie back bridle line, hang swivel in blocks. Unpin sub spreader beam & reposition drlg line over spreader & repin. Shovel out under sub. Hang bridge short wind walls. 03:00 - 05:30 2.50 MOVE RURD RIGUP R/U crane & set in top drive. R/U pickup line on blks to help crane set top drive. 05:30 - 07:30 2.00 MOVE RURD RIGUP Circulate hydraulics, clean guides for sling shot ginb poles. Raise & pin poles. 07:30 - 09:00 1.50 MOVE RURD RIGUP Clean out around sling shot legs. Raise DS windwall & chain up. Knock out pins between sub & sling shot legs. Prepare to raise sub, work sub up & down to test brake and warm up hydraulics. 09:00 - 12:00 3.00 MOVE RURD RIGUP Filter gasket on hydraulic system blew, cleaned up hydraulic oil in bldg. No oil on pad. Repair filter gasket. Check hydraulic connections, fill hydraulic tank, circ hydraulics & warm up. 12:00 - 18:00 6.00 MOVE RURD RIGUP Start raising sub, develop leak in drylock on ODS, change out, start raising sub, develop leak on DS drylock and flow block at hyraulit unit. Change out drylock and O -rings in flow block. Align #2 mud pump and �1 ,,,.,, & Printed: 4/30/2003 4:20:52 PM rrINp* L J a . . ConocoPhillips Alaska Page 5 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 2/21/2003 12:00 - 18:00 6.00 MOVE RURD RIGUP bolt down. Put belts and guards on pump. Working in pits plumbing and floor plates. 18:00 - 20:00 2.00 MOVE RURD RIGUP Fill hydraulic tank on raising unit, start raising sub, lifted sub 8', oil filter blew off, all oil stayed inside primary containment. 20:00 - 22:30 2.50 MOVE RGRP RIGUP Clean up hydraulic oil inside unit, mechanic found that check valve in oil filter blew apart causing filter housing to blow apart. Hard line bypassing filter. Continued to put floor plates and plumb in pits. Pull other filter housing and checked, ok. 22:30 - 00:00 1.50 MOVE RGRP RIGUP Warming up tote of hydraulic oil, align #1 mud pump and bolt in place. Put belts and guards on. Getting mud pits rigged up. 2/22/2003 00:00 - 02:00 2.00 MOVE RGRP RIGUP Finish filling hydraulic tank, warm oil in tank preparing to lift sub. 02:00 - 04:00 2.00 MOVE RURD RIGUP Raise sub & pin. 04:00 - 15:00 11.00 MOVE RURD RIGUP Hang windwalls front of cellar section, start hanging back sections of wind walls. Set cement tanks, hang side and cellar door wind walls. Dress pumps w/5 -1/2" liner, set water tank and koomey house. 15:00 - 18:00 3.00 MOVE RURD RIGUP Clean ice and snow on ODS dog house outside windwalls. Set brake cooling water house, set stairs to rig floor to top of water tank. Set mat for stair tower and utility tower. 18:00 - 00:00 6.00 MOVE RURD RIGUP Hang two top section windwall drillers side, set stair tower and pin. Finish putting guards on mud pumps, install pop -offs moth mud pumps. Dress #1 pump also change out wear plate. Start dressing #2 mud pump. Install agitators and gun lines in pits. 2/23/2003 00:00 - 03:00 3.00 MOVE RURD RIGUP Hang last sub windwall. Spot fan, stand service tower. 03:00 - 06:00 3.00 MOVE RURD RIGUP Set roof sections between rig and pits. 06:00 - 12:00 6.00 MOVE RURD RIGUP Start setting pipeshed in place. Continue rigging up in pump room, motor shed and mud pits. 12:00 - 15:30 3.50 MOVE RURD RIGUP Unsecure monkeyboard doghouse and raise in place. Set stairway from off driller side dog house to top of choke house, finish dressing #1 mud pump. Hook up dresser sleeves equalizer lines in injection room. 15:30 - 21:00 5.50 MOVE RURD RIGUP Set poorboy gasbuste, set mats for pipe sheds. Pull valve seats both mud pumps and install new ones. Plumbing in gas buster and in pits. Get steam going to rig floor, had problems with return line freezing, temporary fix steam valve in choke hose plugged. Raise cattlechute. 21:00 - 00:00 3.00 MOVE RURD RIGUP Pipe sheds not centered, removed far off driller side pipeshed, center up lay -down machine section pipe shed. Pick up cattle chute, hang v -door track. 2/24/2003 00:00 - 03:00 3.00 MOVE RURD RIGUP FOLD OVER BEAVER SLIDE AND PIN. HOOK UP MAIN RIG AIR LINES. 03:00 - 06:00 3.00 MOVE RURD RIGUP FASTEN WIND TARPS AND STAND UP BEAVER SLIDE ROOF SECTION. 06:00 - 12:00 6.00 MOVE RURD RIGUP FASTEN WIND TARPS TO RIG AND BEAVER SLIDE AND BOTTOM ROOF SECTION. RIG UP GUN LINES AND AGITATORS IN PITS 4,5 & 6. SET THE STAIRS TO DE -WATER HOUSE. HOOK UP GAS BUSTER LINE. FIND RIG FLOOR TOOL BOX AND PARTS FOR TOP DRIVE. 12:00 - 18:00 6.00 MOVE RURD RIGUP HANG BTM C- SECTION LINES TO RIG H2O TANK. REPLACE HEATER CORE TO DOG HOUSE HEATER, REPLACE STEAM VALVES IN RIG H2O BUILDING. M/U EQUALIZER TO RIG H2O TANKS, WORKING IN PITS. 18:00 - 00:00 6.00 MOVE RURD RIGUP HANG BOTTOM DRILLER SIDE RAIL, SORT OUT OTHER TOP DRIVE SECTIONS. TAKE MEASUREMENTS TO ASSURE WHERE OTHER SECTIONS GO. M/U GUN LINES AND AGITATORS IN PITS Printed: 4/30/2003 4:20:52 PM rnt ConocoPhillips Alaska Page 6 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333 @ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 2/24/2003 18:00 - 00:00 6.00 MOVE RURD RIGUP 1,2, & 3. PULL ELECTRICAL WIRES FOR RIG WATER TANKS AND BRAKE COOLING. INSTALL FREEZE PLUGS, MIXING PUMPS AND CHARGE PUMPS. SPOT TIOGA TO PIPE SHED. 2/25/2003 00:00 - 12:00 12.00 MOVE RURD RIGUP Install top drive rails. Plug holes in substructure wind walls. Work on agitators in pit room. 12:00 - 14:30 2.50 MOVE RURD RIGUP Change out 3 top drive rail bolts. Finish snugging up 2nd section rails. 14:30 - 17:00 2.50 MOVE RURD RIGUP Hang last section top drive rail. Cont' work on pits. 17:00 - 20:30 3.50 MOVE RURD RIGUP Install all top drive rail bolts. Hook up poor boy degasser line to choke and pits. Install main auger to dewater unit. 20:30 - 23:00 2.50 MOVE RURD RIGUP PU last section TD railing. Install floor plates. 23:00 - 00:00 1.00 MOVE RURD RIGUP RD rigging. Install) rail bolts. 2/26/2003 00:00 - 01:00 1.00 MOVE OTHR RIGUP Prespud meetimg with all personnel. 01:00 - 06:00 5.00 MOVE RURD RIGUP Install side door beaver slide. PU and install cable tray covers on rig floor. Install missing bolts in top drive rails. 06:00 - 12:00 6.00 MOVE RURD RIGUP Installed mud ramp in pit room. Help mechanic shim hydromatic. Hang V doors.Helped electrician pull wires to rig floor. Chip ice and prep rig floor to PU top drive. 12:00 - 18:00 6.00 MOVE RURD RIGUP Pull wires to rig floor. Align hydromatic. Safety wire bolts on overiding clutch. Install guards on hydromatic. Install bottom section of derrick ladder. Install floor plates. 18:00 - 00:00 6.00 MOVE RURD RIGUP RU top drive. RU 2nd tioga in pipe shed. Work in pits and dewater house. Install new grease lines for auger. 2/27/2003 00:00 - 06:00 6.00 MOVE RURD RIGUP Rig up tongs and torque quill shaft. Position top drive and stand it up. PU top drive from cradle and stab rollers into rails. 06:00 - 12:00 6.00 MOVE RURD RIGUP Attempt to stab quill shaft. Connect compensation cylinders. Install frame and grating around hoppers. Hammer up charge pumps. Put line on equilizer and function. Turn water on to pits. 12:00 - 15:00 3.00 MOVE RURD RIGUP Stab quill shaft in top drive. Dress pins for compensator cylinder. Bring remaining top drive parts to rig floor. Steam off snow and ice. Connect glycol lines from hydromatic to water tower. 15:00 - 21:30 6.50 MOVE RURD RIGUP Slide link adapter on quill shaft and secure with chain. Torque upper IBOP. Install lower IBOP and saver sub. 21:30 - 22:00 0.50 MOVE RURD RIGUP Chain lin adapter back uo. Remove torque arrester. 22:00 - 23:00 1.00 MOVE RURD RIGUP Change out upper IBOP. Torque upper, lower IBOP and saver sub to specs. 23:00 - 00:00 1.00 MOVE RURD RIGUP Install torque arrester, slide crank assembly and pipe handler. 2/28/2003 00:00 - 06:00 6.00 MOVE RURD RIGUP Finish hooling up top drive service to top drive and pipe handler. Install lower kelly valve actuator. 06:00 - 12:00 6.00 MOVE RURD RIGUP Install S -pipe on top drive. Hang service loops from derrick. Prep pits to take on water. Fill drawworks with oil. 12:00 - 17:00 5.00 MOVE RURD RIGUP Tighten clamps on ervice loops in derrick and connect safety cable. Connect hydraulics and electrical. Hang electrical service loop. Fill swivel with oil. 17:00 - 00:00 7.00 MOVE RURD RIGUP PU lower section stand pipe. Fill hydraulic unit for top drive. Connect blower hose. Remove shippong bracket. Hang lights. Check top drive motor brushed. Functio test top drive. Adjust counter balance. Remove rotary chain guard and prep to install same. 3/1/2003 00:00 - 06:00 6.00 MOVE RURD RIGUP Check and retighten bolts on top drive rails. Pressure up and adjust counter balance cylinders on top drive.. Function test torque wrench & IBOP acuator. Hang mud line aross rig floor to bottom of stand pipe. 06:00 - 12:00 6.00 MOVE RURD RIGUP Tighten clamps on stand pipe. Turn goose neck, tighten hammer unions. Hang rotary hose and connect to top drive. Hang shock hose from cellar to mud line on rig floor. Printed: 4/30/2003 4:20:52 PM CONFIDENTIAL 110 . ConocoPhillips Alaska Page 7 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 3/1/2003 12:00 - 15:00 3.00 MOVE RURD RIGUP Silicon rotary chain guard and bolt together. Remove top brace f/ standpipe so welder can repair. RU bales to top drive. Install safety cables on shock hose in breezeway. Install sheave under floor f/ guide f/ slipping drilling line. Work w/ electrician on trouble shooting top drive functions. 15:00 - 18:00 3.00 MOVE RURD RIGUP Continue to trouble shoot top drive functions. RU air to rotary clutch. Hook up main chain from drawworks to rotary, bolt up guard. 18:00 - 21:00 3.00 MOVE RURD RIGUP Continue to trouble shoot top drive problems. Hook up hydraulics to iron roughneck. Function test iron roughneck. Install stand pipe brace. 21:00 - 23:30 2.50 MOVE RURD RIGUP Top drive working. Finish installing brace f/ standpipe. Safety wire- tie bolts on top drive motor cover and block dolly. 23:30 - 00:00 0.50 MOVE RURD RIGUP Clean up cellar area. Prepare for augering 30" hole for conductor. 3/2/2003 00:00 - 06:00 6.00 MOVE RURD RIGUP Safety wire bolts in block dolly. Check length of pick up slings. Empty cuttings bucket of rig tools and put away. Remove spreader and clear out cellar. Build scaffolding around cellar box. Empty pipe shed and load spral DC and HWDP. Strap and thaw. 06:00 - 12:00 6.00 MOVE RURD RIGUP Stand back 1 std HWDP. MU 8" DC, XO's and 30" auger bit. PJSM. Clear snow from cellar. Install screens on mud cleaner. 12:00 - 18:30 6.50 MOVE RURD RIGUP 2 "+ of ice in bottom of cellar. Steam and chip out ice to 5 1/2' from cellar top. 18:30 - 21:00 2.50 DRILL DRLG COND1 Auger 30" hole from pad level to 24'. 21:00 - 22:00 1.00 DRILL OTHR COND1 Shovel excess dirt and ice in cellar into 30" hole. 22:00 - 00:00 2.00 DRILL DRLG COND1 Auger from 24' to 34' (from pad level). Shovel excess cuttings in cellar into hole. 3/3/2003 00:00 - 14:00 14.00 DRILL DRLG COND1 Continue to auger 30" hole f/ 34' to 83' (from pad level). Shovel excess cutting in cellar in hole. 14:00 - 15:15 1.25 DRILL OTHR COND1 Shovel excess dirt in hole. Auger fill dirt from hole. 15:15 - 15:30 0.25 DRILL SFTY COND1 Pre job saftey meeting w/ toolpusher on laying down auger and BHA. 15:30 - 17:00 1.50 DRILL PULD COND1 Cover hole w/ 3" X 12" boards & plywood. Remove snow bucket, VD 30" auger & BHA. 17:00 - 19:00 2.00 DRILL OTHR COND1 Hookup rig up slings to PU 20" conductor. Work on laydown machine. 19:00 - 00:00 5.00 DRILL OTHR COND1 PU 1 joint of 20" conductor pipe. Weld support braces, PU 2nd joint, weld the two together. Wrap w/ insulation and cool down. 3/4/2003 00:00 - 02:00 2.00 CASE RUNC COND1 Recheck depth of cellar box. Measure Rotary table to ice level. Lower 20" pipe (91.51 # /ft) into hole. 02:00 - 06:30 4.50 CASE OTHR COND1 Line up and plumb bob center of conductor pipe to rotary table. Dump (14sx) barite on outside of pipe and (3 sx) inside of pipe. Chip out more ice in cellar floor. MU 2" conduit to cement conductor, run to bottom of hole. Botom joint of 2" conduit is perforated. RU Dowell /Schlumberger to cement conductor. 06:30 - 07:00 0.50 CEMENT SFTY COND1 PJSM prior to cementing 20" conductor. 07:00 - 07:30 0.50 CEMENT PUMP COND1 Dowell mix & pump 315 sx (52.2 bbls) Arctic Set 1 c 15.7 ppg to fill conductor hole and allow floor in 10' diam. cellar. 07:30 - 12:00 4.50 MOVE RURD RIGUP While wait on cement to cure: Hang stabbing board, install guard on rotary rpm indicator. Install casing snub line anchor. Hook up pressure sensors. 12:00 - 14:00 2.00 MOVE RURD RIGUP While wait on cement to cure: Trouble shoot problem with drawworks. Electrician found Air to electric not hooked up yet on driller's console. Hook up control lines on rig floor. 14:00 - 20:00 6.00 WELCTL NUND COND1 Set base plate over 20" conductor. Weld gussets to 20" conductor. Cut two 4" holes in conductor, install two nipples on conductor to take returns. Cut off 20" to desired height(2.60' below pad (top of ice) level. Install FMC 20" landing ring. Weld per FMC procedure. Printed: 4/30/2003 4:20:52 PM I t 0f , f.t g i • ConocoPhillips Alaska Page 8 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Cade Phase Description of Operations 3/4/2003 14:00 - 20:00 6.00 WELCTL NUND COND1 Hang cement standpipe in derrick. Install floor safety mats, continue to hookup sensors on rig floor. 20:00 - 00:00 4.00 WELCTL OTHR COND1 While allowing landing rig to cool: Hookup choke control hoses, clean up not needed equipment f/ cellar, hang manlifts f/ nipple up, hang ODS air winch in cellar f/ same. 3/5/2003 00:00 - 03:00 3.00 WELCTL OTHR COND1 While allowing 20" landing ring to cool, continue RU: PU flowline and stab into pit room wall. Hang flow line. 03:00 - 04:00 1.00 WELCTL OTHR COND1 While allowing 20" landing ring to cool, continue RU: Clean up in cellar, pick up boards, PU tools. 04:00 - 04:30 0.50 WELCTL OTHR COND1 While allowing 20" landing ring to cool: PJSM on picking up 5" HWDP & 5" DP. Prepare rig floor to pick up pipe. 04:30 - 08:30 4.00 WELCTL OTHR COND1 While allowing 20" landing ring to cool: Drift to 2.36 ", strap 5" HWDP. PU 29 joints and Daily jars, stand back total 10 stands of 5" HWDP, then 5 stands 5" DP. 08:30 - 12:00 3.50 WELCTL NUND COND1 PJSM. Thaw out 20" spacer spool and start nipple up on FMC 20" landing ring. 12:00 - 00:00 12.00 WELCTL NUND COND1 NU 20" diverter system. Install 16" knife valve to 20" spool,MU flowline, install flow meter in flowline, connect csg fillup line. Install driller side man lift winch. Function test 20" diverter element & 16" knife valve for proper hose connections. Connect two 16" pieces of diverter line to knife valve. Connect mud bucket hose to flow line. 3/6/2003 00:00 - 07:00 7.00 WELCTL NUND COND1 NU last section of diverter line. Connect fill -up and bleed off lines. Connect turnbuckles to annular preventer. Air up flow line boot. Connect floor drains. Install 4" ball valves on conductor in cellar. 07:00 - 12:00 5.00 MOVE RURD COND1 Run mud pumps #1 and #2. RU cement hose to stand pipe. Blew air through mud system. Fill rod oilers. Clean cellar. Service mud manifold on rig floor. 12:00 - 15:00 3.00 MOVE RURD COND1 Change out small tugger line. Function trip tank pump. Move turnbuckles from annular to bell nipple. RU safety line on stabbing board. 15:00 - 21:00 6.00 WELCTL BOPE COND1 Function test 20" diverter system. Witness of test by AOGCC was waived by Tom Maunder. Closing time 24 sec. System pressure 3000 psi; after closing 1550 psi. attain 200 psi buildup in 21 seconds, full charge 1 min 50 sec. Nitrogen bottles (6) average 2300 psi. Hook up csg fillup manifold. Hookup mud pressure to geolograph and choke panel. 21:00 - 00:00 3.00 MOVE RURD COND1 PJSM on checking out mud system f/ leaks. # 1 mud pump has 4" isolation valve leaking. # 1 mud pump has a wear plate f/ liner leaking (# 1 cylinder). Changing out gate and seat on 4" valve on # 1 mud pump. PU Baker plug launcher cement head. Break lift sub, remove baker preloaded drill pipe wiper plug. Load Davis Lynch latch down drill pipe wiper, push through head one time. Reload Davis Lynch latch down drill pipe wiper plug. Retorque lift sub to 10,000 ft/lb. 3/7/2003 00:00 - 12:00 12.00 RIGMNT RGRP COND1 Attempt to test mud pumps. Replace wear plate, gaskets, and liner on #1 mud pump. Replace kill line low torque valve. Repair isolation valve on mud manifold. Repair leak in 4" valve on #1 pump. Replace gasket on screen for suction on #1 mud pump. 12:00 - 13:30 1.50 RIGMNT RGRP COND1 Continue working on # 1 mud pump suction, Takine on water in pits in pits 13:30 - 15:00 1.50 DRILL OTHR COND1 Take on water in pits, start to mix spud mud. 15:00 - 15:30 0.50 DRILL SFTY COND1 Pre spud meeting. 15:30 - 19:30 4.00 DRILL PULD COND1 PU BHA, 16" bit, motor, MWD, stab, x -o. Printed: 4/30/2003 4:20:52 PM F"p(Sf • ConocoPhillips Alaska Page 9 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code code Phase Description of Operations 3/7/2003 19:30 - 21:30 2.00 RIGMNT RGRP COND1 Mix spud mud, work on rotary table. Can't get enough torque f/ bit MU. 21:30 - 22:30 1.00 DRILL OTHR COND1 Test # 1 & # 2 mud pump. 22:30 - 23:00 0.50 RIGMNT RGRP COND1 Replace liner gasket on # 1 mud pump, right side cylinder, facing pump. 23:00 - 23:30 0.50 DRILL OTHR COND1 Test # 1 & # 2 mud pump. 23:30 - 00:00 0.50 RIGMNT RGRP COND1 Work on # 1 mud pump, check 4" valve again for leak. 3/8/2003 00:00 - 01:30 1.50 DRILL OTHR SURFAC Mix spud mud. Check isolation valve on #2 mud pump. 01:30 - 02:00 0.50 DRILL OTHR SURFAC Mix spud mud. Rebuild 3" Demco valve on rig floor. 02:00 - 03:00 1.00 DRILL CIRC SURFAC Mix spud mud. Check 3" Demco valve and circ through flowline. 03:00 - 04:00 1.00 DRILL OTHR SURFAC Mix spud mud. Check pop -off and 2" bleeder valve on #2 mud pump. 04:00 - 04:30 0.50 DRILL CIRC SURFAC Mix spud mud. Circ through flowline. 04:30 - 06:30 2.00 DRILL CIRC SURFAC Mix spud mud. Circ through bit to shear polymer. 06:30 - 07:30 1.00 DRILL OTHR SURFAC Mix spud mud. Clean pump suction screen of polymer. 07:30 - 08:30 1.00 DRILL CIRC SURFAC Mix spud mud. Circ through bit to shear polymer. 08:30 - 09:00 0.50 DRILL OTHR SURFAC Mix spud mud. Break off top drive. Blow down top drive and mud line. 09:00 - 11:00 2.00 DRILL CIRC SURFAC Mix spud mud. Circulate through bleed off choke to flow line and then pits. 11:00 - 12:00 1.00 DRILL SFTY SURFAC Pre spud meeting. Diverter drill, spill drill. Make up stand of 5" HWDP, ready to spud. 12:00 - 13:30 1.50 DRILL DRLG SURFAC Drill 16" surface hole f/ 112' to 187' w/ 50 rpm, motor 64 rpm, 600 psi, 427 gpm (120 spm). 13:30 - 15:00 1.50 DRILL OTHR SURFAC Shut down drilling. Clean out auger f/ shakers to dewater. 15:00 - 16:00 1.00 DRILL DRLG SURFAC Drill 16" surface hole f/ 187' to 195' w/ 50 rpm, motor 64 rpm, 600 psi, 427 gpm (120 spm). 16:00 - 21:30 5.50 DRILL OTHR SURFAC Shut down due to 10 gal mud spill, through auger shaft seal. Clean up spill. Reported to Kuparuk security and exploration environmental. 21:30 - 00:00 2.50 DRILL DRLG SURFAC Drill 16" surface hole f/ 195' to 255' w/ 50 rpm, motor 64 rpm, 600 psi, 427 gpm (120 spm). 3/9/2003 00:00 - 04:45 4.75 DRILL DRLG SURFAC Drill 16" surface hole f/ 255' to 364' w/ 10k WOB, 60 rpm, motor 64 rpm, 600 psi, 427 gpm (120 spm). 04:45 - 05:15 0.50 DRILL CIRC SURFAC Circ two bottoms up prior to POOH to PU (9) 8" drill collars. 05:15 - 06:00 0.75 DRILL TRIP SURFAC Monitor well. POOH to mud motor. 06:00 - 06:15 0.25 DRILL OTHR SURFAC Change offset on mud motor f/ 0.78? to 0.0 ?. 06:15 - 08:00 1.75 DRILL PULD SURFAC PJSM. PU /MU (3) 8" NM drill collars. 08:00 - 09:30 1.50 RIGMNT RGRP SURFAC Repair bolts that hold cap( to retain pin in place) on laydown machine. 09:30 - 11:00 1.50 DRILL PULD SURFAC PU (6) 8" spiral drill collars. 11:00 - 11:15 0.25 DRILL CIRC SURFAC Circ bottoms up prior to drilling. 11:15 - 12:00 0.75 DRILL DRLG SURFAC Drill 16" surface hole f/ 364' to 400' w/ 10 -15k WOB, 70 rpm, motor 75 rpm, 750 psi, 497 gpm (140 spm). PU wt 110k, SO wt 100k, Rot wt 108k 12:00 - 14:30 2.50 DRILL DRLG SURFAC Drill 16" surface hole f/ 400' to 496' w/ 10 -15k WOB, 80 rpm, motor 86 rpm, 1000 psi, 575 gpm (162 spm). 14:30 - 15:00 0.50 DRILL CIRC SURFAC Circulate hole clean, clean auger of clay. 15:00 - 20:30 5.50 DRILL DRLG SURFAC Drill 16" surface hole f/ 496' to 694' w/ 10 -15k WOB, 80 rpm, motor 92 rpm, 1100 psi, 615 gpm (173 spm). 20:30 - 21:00 0.50 DRILL CIRC SURFAC Circulate bottoms up. 21:00 - 00:00 3.00 DRILL DRLG SURFAC Drill 16" surface hole f/ 694' to 807' w/ 10 -15k WOB,100 rpm, motor 105 rpm, 1450 psi, 710 gpm (200 spm). 3/10/2003 00:00 - 00:30 0.50 DRILL DRLG SURFAC DrIg f/ 807' to 830'. 00:30 - 01:45 1.25 DRILL DRLG SURFAC Work on #2 mud pump. 01:45 - 03:30 1.75 DRILL DRLG SURFAC Drlg f/ 830' to 907'. 03:30 - 04:00 0.50 DRILL DRLG SURFAC Lost #4 generator. Engine OK. 04:00 - 08:00 4.00 DRILL DRLG SURFAC Drlg f/ 907' to 1043'. 08:00 - 09:30 1.50 DRILL CIRC SURFAC Circ slow. Clean auger and shakers. Load out mud on rollagons. Printed: 4/30/2003 4:20:52 PM • ConocoPhillips Alaska Page 10 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 3/10/2003 09:30 - 10:30 1.00 DRILL DRLG SURFAC Drlg f/ 1043' to 1054'. 10:30 - 11:45 1.25 DRILL OTHR SURFAC Clean suction screens on both pumps and change out shaker screens. 11:45 - 18:00 6.25 DRILL DRLG SURFAC Drlg f/ 1054' to 1308'. 18:00 - 19:00 1.00 DRILL CIRC SURFAC CBU to check samples for csg seat. 19:00 - 19:30 0.50 DRILL DRLG SURFAC Drlg f/ 1308' to 1350'. 19:30 - 20:00 0.50 DRILL CIRC SURFAC CBU to check samples for csg seat. 20:00 - 20:30 0.50 DRILL DRLG SURFAC Drlg f/ 1308' to 1358'. 20:30 - 21:30 1.00 DRILL CIRC SURFAC CBU to check samples for csg seat. 21:30 - 23:00 1.50 DRILL DRLG SURFAC Replace seal ring on union in stand pipe. 23:00 - 23:30 0.50 DRILL DRLG SURFAC Drlg f/ 1358' to 1391'. 23:30 - 00:00 0.50 DRILL CIRC SURFAC CBU to check samples for csg seat. 3/11/2003 00:00 - 01:00 1.00 DRILL DRLG SURFAC Drlg f/ 1391' to 1430' 01:00 - 03:00 2.00 DRILL CIRC SURFAC CBU and pump weighted sweep. 03:00 - 08:00 5.00 DRILL WIPR SURFAC POOH. 08:00 - 10:00 2.00 CASE RURD SURFAC M/U 13 -3/8" Casing Hanger Assembly and Running Tool to Landing Joint. 10:00 - 12:00 2.00 CASE RURD SURFAC R/D GBR and R/U casing stabbing board. Install fall arrestors CO beaver slide. Tie back block hanging line. 12:00 - 13:30 1.50 DRILL WIPR SURFAC RIH to 1430'. 13:30 - 16:00 2.50 DRILL CIRC SURFAC CBU @ 670 GPM, 80 RPM. 16:00 - 19:00 3.00 DRILL TRIP SURFAC Drop 2.6" Drift and POOH. 19:00 - 21:00 2.00 DRILL PULD SURFAC Download MWD and L/D BHA. 21:00 - 00:00 3.00 CASE RUNC SURFAC R/U to run 13 -3/8" Casing. 3/12/2003 00:00 - 02:00 2.00 CASE RUNC SURFAC PJSM running casing. M/U shoe track (float shoe, 2- joints 13 -3/8" casing, float collar) and Baker Lock all connections. 02:00 - 05:00 3.00 CASE RUNC SURFAC RIH w/ 13 -3/8" casing filling pipe every 5 joints (no problems encountered). 05:00 - 06:45 1.75 CASE RUNC SURFAC M/U casing hanger, landing joint and circulating swedge. R/D GBR and land hanger. 06:45 - 08:30 1.75 CEMENT CIRC SURFAC Circulate and condition mud @ 6 BPM, 180 psi 08:30 - 10:30 2.00 CEMENT PULD SURFAC Back out landing joint and cut hole for flow line. M/U landing joint and cut off below table. L/D GBR tools and casing pup 10:30 - 13:00 2.50 CEMENT TRIP SURFAC M/U stinger and centralizer. RIH to 1283.48. M/U cement head. Tag in adapter and engage receiver in Float Equipment. 13:00 - 14:30 1.50 CEMENT CIRC SURFAC Circulate and condition mud for cement job. 14:30 - 15:00 0.50 CEMENT SFTY SURFAC PJSM Stab -In Cement Job. Continue circulating and conditioning mud for cement job. 15:00 - 15:45 0.75 CEMENT SEQT SURFAC Mix wash, Circulate 10 bbls water, Test Cement Lines to 5K 15:45 - 18:00 2.25 CEMENT PUMP SURFAC Pump 50 bbl Wash, 50 bbl MudPUSH,140 bbl Lead Cement and 49 bbls Tail Cement. Kicked plug out with 2 bbls cement on top and displaced with fresh water. Bumped plug as planned w/ 800 psi @ 16.1 bbls total displacement. Unstung from Float collar and verifiy floats holding (OK). Note: Mixed red dye in 1st 10 bbls MudPush to comfirm cement volumes. Observed red dye across shakers 115 bbls into Lead Cement displacement (75 bbls expected in gage hole). Continued pumping a total of 140 bbls lead before routing returns down diverter line into open top tank. Diverted +/- 68 bbls to open top tank for disposal. Good quality cement being diverted to tank prior to final displacement. 18:00 - 18:30 0.50 CEMENT PULD SURFAC Rig down & blow down cementing equipment. 18:30 - 19:00 0.50 CEMENT TRIP SURFAC POH w/ DP & cementing stinger. 19:00 - 00:00 5.00 WELCTL NUND SURFAC Lay down landing joint, N/D surface stack. Printed: 4/30/2003 4:20:52 PM I, • ConocoPhillips Alaska Page 11 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code C o d e Phase Description of Operations 3/13/2003 00:00 - 05:00 5.00 WELCTL NUND SURFAC N/D Diverter. 05:00 - 09:00 4.00 WELCTL NUND SURFAC N/U Stack. 09:00 - 12:00 3.00 WELCTL OTHR SURFAC Rig shut down due to accident - Nabors employee medivaced to Barrow. 12:00 - 21:00 9.00 WELCTL NUND SURFAC N/U BOPE. 21:00 - 22:00 1.00 WELCTL OTHR SURFAC Rig shut down due to accident - Nabors employee injured hand (stand down - safety meeting). 22:00 - 00:00 2.00 WELCTL NUND SURFAC N/U BOPE. 3/14/2003 00:00 - 20:00 20.00 WELCTL NUND INTRM1 N/U BOPE, SET STACK ON WELLHEAD, INSTALLED HCR, CHOKE & KILL VALVES, HOOKED UP FLOW LINE AND INSTALLED KOOMEY LINES. PJSM BEFORE EACH TASK. 20:00 - 00:00 4.00 WELCTL NUND INTRM1 INSTALLED 5" RAMS & BLIND. 3/15/2003 00:00 - 03:00 3.00 WELCTL NUND INTRM1 TIGHTEN BLIND RAM DOORS, OPEN TOP DOORS AND INSTALL VARIABLE RAM BLOCKS, CLOSE DOORS. INSTALL TURNB UCKLES AND PULL STACK OVER TO CENTER. 03:00 - 12:00 9.00 WELCTL NUND INTRM1 CLEAN UP AND INSTALL KILL LINE TARGET TEE. INSTALL CHOKE LINE TARGET TEE. INSTALL KILL LINE AND CHOKE LINE TO STACK. 12:00 - 17:50 5.83 WELCTL NUND INTRM1 INSTALL CHOKE LINE, & TURN BUCKLES. 17:50 - 19:00 1.17 WELCTL BOPE INTRM1 CLEAN WORKING AREA, RIG UP TO TEST BOPE. 19:00 - 22:00 3.00 WELCTL BOPE INTRM1 THAW OUT ICE PLUG IN STAND PIPE. 22:00 - 00:00 2.00 WELCTL BOPE INTRM1 FUNCTION TEST BOP'S & FILL CHOKE MANIFOLD KILL LINE AND BOP'S. 3/16/2003 00:00 - 01:00 1.00 WELCTL BOPE INTRM1 PJSM ON BOP TEST, PULL INTERNALS F /KILL LINE CHECK VALVE. 01:00 - 11:00 10.00 WELCTL BOPE INTRM1 TIGHTEN FLANGE ON CHOKE MANIFOLD, TIGHTEN LOCKDOWN PACKING NUTS ON CASING SPOOL. SERVICE CHOKE LINE HCR VALVE. START TESTING BOPE. TIGHTEN GRAY LOCKS ON STACK. HCR VALVE LEAKING. 11:00 - 12:00 1.00 WELCTL NUND INTRM1 DRAIN STACK, BLOW DOWN CHOKE AND KILL LINES. 12:00 - 16:00 4.00 WELCTL NUND INTRM1 PJSM ON TAKING CHOKE & HCR OFF. DISASSEMBLE CHOKE LINE AND HCR. REPLACE HCR VALVE. 16:00 - 18:00 2.00 WELCTL NUND INTRM1 TIGHTEN GRAY LOCK CLAMPS ON BOP STACK. 18:00 - 20:00 2.00 WELCTL BOPE INTRM1 RIH W/TEST PLUG. FILL STACK AND TEST BODY OF BOPS. 20:00 - 22:00 2.00 WELCTL BOPE INTRM1 ATTEMPT TO TEST BOP'S, TOP GRAY LOCK CLAMP STILL LEAKING. 22:00 - 00:00 2.00 WELCTL NUND INTRM1 PJSM, N/D BOP'S (TOP DOUBLE GATE) TO CHECK API RING. 3/17/2003 00:00 - 03:00 3.00 WELCTL BOPE INTRM1 BREAK GRAY -LOCK CLAMP UNDER DOUBLE GATE BOP & REMOVE, REMOVE TURNBUCKLES & LIFT STACK FROM MUD CROSS. 03:00 - 04:00 1.00 WELCTL BOPE INTRM1 INSPECT RING GROOVES, CLEAN AND REPLACE API RING. 04:00 - 08:30 4.50 WELCTL BOPE INTRM1 PJSM, SET STACK BACK ON MUD CROSS & INSTALL DIFFERENT GRAY -LOCK, TIGHTEN AND INSTALL FLOW LINE AND TURN BUCKLES. 08:30 - 10:00 1.50 WELCTL BOPE INTRM1 RUN TEST PLUG, FILL STACK. 10:00 - 11:00 1.00 WELCTL BOPE INTRM1 PERFORM BODY PRESSURE TEST, TIGHTEN FMC GLAND NUTS ON LOWER LOCK DOWNS, TIGHTEN FMC WELL HEAD CLAMP. 11:00 - 22:30 11.50 WELCTL BOPE INTRM1 FILL CHOKE MANIFOLD, START TESTING BOPE, CHOKE MANIFOLD VALVES, 250 LOW, 5000 HIGH, MANUAL CHOKE & KILL, HCR CHOKE & KILL, 250/500, ANNULAR 250/3500. TEST KOOMEY. 22:30 - 00:00 1.50 WELCTL BOPE INTRM1 RIG DOWN TESTING EQUIPMENT & SET WEAR RING. 3/18/2003 00:00 - 01:00 1.00 WELCTL OTHR INTRM1 Finish setting FMC wear bushing. R/D running tool. Clear rig floor. Printed: 4/30/2003 4:20:52 PM • ConocoPhillips Alaska Page 12 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333 @ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Cod Phase Description of Operations 3/18/2003 00:00 - 01:00 1.00 WELCTL OTHR INTRM1 Prepare to PU 5" drill pipe. 01:00 - 05:30 4.50 DRILL PULD INTRM1 PU 75 joints 5" drill pipe. stand back in derrick. 05:30 - 06:30 1.00 DRILL OTHR INTRM1 Connect rotary hose to top drive. 06:30 - 09:30 3.00 DRILL OTHR INTRM1 PJSM. PU /MU 12 1/4" BHA (BHA # 2). 09:30 - 11:00 1.50 DRILL OTHR INTRM1 Up load MWD and load source. 11:00 - 13:30 2.50 DRILL TRIP INTRM1 RIH w/ 8" DC's and 5" HWDP. 13:30 - 14:00 0.50 DRILL CIRC INTRM1 Circulate and condition mud. 14:00 - 14:30 0.50 CASE MIT INTRM1 PJSM. RU to test 13 3/8" casing. 14:30 - 15:30 1.00 CASE MIT INTRM1 Test casing to 2500 psi f/ 30 min. Chart test. Rig down. Blow down lines. 15:30 - 17:30 2.00 CEMENT DSHO INTRM1 Tag float collar @ 1337', drill FC, cement, FS CO 1423, rat hole to 1430', and 5' of new hole. 17:30 - 19:00 1.50 DRILL CIRC INTRM1 Circulate and condition mud prior to FIT @ 1435'. Mud 9.4 ppg. 19:00 - 22:00 3.00 DRILL FIT INTRM1 RU to perform FIT /LOT w/ injection pump @ 1435'. 22:00 - 23:00 1.00 DRILL FIT INTRM1 Rig down and blow down testing equipment. 23:00 - 00:00 1.00 DRILL DRLG INTRM1 Drill 12 1/4" hole f/ 1435' to 1450', change mud to 9.6 ppg. 3/19/2003 00:00 - 01:00 1.00 DRILL FIT INTRM1 F.I.T., BLEED OFF AND CHECK VOLUME.16.0 PPG EMW. BLED OFF 40 GAL, 50.6 GAL PUMPED. 01:00 - 02:30 1.50 DRILL CIRC INTRM1 BLOW DOWN CHOKE LINE & CEMENT LINE. UD TEST TOOLS, RIH TO BOTTOME, CIRC BTMS UP @ 1450'. 02:30 - 08:00 5.50 DRILL DRLG INTRM1 DRLD F/1450- 1756'. 08:00 - 09:00 1.00 DRILL CIRC INTRM1 P/U AND CIRC SLOW WHILE CLEANING OUT AUGER AND DEWATER TANK & PUMP (CLAY). 09:00 - 18:00 9.00 DRILL DRLG INTRM1 DRLD F/1756- 2231'. 18:00 - 19:00 1.00 DRILL CIRC INTRM1 CIRC HOLE CLEAN. 19:00 - 21:30 2.50 DRILL WIPR INTRM1 WIPER TRIP F/2231- 1396'., TIGHT SPOT @- 1850', WIPED OUT. FUNCTION TEST BOPE. 21:30 - 22:00 0.50 RIGMNT RSRV INTRM1 SERVICE TOP DRIVE. 22:00 - 22:30 0.50 DRILL WIPR INTRM1 RIH TO TWO STDS OFF BTM. 22:30 - 00:00 1.50 DRILL CIRC INTRM1 CIRCULATE HOLE CLEAN. 3/20/2003 00:00 - 01:30 1.50 DRILL CIRC INTRM1 CIRCULATE WHILE RIG CREW ASSISTS ROLLAGON MUD TRANSFER SPILL. GET SLOW PUMP RATE. 01:30 - 03:30 2.00 DRILL DRLG INTRM1 DRLD F/2231 -2280' BIT BALLING F /CLAY, UNBALLED BIT, LOST 200 PSI PUMP PRESSURE. 1.8 hr ADT 03:30 - 04:00 0.50 DRILL CIRC INTRM1 CIRC W / #2 PUMP, REPAIR POP OFF ON #2 PUMP. 04:00 - 12:00 8.00 DRILL DRLG INTRM1 CONTINUE DRILLING F/2280- 2600', LWD- DENSITY TOOL FAILURE, CONTINUE DRILLING, P/U AND CYCLE PUMPS FOR MWD AS NEEDED. 5.82 hrs ADT 12:00 - 13:30 1.50 DRILL OTHR INTRM1 CHANGE SHAKER SCREENS. 13:30 - 00:00 10.50 DRILL DRLG INTRM1 CONTINUE DRLG F/2600- 2996'. 8.13 hrs ADT 3/21/2003 00:00 - 02:30 2.50 DRILL CIRC INTRM1 Section of standpipe on rig floor (back corner of ODS "A" leg) union washed. Remove section; rigged up to circ hole after pulling up to 2797', with 2" cementing hose and head pin. Circ samples to surface. 02:30 - 06:30 4.00 DRILL WIPR INTRM1 Wiiper trip from 2797' to 13 3/8" casing shoe. Tight @ 2635', 2584'- 2581', 2489',2469', 2454'- 2449', 2412'- 2410', circ thru 2419' to 2392' w/ 30 spm & 147 psi, 2385'- 2370', 2329'- 2318',2268'- 2210', 2203',2138'- 2130', 1995'. 06:30 - 07:00 0.50 DRILL OTHR INTRM1 Clean rig floor, install floor safety valve, monitor well. 07:00 - 07:30 0.50 RIGMNT RSRV INTRM1 Service rig. 07:30 - 09:30 2.00 RIGMNT RGRP INTRM1 PJSM. Install standpipe mud line section behind "A" leg ODS. Pump through top drive, test line to 3500 psi. Blow down line. 09:30 - 10:30 1.00 DRILL WIPR INTRM1 RIH f/ 1391' to 2890'. No problems. Printed: 4/30/2003 4:20:52 PM ..,fi t. • t r. S .h.., $ „C, 5 1, ConocoPhillips Alaska Page 13 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 3/21/2003 10:30 - 11:30 1.00 DRILL CIRC INTRM1 Circulate and condition mud after short trip. Rotate @ 100 rpm, pump 60 spm to 190 spm. Max gas units 170. Circ 5700' strokes. 11:30 - 12:00 0.50 DRILL REAM INTRM1 Precautionary wash & ream w/ 100 rpm & 190 spm to bottom @ 2996'. No problems. 12:00 - 14:15 2.25 DRILL DRLG INTRM1 Drill 12 1/4" hole f/ 2996' to 3093' (97') ADT 2 hrs 14:15 - 17:00 2.75 DRILL OTHR INTRM1 Circ at reduced rate while waiting on rolligons -- to have enough room to hold waste mud. 17:00 - 18:15 1.25 DRILL OTHR INTRM1 Circ c reduced rate while: PJSM. Pump 85 bbls waste mud to rolligon. Move fluid to injection pit. 18:15 - 20:00 1.75 DRILL DRLG INTRM1 Drill 12 1/4" hole f/ 3093' to 3135' (42') ADT 1.75 hrs 20:00 - 21:00 1.00 RIGMNT RGRP INTRM1 Circulate at reduced rate while change shaker screen on dewater shaker. 21:00 - 22:30 1.50 DRILL DRLG INTRM1 Drill 12 1/4" hole f/ 3135' to 3175' (40') ADT 1.25 hrs 22:30 - 23:30 1.00 DRILL CIRC INTRM1 Circulate bottoms up f/ samples. 23:30 - 00:00 0.50 DRILL WIPR INTRM1 Blow down top drive. Wiper trip f/ 3175'. Midnight bit depth 3035'. 3/22/2003 00:00 - 01:00 1.00 DRILL WIPR INTRM1 Continue POOH f/ wiper trip f/ 3035' to 2705'. RIH. No problems. 01:00 - 03:00 2.00 DRILL CIRC INTRM1 Circulate and condition hole f/ casing @ 3175'. 03:00 - 06:00 3.00 DRILL TRIP INTRM1 Flowcheck well. OK. Pump dry job. POOH to DC's, SLM no correction, no problems. 06:00 - 08:30 2.50 DRILL OTHR INTRM1 PJSM. L/D (6) 8" steel drill collars & (3) 8" monel drill collars 08:30 - 09:45 1.25 DRILL OTHR INTRM1 Remove source and download MWD /LWD tools. 09:45 - 11:00 1.25 DRILL OTHR INTRM1 Drain Sperry Sun 8" motor, break off Hughes 12 1/4" bit. 11:00 - 11:30 0.50 DRILL OTHR INTRM1 Clear rig floor of 12 1/4 "stabilizers, clean floor. 11:30 - 12:00 0.50 WELCTL OTHR INTRM1 Pull FMC wear ring, set FMC test plug. 12:00 - 13:00 1.00 WELCTL OTHR INTRM1 PJSM. Clean ice from working area in cellar. Prepare to change rams in upper and lower pipe rams. 13:00 - 16:45 3.75 WELCTL OTHR INTRM1 Change upper and lower pipe rams in 13 5/8" 5m BOP stack to 9 5/8 ". Hang air winch on stabbing board & antifall. Remove kelly hose f/ top drive. Put change over & hook up 2" hi pressure hose to gooseneck on top drive. Rig up air hose f/ casing elevators. 16:45 - 17:30 0.75 WELCTL BOPE INTRM1 Fill 13 5/8" 5m Hydril BOP stack w/ water. Test door seals to 250 psi low and 3500 psi high w/ annular. L/D test plug, x -o, and test joint. 17:30 - 20:00 2.50 CASE RURD INTRM1 Rig up casing tools to run 9 5/8" casing. Change bales to long 500 ton. Attatch elevators, MU Frank's fillup tool, RU spiders, hang power tongs. Bring to floor centralizers and cementing head, x -o, and circ swage. 20:00 - 21:00 1.00 CASE SFTY INTRM1 PJSM on running 9 5/8" casing. 21:00 - 00:00 3.00 CASE RUNC INTRM1 MU Davis Lynch type 501 float shoe, (2 joints) 9 5/8" 53.5 ppf seal lock boss L -80 casing, Davis Lynch type 700 float collar, (10 joints) 9 5/8" 53.5 ppf seal lock boss L -80 casing, (8 joints) 9 5/8" 47 ppf seal lock boss L -80 casing. Total of 20 joints casing in hole @ midnight 931.80' 3/23/2003 00:00 - 01:45 1.75 CASE RUNC INTRM1 Continue running a total of 18 joints (10 more) 9 5/8" 47 ppf seal lock boss L -80 casing. MU 9 5/8" 47 ppf seal lock boss L -80 pin x 9 5/8" 47 ppf BTC L -80 box pup jpint . MU joint # 31 which is 40 ppf L -80 BTC. 01:45 - 02:30 0.75 CASE CIRC INTRM1 Circulate 9 5/8" casing while at shoe of 13 3/8 ", with Frank's fillup tool. Stage rate up to 7.5 bpm (90 spm) w/ 700 psi. Circ total of 2524 strokes (213.5 bbls) 02:30 - 05:00 2.50 CASE RUNC INTRM1 Continue to run 9 5/8" 40 ppf L -80 BTC casing f/ 1405' (joint # 31 to joint # 75) to 3133' 05:00 - 05:30 0.50 CASE RURD INTRM1 Rig down Frank's fillup tool f/ top drive. Blow down top drive. 05:30 - 06:15 0.75 CASE RUNG INTRM1 MU FMC 9 5/8" hanger w/ pup joint, make up landing joint w/ 9.75 4NA -20 Left hand thread. RIH f/ 3133' to 3164'. Appeared to have fill @ 3162'. RU Dowell Schlumberger cementing head, attatch cementing hose. Printed: 4/30/2003 4:20:52 PM = i • ConocoPhillips Alaska Page 14 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 3/23/2003 06:15 - 08:15 2.00 CEMENT CIRC INTRM1 Establish circulation, wash f/ 3162' to 3166.95' landed on hanger. Establish circ @ 4 bpm (53 spm) w/ 236 psi, stage up to 5 bpm (60 spm) w/ 246 psi, final @ 5 bpm (60 spm) w/ 200 psi. Circ total of 6550 strokes (554 bbls), recip pipe 8' stroke (At 8.7' above landed position pulled up to 280k -- -BOP stack). PU wt 185. SO wt 170K. PJSM w/ Dowell while circulating. 08:15 - 09:15 1.00 CEMENT PUMP INTRM1 Dowell pump 10 bbls CW 100 @ 8.4 ppg, test lines to 2000 psi, pump 30 bbls CW 100, shut down, drop Davis Lynch anti rotation bottom plug, pump 61 bbls mudpush @ 11.7 ppg w/ 4 bpm & 200 psi, follow w/ 45.2 bbls(217 sx) class G w/ adds @ 15.8 ppg @ 4 bpm, shut down, drop top Davis Lynch anti rotation plug, pump another 3 bbis(14 sx) class "G" cement w/ adds CO 15.8 ppg, follow w/ 7 bbls water. 09:15 - 09:45 0.50 CEMENT DISP INTRM1 Rig displace cement w/ 9.7 ppg mud @ 8 bpm until 2500 strokes into displacement, slow pumps to 3 bpm, bump plug @ 2597 strokes, apply 1200 psi. 09:45 - 10:00 0.25 CEMENT OTHR INTRM1 Hold pressure 5 min, bleed off to check floats. OK. 10:00 - 12:00 2.00 CASE RURD INTRM1 Rig down casing tools and cement tools. Drain stack. 12:00 - 13:00 1.00 CASE RURD INTRM1 Continue rigging down casing tools. Change bales back to shorter drilling bales and attatch drill pipe elevators. 13:00 - 15:00 2.00 WELCTL OTHR INTRM1 PU /MU FMC 9 5/8" packoff on running and retrieving tool. Set packoff. RILDS. Test packoff to 5000 psi. OK. Pull FMC R &R tool, RU test joint. 15:00 - 19:00 4.00 WELCTL OTHR INTRM1 MU test plug, attempt to set test plug, wrong one, MU right test plug (13 1/2" OD), set test plug. Change rams f/ 9 5/8" to 3 1/2" x 6" variable top pipe and 5" lower pipe. Removecheck valve ball for testing BOPE. 19:00 - 21:00 2.00 WELCTL OTHR INTRM1 PU tools, fill stack and choke manifold w/ water. Held PJSM. MU floor safety valve, dart valve and ported sub f/ testing. 21:00 - 00:00 3.00 WELCTL BOPE INTRM1 Test 13 5/8" BOPE & choke manifold. Testing all to 250 psi low and all but annular to 5,000 psi high (annular to 3500 psi high). Chart test. Hold test for 5 min. Koomey test. 3/24/2003 00:00 - 04:00 4.00 WELCTL BOPE INTRM1 Continue testing BOPE. Pull test plug. Set wear ring, Test IBOP and lower manual valve on top drive. Drain and blow down kill & choke lines. R/D test equipment. 04:00 - 05:00 1.00 DRILL PULD INTRM1 PJSM, R/U to P/U drillpipe, warm up skate to make operable. 05:00 - 09:30 4.50 DRILL PULD INTRM1 P/U drillpipe, RIH 90 jts, POH and stand back. 09:30 - 11:30 2.00 DRILL PULD INTRM1 P/U 69 jts dp, RIH lots of scale in pipe. 11:30 - 13:00 1.50 RIGMNT RSRV INTRM1 R/U and pump thru open ended drillpipe to remove scale, service iron roughneck, change tong dies while pumping thru pipe. Perform kick while tripping drill. 13:00 - 14:00 1.00 DRILL PULD INTRM1 POH w /drillpipe, SLM 23 stds. 14:00 - 14:30 0.50 DRILL OTHR INTRM1 Clean rig floor. 14:30 - 16:00 1.50 DRILL PULD INTRM1 P/U slips & lifting subs & stabilizers to rig floor. Size slips & dog collar. 16:00 - 18:30 2.50 DRILL PULD INTRM1 PJSM, P/U BHA to first non mag flex DCLR, set motor CP .62 deg. 18:30 - 20:30 2.00 DRILL PULD INTRM1 Load GR & nuetron sources in MWD. 20:30 - 23:00 2.50 DRILL PULD INTRM1 Continue p/u BHA, drift spiral DCLRS, snow & ice in clrs. 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Turn elevator, clear rig floor, prepare to RIH w /HWDP, rigging up to hang kelly hose. 3/25/2003 00:00 - 01:30 1.50 DRILL TRIP INTRM1 Install kelly hose. Pump through BHA, shallow test MWD tools.. Blow down top drive. 01:30 - 02:30 1.00 DRILL TRIP INTRM1 RIH to 3058'. 02:30 - 03:30 1.00 DRILL CIRC INTRM1 Circ and condition mud. 03:30 - 06:00 2.50 CASE DEQT INTRM1 Set back one std. RU equipment. Test csg to 2500 psi for 30 Printed: 4/30/2003 4:20:52 PM y � y -A Y :. • ConocoPhillips Alaska Page 15 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From To Hours Code Code Phase Description of Operations 3/25/2003 03:30 - 06:00 2.50 CASE DEQT INTRM1 mins.(chart test) RD. Blow down lines. 06:00 - 08:30 2.50 CEMENT DSHO INTRM1 Break circ. Drill out FC, cement, FS and 5' new formation to 3180'. 08:30 - 09:00 0.50 CEMENT CIRC INTRM1 CBU. 09:00 - 10:30 1.50 CEMENT FIT INTRM1 Std back 1 std. Performed FIT. 3180' TVD - 9.6 MW - 1095 psi. = 16.2 ppg. Bled off press. Blow down lines. 10:30 - 11:00 0.50 DRILL CIRC INTRM1 Drill 15' new formation. CBU. 11:00 - 13:00 2.00 CEMENT FIT INTRM1 Std back 1 std. Performed LOT. 3195 TVD - 9.6 MW - 1080 psi. = 16.1 ppg. Attempt to pump 3 bbls fluid. Pressured to 1550 psi in 6 stks. Bleed off. Blow down lines. 13:00 - 13:15 0.25 DRILL DRLG INTRM2 Drill 8 1/2" hole f/ 3195' to 3207. ART = .25 hrs 13:15 - 13:45 0.50 DRILL OBSV INTRM2 Flow check well @ 3207'. OK. 13:45 - 17:00 3.25 DRILL DRLG INTRM2 Drill 8 1/2" hole f/ 3207' to 3360' ART - 3 hrs 17:00 - 17:30 0.50 DRILL OTHR INTRM2 Perform PWD baseline test w/ 9.55 ppg mud weight, FV 50, PV 13, YP 14 500 gpm: 80 rpm = 10.36 ppg, 100 rpm = 10.39 ppg, 120 rpm = 10.40 ppg 550 gpm: 80 rpm = 10.47 ppg, 100 rpm = 10.48 ppg, 120 rpm = 10.50 ppg 600 gpm: 80 rpm = 10.56 ppg, 100 rpm = 10.60 ppg, 120 rpm = 10.63 ppg 17:30 - 23:00 5.50 DRILL DRLG INTRM2 Drill 8 1/2" hole f/ 3360' to 3601' ART = 5.02 hrs 23:00 - 23:15 0.25 DRILL CIRC INTRM2 Circ to reduce ECD's. 23:15 - 00:00 0.75 DRILL DRLG INTRM2 Drill 8 1/2" hole f/ 3601' to 3646' ART = .66 hrs 3/26/2003 00:00 - 01:30 1.50 DRILL DRLG PROD Drilling 8 1/2" hole from 3646' to 3676'. ADT = 1.0 hrs 01:30 - 03:00 1.50 DRILL CIRC PROD Circ while EPOCH re- installed software on mud logging computer. 03:00 - 09:30 6.50 DRILL DRLG PROD Drilling from 3676' to 3975'. 120 rpms, 5 -10k bit wt, 525 gpm. Using 11.0 ppg as ECD hardline. At 0830 increased hardline to 11.2 ppg to increase penetration rate. ADT = 5.44 hrs 09:30 - 10:00 0.50 DRILL CIRC PROD CBU to clean hole and lower ECD. 10:00 - 12:00 2.00 DRILL DRLG PROD Drilling 8 1/2" hole from 3975' to 4097'. ADT = 1.4 hrs ADT for last 12 hrs - 7.84 hrs. 12:00 - 12:30 0.50 DRILL DRLG PROD Drilling 8 1/2" hole from 4097 to 4111'. ADT - .42 hrs. 12:30 - 13:00 0.50 DRILL CIRC PROD Circ hole clean. 13:00 - 14:00 1.00 DRILL WIPR PROD Wiper trip to 9 5/8" casing shoe @ 3166'. Function test Hydril, top and bottom pipe rams. No problems on wipertrip. 10k overpull. Minor swabbing. 14:00 - 14:45 0.75 DRILL WIPR PROD RIH f/ 9 5/8" casing shoe (3166') to 4020'. 14:45 - 15:00 0.25 DRILL REAM PROD Wash and ream last stand f/ 4020' to 4111'. Precautionary. 15:00 - 00:00 9.00 DRILL DRLG PROD Drill 8 1/2" hole from 4111' to 4521' ADT = 7.12 hrs Recd verbal approval from AOGCC for annular injection. 3/27/2003 00:00 - 01:00 1.00 DRILL DRLG PROD Driling 8 1/2" hole from 4521' to 4544'. ADT -.75 hrs 01:00 - 01:45 0.75 DRILL DRLG PROD Orient and slide from 4544' to 4580' to drop inclination below 1 ?. AST -.75 hrs 01:45 - 02:15 0.50 DRILL REAM PROD Backream slide. Take slow pump rates. Make connection. 02:15 - 12:00 9.75 DRILL DRLG PROD Drilling 8 1/2" hole from 4580' to 5100'. ADT -8.11 hrs ECD while drilling 10.9 ppg. 12:00 - 13:00 1.00 DRILL DRLG PROD Drilling 8 1/2" hole from 5100' to 5132'. ADT - .56 hrs 13:00 - 13:30 0.50 DRILL CIRC PROD Clean suction screen on #2 pump. 13:30 - 13:45 0.25 DRILL DRLG PROD Drilling 8 1/2" hole from 5132' to 5146'. ADT - .25 hrs 13:45 - 14:30 0.75 DRILL CIRC PROD Circ hole clean for wiper trip. 14:30 - 18:00 3.50 DRILL WIPR PROD Clean solids from trip tank so that trip tank system will operate properly. 18:00 - 18:15 0.25 DRILL OBSV PROD Monitor well. Static Printed: 4/30/2003 4:20:52 PM 3 a, . s ConocoPhillips Alaska Page 16 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Cod Phase Description of Operations 3/27/2003 18:15 - 18:45 0.50 DRILL WIPR PROD Pull one stand. Blow down top drive. 18:45 - 19:30 0.75 DRILL WIPR PROD Continue POOH to 4111'. Hole in good shape. Slight overpull up to 20k CO 4774 - 4744, wipe out. OK. Function pipe rams and annular. 19:30 - 20:15 0.75 DRILL WIPR PROD RIH f/ 4111' to 5053'. MU top drive. 20:15 - 20:45 0.50 DRILL REAM PROD Fill pipe, circ, precautionary wash & ream f/ 5053' to 5146' while circ BU. No fill. Max gas units 89 @ 2100 strokes. 20:45 - 00:00 3.25 DRILL DRLG PROD Drilling 8 1/2" hole from 5146' to 5268'. ADT - 2.68 hrs 3/28/2003 00:00 - 08:00 8.00 DRILL DRLG PROD Drill 8 1/2" hole f/ 5268' to 5654' ADT = 6.54 hrs 08:00 - 08:15 0.25 RIGMNT RGRP PROD PU, circ while change out rod oiler hose on # 1 pump. 08:15 - 12:00 3.75 DRILL DRLG PROD Drill 8 1/2" hole f/ 5654' to 5831' ADT = 2.5 hrs 12:00 - 18:30 6.50 DRILL DRLG PROD Drill 8 1/2" hole f/ 5831' to 6081' ADT3.32 hrs Flow check well @ 5931', 5965', 5970', 5977' 18:30 - 19:00 0.50 DRILL CIRC PROD Circ hole clean, Survey, SPR @ 6081' w/ 9.6 ppg mud. # 1 @ 35 spm = 200 psi @ 47 spm = 300 psi # 2 @ 35 spm = 200 psi @ 47 spm = 300 psi. 19:00 - 19:30 0.50 DRILL OBSV PROD Monitor well. Clean possum belly of shakers to use trip tank. 19:30 - 20:30 1.00 DRILL WIPR PROD POOH f/ wiper trip f/ 6081' to 5055'. Hole in good shape. Slight overpull @ 5410', 5343'- 5340', 5321'- 5318'. Good fill. Function Hydril and both sets of pipe rams. 20:30 - 21:00 0.50 RIGMNT RSRV PROD Service top drive. 21:00 - 21:30 0.50 DRILL WIPR PROD RIH f/ 5055' to 5990'. No problems. Hole in good shape. 21:30 - 22:00 0.50 DRILL REAM PROD Precautionary wash & ream f/ 5990' to 6081' while circ bottoms up.. No fill. Max gas units 85 @ 2300 strokes and 65 CO 3300 strokes. 22:00 - 00:00 2.00 DRILL DRLG PROD Drill 8 1/2" hole f/ 6081' to 6163' ADT = 1.4 hrs 3/29/2003 00:00 - 03:15 3.25 DRILL DRLG PROD Drill 8.5" hole f/ 6163' to 6266'. ART = 2.4 hr 03:15 - 05:30 2.25 RIGMNT OTHR PROD Trouble shoot top drive problem. High torque indicated (enough to stall out top drive, although no torque in drill string) (10 k -16 k ft/lb) 05:30 - 09:30 4.00 DRILL TRIP PROD Monitor well. Pump dry job. Break off top drive. POOH to shoe to further evaluate top drive. Hole in real good shape. No problems. Correct fill. 09:30 - 10:30 1.00 RIGMNT OTHR PROD Trouble shoot top drive problem. High torque indicated (enough to stall out top drive, although no torque in drill string) (10 k -16 k ft/lb) 10:30 - 16:30 6.00 DRILL TRIP PROD Continue to POOH to Sperry Sun LWD /MWD tools. 16:30 - 18:30 2.00 DRILL TRIP PROD PJSM on radioactive sources. L/D Sperry Sun BHA. L/D Motor and bit. Function blind rams. 18:30 - 19:00 0.50 RIGMNT RGRP PROD PJSM on rigging down enough of Varco top drive to get to the Oilwell PC 500 Swivel. 19:00 - 00:00 5.00 RIGMNT RGRP PROD Remove drilling bales. Remove kelly hose. Remove pipe handler. Remove torque arrestor. Break upper and lower IBOP valves. 3/30/2003 00:00 - 04:00 4.00 RIGMNT RGRP PROD Bleed off hydraulic pressure. Remove cylinders and chains from blocks. Remove gooseneck and "S" pipe. 04:00 - 07:00 3.00 RIGMNT RGRP PROD Unbolt stiff arms from swivel. RU pick up lines from blocks to swivel. Remove swivel from top drive and set in mouse hole. 07:00 - 10:00 3.00 RIGMNT RGRP PROD RU and place swivel in rotary table. Break out quill pin. 10:00 - 12:00 2.00 RIGMNT RGRP PROD LD swivel. PU new swivel. Make up quill pin. 12:00 - 14:30 2.50 RIGMNT RGRP PROD Set swivel in mousehole and grind tong marks from quill shaft. Stab swivel in top drive. Connect swivel links. RD slings. Latch swivel in hook. 14:30 - 00:00 9.50 RIGMNT RGRP PROD Connect cylinder assembly to link swivel. Chain up link tilt. MU upper and lower IBOP. Install torque arresstor and pipe handler. Function top drive. Set press on cylinder assembly. Install "S" pipe. Change grabber dies. Check oil in swivel and top drive. Clear tools. Connect kelly hose and install bails and elevators. 3/31/2003 00:00 - 01:00 1.00 DRILL TRIP PROD RU floor to RIH. Printed: 4/30/2003 4:20:52 PM • ConocoPhitlips Alaska Page 17 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 3/31/2003 01:00 - 02:30 1.50 DRILL TRIP PROD MU BHA. 02:30 - 03:15 0.75 DRILL TRIP PROD Upload Sperry Sun tools. 03:15 - 03:30 0.25 DRILL SFTY PROD PJSM for loading gamma and neutron sources. 03:30 - 04:00 0.50 DRILL TRIP PROD Load sources in tools. 04:00 - 05:45 1.75 DRILL TRIP PROD RIH to MU FS, NMS, NMDC's, SDC's and XO. 05:45 - 06:30 0.75 DRILL TRIP PROD RIH w/ HWDP and DP to 1546'. 06:30 - 07:30 1.00 DRILL CIRC PROD Fill pipe. Break circ. Suction valves open on unweighted premix fluid and active system. Circ out fluid. Monitor well. Shallow test MWD. 07:30 - 08:00 0.50 DRILL SFTY PROD PJSM. 08:00 - 09:30 1.50 DRILL TRIP PROD RIH to shoe. Function pipe rams. BOP drill. 09:30 - 10:30 1.00 DRILL CIRC PROD Fill pipe. Circ and condition mud. 10:30 - 12:00 1.50 RIGMNT RGRP PROD Work on IBOP. 12:00 - 13:00 1.00 DRILL TRIP PROD PJSM w/ toolpusher. Trip in hole w/ 8 1/2" rotary assembly from 3145' to 4500'. 13:00 - 14:00 1.00 DRILL CIRC PROD Circulate and condition mud © 4500'. 14:00 - 15:00 1.00 DRILL TRIP PROD Continue RIH w/ 8 1/2" f/ 4500' to 6244'. 15:00 - 16:00 1.00 DRILL CIRC PROD Circulate and condition mud © 6244'. 16:00 - 16:30 0.50 DRILL CIRC PROD Circulate and tie in Sperry Sun log. 16:30 - 18:30 2.00 DRILL DRLG PROD Rotary drill 8 1/2" hole f/ 6266' to 6307' ART = 1.8 hrs 18:30 - 18:45 0.25 RIGMNT RGRP PROD Rig engines #1 and #2 went down on overheat. Adjust louvers. Restart. 18:45 - 21:15 2.50 DRILL DRLG PROD Rotary drill 8 1/2" hole f/ 6307' to 6371'. ART = 1.82 hrs 21:15 - 22:15 1.00 DRILL OTHR PROD Suction screens on both mud pumps were plugging up. Lost from 2023 psi to 1675 psi. Clean screens on both pumps. Replace shaker screen on shaker also. 22:15 - 22:30 0.25 DRILL DRLG PROD Rotary drill 8 1/2" hole f/ 6371' to 6373' ART = .12 hrs. 22:30 - 23:15 0.75 DRILL OTHR PROD Check surface system, pressure test to 3200 psi. OK. Suction screens plugged, clean screens. 23:15 - 00:00 0.75 DRILL DRLG PROD Rotary drill 8 1/2" hole f/ 6373' to 6400'. ART = .73 hrs AOGCC rep John Spalding granted an extension on weekly BOP test until core point is reached. 4/1/2003 00:00 - 06:00 6.00 DRILL DRLG PROD Drlg 8 1/2" hole from 6400' to 6576'. 06:00 - 07:00 1.00 DRILL CIRC PROD CBU for samples. Clean suctiion screens on mud pumps. 07:00 - 12:00 5.00 DRILL DRLG PROD Drlg 8 1/2" hole from 6576' to 99999' last 12 hr ADT - 8.53 hrs. Problems with polymer plugging pump suction screens. Drill out and replace screens. Hopper discharge causing aird up mud in suction pit. 12:00 - 12:30 0.50 RIGMNT RSRV PROD Service drawworks. 12:30 - 13:45 1.25 DRILL DRLG PROD DrIg 8 1/2" from 6685' to 6710'. ADT .74 hrs. 13:45 - 14:30 0.75 RIGMNT RSRV PROD Service top drive and crown. Add 4 gals oil to swivel. 14:30 - 00:00 9.50 DRILL DRLG PROD DrIg 8 1/2" hole from 6710' to 6946'. ART 7.47 hrs. 4/2/2003 00:00 - 01:00 1.00 DRILL DRLG PROD Drill 8 1/2" hole from 6946' to 6969'. ADT - .82 hrs 01:00 - 03:15 2.25 DRILL DRLG PROD Change liner in #2 charge pump. (washed out) 03:15 - 11:15 8.00 DRILL DRLG PROD Drill 8 1/2" hole from 6969' to 7120'. ADT - 6.46 hrs. Eratic torque and bit bounce. 20k drag bottom 10' of hole. 11:15 - 13:30 2.25 DRILL CIRC PROD Circ hole clean. Line up pits fior trip. Pump dry job. 13:30 - 17:30 4.00 DRILL TRIP PROD POH to shoe. Monitor well. No hole problems. Monitor well at shoe. POH to HWDP. Monitor well. 17:30 - 19:00 1.50 DRILL TRIP PROD Std back HWDP and DC's. 19:00 - 19:15 0.25 DRILL SFTY PROD PJSM on RA sources. 19:15 - 21:00 1.75 DRILL TRIP PROD Clear floor. Turn elevators. Remove sources. LD Sperry Sun tools. No apparent damage to bit or BHA. 21:00 - 22:45 1.75 WELCTL OTHR PROD Install 2nd valve on annulus. Pull wear bushing. Install test plug. Fill stack with H2O. 22:45 - 23:00 0.25 WELCTL SFTY PROD PJSM. Review BOP test procedure. Printed: 4/30/2003 4:20:52 PM ,"^�' r+. ;• rw k k, r r K'*' 4 0µy, • • ConocoPhillips Alaska Page 18 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Cod Phase Description of Operations 4/2/2003 23:00 - 00:00 1.00 WELCTL BOPE PROD Test BOPE to 250 - 5000 psi. Witness of test waived by AOGCC rep John Spalding. 4/3/2003 00:00 - 01:45 1.75 WELCTL BOPE PROD Test upper rams, choke HCR, manual choke and manual kill, lower pipe rams to 250 - 5000 psi. Test annular to 250 - 3500 psi. 01:45 - 03:30 1.75 WELCTL BOPE PROD Install check valve. Test Koomey. Pull test jt. Test blind rams from 250 - 5000 psi. Pull test plug and install wear bushing. LD test jt. 03:30 - 05:30 2.00 WELCTL BOPE PROD Test upper and lower IBOP, TIW and dart valve from 250 - 5000 psi. 05:30 - 06:00 0.50 WELCTL BOPE PROD RD test equipment. Blow down lines. 06:00 - 10:00 4.00 RIGMNT RGRP PROD Change oil in swivel. Service top drive. 10:00 - 12:00 2.00 DRILL PULD PROD PU Sperry Sun tools. Upload MWD. 12:00 - 12:15 0.25 DRILL SFTY PROD PJSM. RA sources. 12:15 - 13:00 0.75 DRILL PULD PROD Load sources. 13:00 - 14:45 1.75 DRILL TRIP PROD RIH w/ DC's and HWDP. 14:45 - 15:30 0.75 DRILL OTHR PROD Shallow test MWD. 15:30 - 16:15 0.75 DRILL TRIP PROD Saver broke while backing out swivel. Change out torque wrench pressure cartridge. 16:15 - 17:00 0.75 DRILL TRIP PROD RIH to shoe. 17:00 - 17:30 0.50 DRILL OTHR PROD Test MWD. Blow down. 17:30 - 19:30 2.00 DRILL TRIP PROD RIH to 6999'. Filled pipe at 4500'. No hole problems. 19:30 - 20:15 0.75 DRILL CIRC PROD CBU. Wash to 7092'. 20:15 - 21:00 0.75 DRILL CIRC PROD Washed out gasket on 4" 1502 union in discharge line between pumps. Replace same. 21:00 - 22:30 1.50 DRILL DRLG PROD Drill 8 1/2" hole from 7121' to 7136'. ADT - 1.36 hrs. 22:30 - 23:00 0.50 DRILL DRLG PROD Reposition dresser sleeve on flowline to stop leak. 23:00 - 23:30 0.50 DRILL DRLG PROD Drill 8 1/2" hole from 7136' to 7140'. 23:30 - 00:00 0.50 DRILL DRLG PROD Clean both pump suction screens. Plugged with polymer and Baranex. 4/4/2003 00:00 - 00:45 0.75 DRILL DRLG PROD Drilling 8 1/2" hole from 7140' to 7147'. ADT - .42 hrs 00:45 - 01:30 0.75 DRILL DRLG PROD Change out both suction screens on mud pumps Plugged with polymer and baranex. Drill larger holes in screens. 01:30 - 02:00 0.50 DRILL DRLG PROD Drilling 8 1/2" hole from 7147 to 7156'. ADT - .27 hrs. 02:00 - 02:45 0.75 DRILL CIRC PROD CBU. 02:45 - 03:45 1.00 DRILL WIPR PROD Made 5 std wiper trip. No hole problems. 03:45 - 04:45 1.00 DRILL CIRC PROD Circ and condition mud. 04:45 - 09:00 4.25 DRILL TRIP PROD Monitor well. Pump dry job. POH to shoe. No problems. 09:00 - 11:00 2.00 RIGMNT RSRV PROD Slip and cut drilling line. 11:00 - 15:00 4.00 DRILL TRIP PROD POH to Sperry tools. 15:00 - 18:30 3.50 DRILL PULD PROD LD Sperry tools. 18:30 - 18:45 0.25 DRILL SFTY PROD PJSM on BHA 18:45 - 21:30 2.75 DRILL PULD PROD PU BHA #5 21:30 - 23:00 1.50 DRILL TRIP PROD Attempt to drift HWDP. Too much internal ice build up. 23:00 - 00:00 1.00 DRILL TRIP PROD RIH w/ BHA #5 1 , i ,,.z.'F e -, 4/5/2003 00:00 - 04:45 4.75 DRILL TRIP PROD RIH to 7156'. Fill pipe every 25 stds. 04:45 - 06:00 1.25 DRILL CIRC PROD CBU // 06:00 - 08:00 2.00 DRILL DRLG PROD Drill 8 1/2" hole from 7156' to 7223'. e0->r L` 1 08:00 - 09:30 1.50 DRILL CIRC PROD Circ and condition mud. 72:- 09:30 - 10:00 0.50 DRILL TRIP PROD Set back one sdt. Monitor well. Pump dry job.�� _ 10:00 - 14:30 4.50 DRILL TRIP PROD POH to shoe. No hole problems. ` i) 5 /� 14:30 - 15:00 0.50 DRILL OTHR PROD Monitor well at shoe. OK. C: c•f- 70,7 15:00 - 17:30 2.50 DRILL TRIP PROD POH to HWDP. ` 17:30 - 18:00 0.50 DRILL OTHR PROD Monitor well. OK. 12. cc` '`` 18:00 - 19:30 1.50 DRILL TRIP PROD POH. 19:30 - 21:00 1.50 DRILL PULD PROD LD BHA. 21:00 - 22:00 1.00 RIGMNT RSRV PROD Service top drive and drawworks. Printed: 4/30/2003 4:20:52 PM # a ConocoPhillips Alaska Page 19 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 4/5/2003 22:00 - 00:00 2.00 DRILL PULD PROD MU BHA #5. , 4/6/2003 00:00 - 06:15 6.25 DRILL TRIP PROD RIH to 7223'. Fill pipe every 25 stds. ''� 06:15 - 08:00 1.75 DRILL CIRC PROD CBU /y 08:00 - 17:30 9.50 DRILL DRLG PROD Drill 8 1/2" hole from 7223' to 7313'. (� : G,:. 17:30 - 19:00 1.50 DRILL CIRC PROD CBU 7Z-4:A72-97 19:00 - 19:30 0.50 DRILL OTHR PROD Set back one std. Monitor well. Pump dry job. Y 19:30 - 21:00 1.50 DRILL TRIP PROD POH to 5351'. < S i 21:00 - 21:30 0.50 DRILL OBSV PROD Hole not taking proper fill. Monitor well. No flow. O { • L r `/ 21:30 - 23:00 1.50 DRILL TRIP PROD RIH to 7105'. Check well) for flow at each std. No flow. 23:00 - 00:00 1.00 DRILL CIRC PROD CBU 00:00 - 05:00 5.00 DRILL TRIP PROD POH to shoe. No hole problems. Well taking proper fill. 6 / � "L14 t 05:00 - 05:15 0.25 DRILL OBSV PROD Monitor well. OK 05:15 - 07:15 2.00 DRILL TRIP PROD POH to HWDP. 72.4 - 7 3 le 07:15 - 07:30 0.25 DRILL OBSV PROD Monitor well. OK. Ctc at 2C 07:30 - 09:15 1.75 DRILL TRIP PROD POH. 09:15 - 09:30 0.25 DRILL SFTY PROD PJSM on LD BHA. 2_L) `C 09:30 - 12:00 2.50 DRILL PULD PROD LD BHA. No problems. z 12:00 - 13:30 1.50 DRILL PULD PROD MU BHA. /c' 7 13:30 - 15:30 2.00 DRILL SFTY PROD Large piece of ice fell from derrick due to sun radiation. Clear floor. Crew removed ice from derrick. 15:30 - 17:30 2.00 DRILL PULD PROD Upload MWD. Install sources. 17:30 - 18:00 0.50 RIGMNT RSRV PROD Service top drive. 18:00 - 21:30 3.50 DRILL TRIP PROD RIH to 7313'. No hole problems. Fill pipe every 2500'. 21:30 - 22:00 0.50 DRILL CIRC PROD CBU 22:00 - 00:00 2.00 DRILL OTHR PROD Mad pass from 7313' to 7151' at 100 fpm. 4/8/2003 00:00 - 00:30 0.50 DRILL TRIP PROD Finish mad pass & RIH to bottom 00:30 - 01:00 0.50 DRILL DRLG PROD Drld f/7313- 7320', ART .13 Hrs.. 01:00 - 01:30 0.50 DRILL CIRC PROD Circulate Bottoms Up. 01:30 - 13:30 12.00 DRILL DRLG PROD Drld f/7320- 7900', ART 10.0 Hrs. \ \j 13:30 - 14:00 0.50 DRILL CIRC PROD Circulate Bottoms Up. 14:00 - 16:00 2.00 DRILL WIPR PROD Short trip 10 stands, hole good. 16:00 - 17:00 1.00 DRILL CIRC PROD Circulate Bottoms Up. 17:00 - 21:00 4.00 DRILL TRIP PROD POH f /wireline logs. 21:00 - 23:00 2.00 DRILL PULD PROD PJSM, laydown bha. 23:00 - 00:00 1.00 DRILL RIRD PROD Clean floor, P/U wireline tools. 4/9/2003 00:00 - 00:30 0.50 LOG PULD PROD M/U WIRELINE TOOLS. 00:30 - 04:30 4.00 LOG ELOG PROD RIH WIRELINE LOG #1 (DIPOLE FM1) 04:30 - 05:00 0.50 LOG PULD PROD UD WIRELINE TOOLS. 05:00 - 05:30 0.50 LOG PULD PROD M/U WIRELINE TOOLS. 05:30 - 09:30 4.00 LOG ELOG PROD RIH WIRELINE LOG #2 (CMR). 09:30 - 10:00 0.50 LOG PULD PROD L/D WIRELINE TOOLS. 10:00 - 11:30 1.50 LOG PULD PROD REMOVE WIRELINE TOOLS FROM PIPE SHED & RIG UP F /DRILL PIPE CONVEYED LOG. 11:30 - 13:30 2.00 LOG PULD PROD PJSM W /SCHL- P/U LOGGING TOOLS. 13:30 - 14:00 0.50 LOG DLOG PROD RIH W/14 STDS 5" DP. 14:00 - 16:00 2.00 LOG OTHR PROD MOVE HWDP & DC TO DRILLERS SIDE. 16:00 - 19:30 3.50 LOG DLOG PROD RIH W /DP. 19:30 - 21:00 1.50 LOG DLOG PROD MAKE UP SIDE DOOR ENTRY SUB & HANG WIRELINE SHIEVE. 21:00 - 00:00 3.00 LOG DLOG PROD LOG RUN #3 (MDT) t / 4/10/2003 00:00 - 05:00 5.00 LOG DLOG PROD DP logging w /MDT. 05:00 - 07:00 2.00 LOG DLOG PROD POH to side entry sub. 07:00 - 08:45 1.75 LOG PULD PROD Release wet latch, spool up wire line, lay down side entry sub & rig down sheaves. Printed: 4/30/2003 4:20:52 PM ConocoPhillips Alaska Page 20 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333 @ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code C ©d Phase Description of Operations 4/10/2003 08:45 - 13:00 4.25 LOG DLOG PROD Pump dry job, blow down top drive, POH w /logging tools. 13:00 - 14:00 1.00 LOG PULD PROD UD MDT tools. 14:00 - 14:30 0.50 LOG PULD PROD P/U RSC tool. 14:30 - 22:30 8.00 LOG ELOG PROD RIH & RSC. 22:30 - 23:00 0.50 LOG PULD PROD RIG down tools. 23:00 - 00:00 1.00 LOG PULD PROD P/U VSP tool. 4/11/2003 00:00 - 04:00 4.00 LOG ELOG PROD Continue VSP log, tool failure, POH. 04:00 - 04:30 0.50 LOG ELOG PROD UD tools, P/U new tool. 04:30 - 13:00 8.50 LOG ELOG PROD RIH w /new VSP tool & log. 13:00 - 14:00 1.00 LOG ELOG PROD Rig down wireline. 14:00 - 19:00 5.00 DRILL WIPR PROD Make up BHA & RIH w /5" dp. 19:00 - 21:00 2.00 DRILL CIRC PROD Circulate bottoms up & monitor well. 21:00 - 00:00 3.00 DRILL TRIP PROD POH UD 5° drillpipe. 4/12/2003 00:00 - 03:00 3.00 DRILL PULD PROD UD Drillpipe and clean pits. service rig. 03:00 - 04:00 1.00 DRILL TRIP PROD RIH w /12 stands dp from derrick. 04:00 - 05:00 1.00 DRILL PULD PROD UD drillpipe. 05:00 - 06:00 1.00 RIGMNT RGRP PROD Work on lay down machine. 06:00 - 09:00 3.00 DRILL PULD PROD UD drillpipe. 09:00 - 10:00 1.00 RIGMNT RGRP PROD Remove dp from shed and work on laydown machine. 10:00 - 14:30 4.50 DRILL PULD PROD UD dp, hwdp and collars. 14:30 - 15:00 0.50 DRILL PULD PROD Clean off rig floor. 15:00 - 18:00 3.00 CASE RURD PROD PJSM, r/u casing equipment. 18:00 - 19:30 1.50 WELCTL BOPE PROD Change rams to T' and test doors. 19:30 - 20:00 0.50 CASE SFTY PROD PJSM, running casing. 20:00 - 00:00 4.00 CASE RUNC PROD Double check all equipment, make up float equipment and run 7" casing. Waiting on weather to allow arrival of cementers. RIH slowly. 4/13/2003 00:00 - 09:00 9.00 CASE RUNC PROD P/U & RUN 7 CASING. 09:00 - 11:00 2.00 CASE CIRC PROD WASH DOWN JT #185, LAST JT. CASING CENTRALIZERS HANGING UP PIPE. 11:00 - 14:00 3.00 CASE CIRC PROD MAKE UP HANGER & LANDING JT, ATTEMPT TO WASHDOWN LAST JT, JT FINALLY CAME FREE W /10 -20K WEIGHT, CENTRALIZERS UP HOLE HANGING UP CASING. 14:00 - 21:00 7.00 CASE CIRC PROD CONDITION HOLE FOR CEMENTING, WAITING ARRIVAL OF CEMENTERS AND RIGGING UP CEMENTING UNIT, (WEATHER DELAY) 21:00 - 21:30 0.50 CEMENT SFTY PROD PJSM FOR CEMENTING OPERATION. 21:30 - 23:00 1.50 CEMENT PUMP PROD PUMP 5 BBL H20, TEST LINES, PUMP 25 BBL H20, DROP PLUG, 92 BBL (450 SX) 15.8 CMT, DISPLACE W/298 BBL 10.0+ NACUNABR BRINE, BUMP PLUG W /800 PSI OVER DISPLACEMENT PRESSURE, PLUGS HELD. 23:00 - 00:00 1.00 CEMENT PULD PROD R/D CEMENTING EQUIPMENT. 4/14/2003 00:00 - 01:00 1.00 CASE RURD PROD Finish UD casing and cementing tools. 01:00 - 03:00 2.00 CASE NUND PROD P/U jt HWDP & set pack -off & test. 03:00 - 04:30 1.50 CMPLTN PCKR PROD PJSM, R/U Schlumberger, m/u wireline set packer 04:30 - 07:00 2.50 CMPLTN PCKR PROD RIH w /BAKER FB -1 packer and set. 07:00 - 07:30 0.50 CMPLTN RURD PROD R/D Schlumberger. 07:30 - 08:00 0.50 CMPLTN RURD PROD R/U GBR to run tubing completion. 08:00 - 10:30 2.50 CMPLTN RUNT PROD PJSM, run completion. 10:30 - 11:00 0.50 CMPLTN OTHR PROD Work on lay down machine. 11:00 - 15:00 4.00 CMPLTN RUNT PROD Run completion. 15:00 - 15:30 0.50 CMPLTN SOHO PROD Space out tubing. 15:30 - 17:00 1.50 CMPLTN DEQT PROD R/U to test, test casing to 3500 psi /30 min, rig down test equip. 17:00 - 20:30 3.50 CMPLTN FRZP PROD R/U to freeze protect tubing w/53 bbl diesel. Printed: 4/30/2003 4:20:52 PM 11 7 ConocoPhillips Alaska Page 21 of 21 Operations Summary Report Legal Well Name: Puviaq #1 Common Well Name: Puviaq #1 Spud Date: 3/8/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Contractor Name: n1333@ppco.com Rig Release: Group: Rig Name: Nabors 16E Rig Number: Date From - To Hours Code Code Phase Description of Operations 4/14/2003 20:30 - 21:00 0.50 CMPLTN FRZP PROD u -tube diesel to tbg x casing annulus. 21:00 - 23:30 2.50 CMPLTN RUNT PROD Attempt to land tubing, seal assembly hanging up in SBR, rotate tubing, land seals and tubing hanger. 23:30 - 00:00 0.50 CMPLTN DEQT PROD R/U to test tubing. 4/15/2003 00:00 - 03:30 3.50 CMPLTN DEQT CMPLTN RU & test 3 1/2" tubing to 3500 psi f/ 5 min. OK. Bleed tbg to 1500 psi. Shut in and pressure up 7" x 3 1/2" annulus to 3000 psi f/ 5 min. OK. Bleed off both sides to zero. 03:30 - 04:00 0.50 CMPLTN OTHR CMPLTN R/D test equipment. Set TWC after pulling 3 1/2" landing joint. 04:00 - 05:30 1.50 CMPLTN OTHR CMPLTN Blow down mud lines, kill and choke lines. Clear rig floor. Suck out stack, flush out lines in pits. 05:30 - 06:00 0.50 CMPLTN SFTY CMPLTN PJSM on nippling down BOPE. 06:00 - 09:00 3.00 CMPLTN NUND CMPLTN Remove kill line and valves, remove choke line and valves. 09:00 - 10:30 1.50 CMPLTN FRZP CMPLTN Freeze protect 9 5/8" x 7" annulus w 39 bbls diesel (1400'). Move injection line to 13 3/8" x 9 5/8 ". 10:30 - 20:30 10.00 CMPLTN NUND CMPLTN Seperate kill valve and choke valves. Remove rams f/ BOP cavities. Disassemble mud lines. Put BOP stack in carrier /cradle. 20:30 - 22:00 1.50 CMPLTN NUND CMPLTN PU and install WKM 3 1/8" 5000 psi tree. 22:00 - 22:30 0.50 CMPLTN OTHR CMPLTN Test tree to 5000 psi. Hold f/ 15 min. OK. 22:30 - 23:00 0.50 CMPLTN OTHR CMPLTN Pull 2 way check valve. 23:00 - 00:00 1.00 CMPLTN DEQT CMPLTN RU and test 3 1/2" tubing to 3500 psi w/ 3 1/2" tbg x 7" annulus open. Chart test. Hold test f/ 30 min. Rig released @ 2400 Hrs, 4/15/2003 Printed: 4/30 12003 4:20:52 PM 20" set @ 112' DRILLING TIME AND MUD WEIGHT CURVE — — . Depth Puviaq #1 —Mud Weight 0 I I I I I I I I 1 I I II I I I I I 1 I I I I 1 I I I I 12 L 1 I J L 4 L 1L J L _ L 1 I L L J 11 L J 1 L J 1 I L J J Ili! 1 I I 1 1 I I I 1 I 1 1 I 1 I 1 I I I 1 I I I I I 1 I I I I 1 I I I 1 I I 1 I I I 1 1 I I I I 1 1 1 I I 1 T I 1 I 1 I 1 I 1 1 - Q 77717 DrilI , 16" Hole 1 __ fL _ __ -___ 1__+L L _ 1 j - __1__+ L ____F L _ 1J - _I __ L 1 J 1 J L 1 __ J_ 1 _ H 1 L L 1 1 000 I 1 1 1 1 1 1 I I I I I I I I I I I I I 1 1 1 - -J - - I _ 1 1 L J 1 1 L J L 1 L L J 1 -1 L- J- J - - 1 - --1 1-- I I l � • I I I I I I I ii li � I/ I I I I 1 - 11.6 I I - • --r I 1 I - I I I I I ij * (( (���� I I I I 1 1 - I 1 1 1 - 1 1 1 1 Drill 12 -1/4" Hole ; ; ; I 1 I I ; 1 1 1 III! i 2000 1 I I I I I I I I I I I I I I I I 1 I I I I I 11.4 13 3/8" set@ 1423' I J L _ L_J__1__1____L_J__L_ J____ 1__I__L_J____J__L_1__I__ __J__L_J__I___ I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I - II 16.01: L 1 I 1 I - I 1 1 1 1 1 I 1 1 1 1 1 I 1 1 1 I 1 1 I 1 I I I - -- - -I ---� r , - - - I - - + '{ -- F' ------ + -- I -- + ---- I 1-- I + ---- + -1-- 4 - - ' 4---- + I + -1 - - -- -- 1-- +-- 1---- 1-- F"-- 4 - -1 - -_ 11.2 1 I I I I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 _ 1 1 1 I - 3000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I J 1 I J L J 1 L J •_ • I L L J 1 L J L -L 1 L 71 1 -'111t J L -1. I _ 1 I 1 I 1 1 1 1 1 1 1 I I I 1 I I 1 1 1 1 I I - 11 r 1 1 T 1 I r 1 1 1 r 1 r I T I r r l 1 r r - I r 7 T 1 r 1 7 1 T 1 1 r 7 1 W L -- I -- 1 1---- 1-- F - ' 1--------- * - 1-- F -- _ - - - - + - - I' i -- r - + ----}- 1-- F - i ---- + -- 1-- * - 1---- '� -- F' + ------ 1--- - - - -- I I I I I I I I I I I I 11 I I I I 1 1 1 1 1 1 1 1 4000 1 I I I 1 I I ■ 9-5/8" set @ 3166' i I I I I 1 1 1 1 I I I I I i i - I 1 I 1 10.8 J 1 1 I J L J L 1_ 16.1 ppg LOT I I I I I I I 1 1 1 1 1 I I 1 I I I I I 1 I 1 1 I I I 1 I— 7 I T I I r 7 I 1 r - I r - 1 T I r - I . 1 ' r 1 r 7 T I r 1 7 I T I 1 r 7 1 - I a ---I -- 1--+-- 1------- 4- - -4-- I ----- 1-- + - I - -1- -- -- I + - - I -- - - -- Drill 8 -1/2" Hole- -- - F --- '� ---- + 1-- + -4 - - -- - -1 - - + 1 -- -- - - -1 - - 10.6 0 W 1 I I I 1 1 1 1 1 I I 1 1 I I I 1 1 1 1 1 I I I 1 1 5000 I I 1 1 1 1 1 I I 1 1 1 I I I I I I i I 1 1 1 1 1 1 1 1 W 1 L J 1 J L _ _ _I It _ _I_ -.1- _ _ _ L _ J _ _I_ -1 _ _ _ _ L _ -I _ L -1 1 _ _I_ L _ 71 1 7117 _17 _ 1 _ _ 1 _ J _ _ L _ 1 _ _ 1 _ l in i I I I I I I I I I I I 1 1 1 1 - 10.4 El W 1 I T I 1 r 7 I 1 r 1 r - I T I r r 1 1 T r I r 1 T I Ti 7 I T 1 1 r 1 1 J -- I -- + ---- - --1 -- - -4 - - 1 +- -- -- -- I -- + -- I - - + -- - I - - 1-- I -- + - - - - + - - - ---- + - - -- - 1---- "� ---- + - - -- - -1 -- - + - -1 - -- �/ p I I I I 11 1 I I I I _ 1 1 I II 1 1 1 I I I I I I 1 I I I I (I) 6000 I I i I I i I I I I I 1 I I 10.2 1 1 1 1 1 1 1 1 I 1 1 1 1 1 � � � 1 1 1 Q J__I__1_ J L J I L J L ___I__ 1__ 1__ L____ __ _1-___L_J__LI_J____1__I__L_J____J__L_1__I____J__L_1__I__- W -- I I I 1 I I I I I I _ I I I I I I I I I I I I I I I - I - - T - I 1 r 7 r 1 r T I r r 7 I r 1 r 7 T I r 7 7 1 T 1 1 r 1 1 ± i i i - i - i � 2-Cores - -I- -H- - - - -- 1 - -i - i 1 - - - 10 7000 III ; I I i i I I I I I 1 I i i I I I I 1 1 1 J L J .1 _ 1 1 I L L 1 1 I I I I I I I I I I I I I I 1 1 1 1 I I I 1 — 9.8 71 T I I r 7 I r 1 - 1 T 1 r r 7 T r 1 r 7 \ I r 7 T I 1 r T I -- '� - -I - -1 1 - t - -4 - -1- -- - I --- ' 1-- 1-- + - - - - ---- + ---- L -- 4-- L - '+ -- -- L - - - -- - - - -1 1 - - - - - - -- 1 1 1 I 1 1 1 I HLL I 1 1 1 HH 1 1 I I I 8000 _ J L J J L I I I I I I I I IL I I I I I I 1 +- -1 - 1 1 . - - - k - - --- - - - - L - -- - 7 + - - - - a - -- - -- - --- - + - - - STD /Log /Complete - - - -�-�- -- I I I I I I I I I 1 1 1 II 1 1 1 1 1 1 1 1 1 1 I I I I - 9.4 I I I I I I I I I - 1 1 1 II 1 1 1 1 1 1 1 1 1 1 11 I I I I - 9000 I I I I 1 I 1 1 1 11 1 1 1 1 1 1 1 1 1 I. 1 1 1 1 J I 1 11 L L J L _ 1 L L 1 L J L J 1 I Li J I J L 1 1 _ I I I I I I I 1 I I I I I 1 I I I I 1 1 1 I I - 9.2 7 I T 1 r 7 r 1 r - T 1 r r 1 T r 7 r 7 T I r 7 7 T I 7 r 7 1 -41-1- J 1- J 4. -I L ___ 1-4 -4- J 1 I I I I 1 I I I I I 1 1 1 II I 1 1 1 1 1 1 1 1 I II 1 1 1 1 10000 ! ! ' I I 1 1 I I I 1 I I I I I I I I 1 1 9 0 5 10 15 20 25 30 35 40 45 Spud Well @ 1200 hrs 3/8/03 TIME TO DRILL (DAYS) Release Rig @ 0300 hrs 4/16/03 prepared by TJB 4/23/01 • P Exploration aul M Team Leader Drilling & Wells P. 0. Box Anchchorage, , AK AK 99510-0360 ConocoPhillips Phone: 907 - 263 -4603 May 22, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for Puviaq #1 (202 -248) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent shutdown operations on the exploration well Puviaq #1. The attachments include a summary of daily operations, an as -built and a pressure graph. If you have any questions regarding this matter, please contact me at 263 -4603 or Tom Brassfield at 265 -6377. Sincerely, P. Mazzolini Exploration Team Leader CPAI Drilling PM /skad RE C EIVE D M A 3 0 Alaska Oil &Gas 2 Cons20. Commission 3 Anchorage ORIGINAL • 0 • Y STATE OF ALASKA A y �lS ALASKA OIL AND GAS CONSERVATION COMMISSION on APPLICATION FOR SUNDRY APPROVALS ' WV /4 1. Type of request: Abandon _ Suspend _ Operational shutdown _X Re -enter suspended well _ Other Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Annular Disposal Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development _ 30' RKB +28' MSL feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic _ Anchorage, AK 99510 -0360 / �, / Service_ Exploration NPRA 4. Location of well at surface 'I ✓ 8. Well number 1713' FNL, 444' FWL Sec. 35, T16N - R1OW, UM Puviaq #1 At top of productive interval 9. Permit numbe /a pproval number 1713' FNL, 444' FWL, Sec. 35, T16N - R1OW, UM 202 - 248 At effective depth 10. API number 50- 279 - 20008 -00 At total depth 11. Field / Pool 1713' FNL, 444' FWL, Sec 35, T16N - R1OW, UM Exploration 12. Present well condition summary Total depth: measured 7900' feet Plugs (measured) true vertical 7900' feet Effective depth: measured 7811' est feet Junk (measured) true vertical 7811' est feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 82' 20" 315 sx AS1 112' 112' Surface 1393' 13 3/8" 184 sx ASLITE + 296sx AS1 1423' 1423' Intermediate 3137' 9 5/8" 231 sx CI "G" + additives 3167' 3167' Production 7861' 7" 450 sx CI "G" + additives 7891' 7891' Perforation depth: measured NA true vertical NA RECEIVED- Tubing (size, grade, and measured depth APR 1 4 2003 3 -1/2" 9.3 ppf L -80 @ 6150' (est) 7 N (Y Packers & SSSV (type & measured depth) �318St'8 Chi `�8 s �t 0 FB -1 CO 6725'& SAB -3 C© 5960' (est) Anchorage 13. Attachments Description summary of proposal _X Detailed operations program _X BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: April 14, 2003 16. If proposal was verbally approved Oil _ Gas Suspended Name of approver Tom Maunder Date approved 4/11 Service _Being Completed 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265 - 6377 Signed r-.-- Pc2. a �V 04 4 ( Title: Drilling Team Leader Date 1 3 Paul Maaolini J TJB FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity _ BOP Test _ Location clearance 1( 303J J' 140 Mechanical Integrity Test _ Subsequent form required 10- 1 .-1O `—‘'44 1CAV p, ,c , - > \o /� _ ��-, r \ . - c' .-\. i�cy.� M c3.1 p p3 s k a r l / Approved by order of the Commission /'�`^-' ' ""� w`� `.' Commissioner Date X// 6 / ley RBDMS BF, APR 2 9 2003 Form 10 -403 Rev 06/15/88 • ORIGINAL SUBMIT IN TRIPLICATE ConocoPhi ps • 3 -1/2" Completion Procedure Exploration Well Puviaq #1 CONFIDENTIAL Network # 10028348 f'URRFNT STATUS' The Puviaq #1 well in the NPRA was spudded 3/8/03 and TD'd on 4/8/03. After logging evaluation, the decision has been made to complete the well as indicated in the original application to drill. An Operations Shutdown is being requested for this well as the Winter Exploration season is coming to a close. The following procedures are being proposed to shutdown operations until activities resume at a later date. 1. Run & cement 7" 26# L -80 BTC -M casing. Plug to be displaced with 10 ppg bring. Calculated TOC @ 5300'. Pressure test to 3000 psi for 30 minutes. 2. Run & land 3 -1/2" tubing per attached schematic. There will be no perforations in the wellbore. 3. ND BOPE's. Install production tree and pressure test to 5000 psi. 4. Freeze protect well to 1400' MD 5. Set BPV in tree. Close all valves and remove handles. Install VR plugs in all annulus valves. Install flanges with 1 /2" bull plugs on all outer valves. 6. Prepare to RD Nabors 16E and demob. 7. Clean -up cellar and location to prepare for summer inspections and long term operations shutdown. 8. Ravenproof the X -mas tree before leaving location. 9. Hang sign on tree with the following information: Phillips Alaska, Inc Puviaq# 1 PTD # 202 -248 API # 50- 279 - 20008 -00 SHL: 1713' FNL, 444' FWL, Sec. 35, T16N, R1OW, UM TJB 4/10/03 Conochips 41 3 -1/2" Completion Procedure Exploration Well Puviaq #1 C:ANFTIlFNTTAI NPtwnrk It 1nf17R14R Puviaq #1, Network #10028348 Completion Schematic, Sheet 1 of 2 Exploration Well - CONFIDENTIAL Nabors 16E RKB @ 30' (1) Tubing Hanger: FMC Gen V with 3 -1/2" 9.3# L -80 EUE 8RD Mod pin down Elevation: 28.2' GL' BPMSL (1) Full Length Joint Tubing under Hanger 16" Conductor o (x) Spaceout Pups as Required @112'MD (1) Landing Nipple @ 500' MD: Surface Casing @ Camco 'DS' nipple w/ 2.875" No -Go Profile 1423'MD/TVD 13-3/8" 72 # L-80 BOSS (1) Gas Lift Mandrel @ + / - 2500' MD: Camco 'KBUG', 3 -1/2" x 1", w/ dummy and latch , 10 -foot handling pups installed above and below. Intermediate Casing @ 3167' MD / 3167' TVD 9 -5/8 ", 53.5 & 47 #, L -80, BOSS & 40 # L80 BTC 10 ppg kill weight brine left in tubing and on backside TOC estimated at 5300' MD Production Tubing 3 -1/2 ", 9.3 #, L -80, EUE 8RD Mod (1) Gas Lift Mandrel @ +/- 5930' MD: Camco 'KBUG' , 3 -1/2" x 1", with Dummy Valve and ? ' Latch, 10 -foot handling pups installed above and below. (1) Joint Tubing i 1 Production Casing @ 7900' MD/TVD 7 ", 26 #, L-80 BTC -Mod ( (1) PBR / Packer Assembly by BOT @ +/- 5960' MD See Sheet 2 for details miser ° See Sheet 2 for Packer Assembly and Below Sheet 1 of 2 Poe.", fit r nmpintinn Cnhnmatir loci tcrt vt 0 prepared by TJB TJB 4/10/03 4/10/03 Page 2 of 3 . , ConocoPhi s p gill 3 -1/2" Completion Procedure Exploration Well Puviaq #1 CONFIDENTIAL Network # 10028348 Puviaq #1 Network #10028348 Completion Schematic, Sheet 2 of 2 Exploration Well - CONFIDENTIAL See Sheet 1 for Completion Assembly Above 6 Handling Pup Seal Stem /PBR with seal stem pinned to shear PBR / Packer from PBR with 39ksi overpull. Assembly 6 foot Handling Pup , , @ +/ 5960'MD Tubing Anchor, Model K -22, with Seal Nipple .. Baker SAB -3 Hydraulic set Packer XO, 4 -1/2" LTC Box x 3 -1/2" EUE 8rd Mod pin (2) Joints Tubing 6 - foot Handling Pup (2) Gas Lift Mandrels: (1) Jt of Tubing CAMCO 'KBUG', 3 -1/2" x 1", with Dummy Valve and Latch, with 10 foot handling pups top and bottom and 1 joint of tubing between pups Production Tubing 3 -1/2 ", 9.3 #, L -80, EUE ■ 3 -1/2" Halliburton I XCnipple with 8rd 2.813" ID polished bore w /RHC plug latched in place Mule Shoe No perforations Tubing Tail set @ 6150' Baker FB -1 Permanent Packer with scoop ' entry a -line guide Set Tubing Tail @ 6750' MD/TVD (1) Landing Nipple: 3 -1/2" Halliburton XNOlipple with 2.75" ID No perforations polished bore Float Collar @ 7920' (est) Production Casing @ 7900' MD/TVD (est) 7 ", 26 #, L -80, BTC TD 8 -1/2" Hole: 7900' MD Sheet 2 of 2 I\,�.. 1 C.,,,,J.J.:.,, 6..1...,Itrho 'ISSUED v1.0 prepared by TJB T1R 4/111/111 pAg, 1 of 1 4/10/02 Annular Disposal during the first quarter of 2003: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S -18 31501 100 0 31601 306 0 31907 January March 3S -15, 3S -16, 3S -22, 3S -08 2003 2003 3S -07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S -10, 3S -15, 3S -09, 3S -14 CD2 -48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2 -45, CD2 -35, CD2 -08, CD2 -28 CD2 -17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2 -08, CD2 -48, CD2 -46 CD2 -22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2 -08, CD2 -36, CD2 -51 2003 il, 3S -10 21104 100 0 21204 388 0 21592 March March 3S -21, 3S -08 2003 2003 1C -22 26944 100 0 27044 0 0 27044 March March 1C -190, 1C -174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P -420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P -427, Heavenly CD2 -34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2 -13, CD2 -37, CD2 - 2002 35 IP 2P -415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P -441, 2P -431, Grizzly, 2P -422A, 2P -427, Heavenly CD2 -26 29146 100 0 380 29626 Open, Freeze Protected September October CD2 -38, CD2 -44, CD2 - 2002 2002 29, CD2 -13 CD2 -49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2 -50, CD2 -46, CD2 - 22 RECEIVED 1 s i...J APR 1 6 2003 Alaska Oil & Gas Cons. Commission Q, Anchorage 202 - 248 -[Fwd: Puviaq Update - CONFIDENTIAL] • • Subject: 202 -248 -[Fwd: Puviaq Update - CONFIDENTIAL] Date: Tue, 01 Apr 2003 06:42:33 -0900 From: Tom Maunder <tom_maunder @admin.state.ak.us> To: Randy Ruedrich <randy_ruedrich @admin.state.ak.us >, Bob Crandall <bob_crandall @admin.state.ak.us >, Steve Davies < steve _davies @admin.state.ak.us >, Winton G Aubert <winton_aubert @admin.state.ak.us >, Jim Regg <jim_regg @admin.state.ak.us> Here is the latest report from Puviaq. Subject: Puviaq Update - CONFIDENTIAL Date: Mon, 31 Mar 2003 13:22:18 -0900 From: "Tom J Brassfield" < Tom. J .Brassfield @conocophillips.com> To: greg_noble @ak.blm.gov, Tom Maunder <tom_maunder @admin.state.ak.us> Greg/Tom, the latest from Puviaq. Drilled 12 1/4" hole to 3175' MD/TVD. Ran & cemented 9 5/8" casing at 3167' MD/TVD- good returns throughout the job. Tested BOPE's. Tested casing to 2500 psi- good test. Drilled out 5' of new hole, performed LOT, drilled an additional 15' of new hole performed a 2nd LOT. Currently getting ready to resume drilling 8 1/2" hole to core point after changing out swivel. Thanks, Tom 265 -6377 (w) 275 -7352 (p) 265 -6916 (f) _______, To m Maunder <tom maunder @admin.state.ak.us> ; S r. Petroleum Engineer I Alaska Oil and Gas Conservation Commission j 1 of 1 4/1/2003 6:42 AM 202 - 248 -[Fwd: Puviaq Progress Report- CONFIDENTIAL] 1 • Subject: 202 - 248 -[Fwd: Puvlaq Progress Report- CONFIDENTIAL] Date: Tue, 01 Apr 2003 06:41:30 -0900 From: Tom Maunder <tom_maunder @admin.state.ak.us> To: Randy Ruedrich <randy_ruedrich @admin.state.ak.us >, Bob Crandall <bob_crandall @admin.state.ak.us >, Steve Davies <steve_davies @admin.state.ak.us >, Winton G Aubert <winton_aubert@admin.state.ak.us>, Jim Regg <jim_regg @admin.state.ak.us> Here is the first report from Puviaq. It came just after I left for DC. Tom Subject: Puviaq Progress Report- CONFIDENTIAL Date: Fri, 21 Mar 2003 18:27:59 -0900 From: "Tom J Brassfield" <Tom.J.Brassfield @conocophillips.com> To: greg_noble @ak.blm.gov, Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Paul Mazzolini" < Paul .Mazzolini @conocophillips.com> Greg/Tom, apologize for the dealy in updating our progress. Spudded the Puviaq well on 3/8/03. Ran & cemented 13 -3/8" to 1423' MD. Stab -in cement job, good returns throughout job, cement to surface. Took 5.2 days to NU & test BOPE's. Tested casing to 2500 psi- good test. Drilled firm cement from top of FC to FS. Drilled out & 5' of new hole, performed LOT. Drilled another 15', performed a 2nd LOT. Currently drilling ahead, looking for casing point very close to permitted depth. Thanks, Tom 265 -6377 (w) 275 -7352 (p) 265 -6916 (f) j Tom Maunder <tom maunder(aadmin.state.ak.us> Sr. Engineer �_ Alaska Oil Oil and Gas s Conservation Commission 1 of 1 4/1/2003 6:42 AM Puviaq Update- CONFIDENTIAL � ' s Subject: Puviaq Update- CONFIDENTIAL Date: Mon, 31 Mar 2003 13:22:18 -0900 From: "Tom J Brassfield" < Tom. J .Brassfield @conocophillips.com> To: greg_noble @ak.blm.gov, Tom Maunder <tom_maunder @admin.state.ak.us> Greg/Tom, the latest from Puviaq. Drilled 12 1/4" hole to 3175' MD/TVD. Ran & cemented 9 5/8" casing at 3167' MD/TVD- good returns throughout the job. Tested BOPE's. Tested casing to 2500 psi- good test. Drilled out 5' of new hole, performed LOT, drilled an additional 15' of new hole performed a 2nd LOT. Currently getting ready to resume drilling 8 1/2" hole to core point after changing out swivel. Thanks, Tom 265 -6377 (w) 275 -7352 (p) 265 -6916 (f) 1 of 1 4/7/2003 10:37 AM Note to File Well Puviaq #1 PTD 202 -248 Sundry 303 -102 ConocoPhillips Alaska, Inc. requests approval for annular disposal in the subject well. This note analyzes information submitted by the applicant and recom- mends approving this request for annular disposal. pp g q p Puviaq #1 13 -3/8" surface casing was cemented with 140 bbls lead cement fol- lowed by 49 bbls tail cement, totaling about 176% excess cement relative to gauge wellbore. 35 bbls of lead cement circulated to surface during initial placement, during which full returns circulated. Successful placement of such volumes of cement indicates that Puviaq #1's surface casing is adequately ce- mented. The formation below the 13 -3/8" casing shoe supported a 16.4 ppg EMW forma- tion integrity test. Applied pressure dropped 105 psi (from 500 psi) during a 10 minute shut in. After drilling to 2666', an injectivity test showed a pressure gradi- ent of 15.4 ppg EMW referenced to the 13 -3/8" casing shoe. During this test, pressure reached a maximum of 440 psi. The pressure then stabilized and shut in pressure varied between 160 psi and 45 psi over 10 minutes. EPA compliant log analysis indicates salinities in the 20,000 ppm range for this well. Approximately 50' of sand is within approximately 100' of the shoe, average porosity equals 20.5% and perm is estimated at approximately 60md (from corre- lation to sidewall cores from a reasonably close well.) There appears to be ade- quate receiving lithologies in this shale dominated section of the wellbore. Based upon information submitted, AOGCC recommends approval of Conoco - Phillips's request for annular disposal in Well Puviaq #1 (PTD 202 -248). V iC 3 /z4 /2._0o3 �- /,/ /.3 Winton Aubert Robert randall Petroleum Engineer Petroleum Geologist AOGCC AOGCC Conoc�Phillips Post Office Box 100360 Anchorage, Alaska 99510 -0360 Scott Lowry Phone (907) 265 -6869 Fax: (907) 265 -1535 Email: scott .I.lowry @conocophillips.com March 26, 2003 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste at Puviaq Dear Commissioner: Phillips Alaska, Inc. hereby requests that Puviaq 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 Puviaq as soon as permission is granted. This injection would take place concurrently with drilling operations. Please find attached form 10 -403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 13 3/8" x 9 5/8" casing annulus 9. No adjacent wells 10. Nearest well is South Simpson at 15 miles. If you have any questions or require further information, please contact Tom Brassfield at 265 -6377, or Randy Thomas at 265 -6830. Sincerely, Tom Brassfield Staff Drilling Engineer cc: Paul Mazzolini ATO -1570 Sharon Allsup -Drake ATO -1530 RECEIVED MAR 26 2003 Alaska Oil & Gas Cons. moo n 0R1G1NAL Anchorage ►mi4l6aa -- 3/ Z& /2.cco • STATE OF ALASKA '0 0T_� 03/ Z6(0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re -enter suspended well _ Other _X - Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Annular Disposal Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development _ 30' RKB +28' MSL feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic _ Anchorage, AK 99510 -0360 Service _ Exploration NPRA 4. Location of well at surface 8. Well number 1713' FNL, 444' FWL Sec. 35, T16N - R1OW, UM Puviaq #1 At top of productive interval 9. Permit number / approval number 1713' FNL, 444' FWL, Sec. 35, T16N - R1OW, UM 202 - 248 At effective depth 10. API number 50- 279 - 20008 -00 At total depth 11. Field / Pool 1713' FNL, 444' FWL, Sec 35, T16N - R1OW, UM _ Exploration 12. Present well condition summary Total depth: measured approx 4000' feet Plugs (measured) true vertical approx 4000' feet Effective depth: measured as above feet Junk (measured) true vertical as above feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 82' 20" 315 sx AS1 112' 112' Surface 1393' 13 3/8" 184 sx ASLITE + 296sx AS1 1423' 1423' Intermediate 3137' 9 5/8" 231 sx CI "G" + additives 3167' 3167' Perforation depth: measured NA true vertical NA RECEIVED Tubing (size, grade, and measured depth M 2 6 2013 No tubing as of 3/26/03 Packers & SSSV (type & measured depth) Alaska t X AR Cons, �+t7ft?l?1��lt�ft NA AnChOrage 13. Attachments Description summary of proposal X Detailed operations program _X BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: March 26, 2003 16. If proposa was verbally approved / Oil Gas _ Suspended W > 31 Z-4/10C Name of approver Date approved Service _Being Drilled 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265 - 6377 1 Signed 6 Title: Drilling Team Leader Date o3 / /2o03 Paul Maaolini 6 TJB r FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity _ BOP Test _ Location clearance _ Lice/ "'0a Mechanical Integrity Test _ Subsequent form required 10- - 1,aitaew LG. plo.e w,►....e C i i fed / o ( to ' P i-tss u } Approved by order of the Commission �< Commissioner Date ' J / / o vj n ORIGINAL Form 10 -403 Rev 06/15/88 • R B D M S B F L SUBMIT IN TRIPLICATE • • Annular Disposal Transmittal Form a. Designation of the well or wells to receive Puviaq drilling wastes. b. The depth to the base of freshwater aquifers and No aquifers / Base Permafrost = +/- 1000' TVD permafrost, if present. RKB c. A stratigraphic description of the interval From the 13 3/8" shoe to the cement top all that is exposed to the open annulus and other open is interbedded claystone, siltstone and shale information sufficient to support a commission with occasional minor non - hydrocarbon bearing finding that the waste will be confined and will sands. not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one- NA- Remote Exploration Well quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of waste can be drilling mud, drilling waste to be disposed of and the estimated density cuttings, cement - contaminated drilling mud, of the waste slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic camp waste /grey water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated differential pressure at the outer casing shoe during annular disposal casing shoe during disposal operations is 1722 psi. operation and calculations showing how this See attached calculation page. value was determined. i g. Details that show the shoe of the outer casing is See attached cementing reports, LOT/FIT reports, I set below the base of any freshwater aquifer and and casing reports and LWD logs. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. • • «Puviaq" Pressure Calculations for Annular Disposal DETAILS: 733 X13 3/8" 72 & 68 lb /ft, L -80 BOSS/BTC casing @ 1423 ft MD (1423 ft cz TVD) • Pburst for 68 ppf = 5020 psi, @ 85 %: P burst85% = 4267 psi Estimated Top of Cement @ 2667 ft MD (2667 ft TVD) TOC (9 5/8" csg x 12 1/4" Open hole annulus) 5/8" 53.5/47 lb /ft, L -80 BOSS & 40 ppf L -80 BTC casing @ 3167 ft v MD (3167 ft TVD) L Pcollapse for 40 ppf = 5750 psi, @ 85%: Pcollapse85% = 4887 psi rn • ASSUMPTIONS: • Maximum injection pressure, PApplied = 1500 psi • Maximum density of injection fluid is 12.0 ppg. • Pore pressure at 13 3/8" casing shoe is 0.468 psi /ft CALCULATIONS: Maximum pressure at 13 3/8" shoe: Pmax = PHydrostatic + PApplied - PFormation P max = 12.0 (0.052) (1423) +1500 — 0.468 (1423) Pmax = 1722 psi Maximum fluid density to burst 13 3/8" casing: Pburst85% = PHydrostatic + PApplied - PFormation 4267 = MW (0.052) (1423) + 1500 — 0.468 (1423) MW = 46.4 ppg Maximum Fluid Density to Collapse 9 5/8" Casing: Pcollapse85% = PHydrostatic + PApplied 4887 = MWmax (0.052) (2667) + 1500 MW = 24.4 ppg CononoPhi1 Alaska, Inc. Drill andSmplete Procedure NPR -A Puviaq #1 Exploratory Test WBS: WCD.E02.X020 Network # 10028348 Tubular Pressure Ratings: OD Wt Grade Conn CpIg OD ID Drift Collapse Burst Tensile (in) (ppf) Type (in) (in) (in) (psi) (psi) Yield 20" 94.0 H-40 PEB NA 19.124 18.936 520 1530 NA 13 -3/8" 72.0 L -80 BOSS 14.375 12.347 12.191* 2670 5380 166100 Body 13 -3/8" 68.0 L -80 BTC 14.375 12.415 12.259 2260 5020 1545000 Joint 9 -5/8" 53.5 L -80 BOSS 10.625 8.535 8.379 ** 6620 7930 1244000 Body 9 - 5/8" 47.0 L - 80 BOSS 10.625 8.681 8.525 4760 6870 1086000 Joint 9 - 5/8" 40.0 L - 80 BTC - M 10.625 8.835 8.679 3090 5750 916000 Body 7" 26.0 L-80 BTC -M 7.655 6.276 6.151 5410 7240 604000 Body 3 -1/2" 9.3 L -80 EUE 4.500 2.992 2.867 10530 10160 207220 Joint *The 13 -3/8" 72 ppf casing has been special drifted to 12.250" ** The 9 -5/8" 53.5 ppf casing has been special drifted to 8.500" Drill String Dimensions and Strengths: Pipe Wt (ppf) Grade Conn TJ OD TJ ID Tube ID Max MU TJ Recommended Type (in) (in) (in) Torque Torsional Max Pull (ft -lb) Yield (kips) (ft -lb) 5" DP 19.5 S -135 & 4 -1/2" IF 6 -3/8" 3 -1/2" 4.276" 22,350 44,700 400 G105 5.0" 50 HvyWATE 4 -1/2" IF 6 -1/2" 3 -1/8" 3.0" 29,400 51,375 553 HWDP TJ B 2/21/03 PAI Daily Drilling Page 1 of 2 • • PIMPS Phillips Alaska, Inc. 66 Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prog Puviaq #1 Puviaq #1 10028348 0' 1,430' 1,430' 4.5 55 3/12/03 Ray Supervisor Springer /Mark Proposed TMD 0' Pressure Test(s) Chambers Rig Name Nabors 16E Daily Cost Type Date (TMD TVD MW 1 Press 1 Tot. press 1 EMW Field Name Exploration Cumulative Cost 110'10'10 ppg 0 psi 10.00 psi 10.00 ppg Current Continue N/U Last Safety BOP Tst 1 Status BOPE Meeting 3/12/03 (LastINext) Event ODR Incident 1st 24 hrs? No Rig Accept: 3/8/02@ 00:00 Code _ Rig Release: @ : 24 HR Forecast NU BOPE / Test Last TMD: INC: Azim: Last Casing Next Casing Survey 3/10/03 1,353 0.04 348.44 13.375 (in) @ 9.625 (in) @ 3200 1423 Operations Summary From To Hours Phase ActivitySubcode Time IT roublelOperation Class PJSM running casing. M/U shoe track (float 00:00 02:00 2 SURFAC CASE RUNC P shoe, 2- joints 13 -3/8" casing, float collar) and Baker Lock all connections. 02:00 05:00 3 SURFAC CASE RUNC P RIH w/ 13 -3/8" casing filling pipe every 5 joints (no problems encountered). M/U casing hanger, landing joint and 05:00 06:45 1.75 SURFAC CASE RUNC P circulating swedge. R/D GBR and land hanger. 06:45 08:30 1.75 SURFAC CEMENT CIRC p Circulate and condition mud @ 6 BPM, 180 psi Back out landing joint and cut hole for flow 08:30 10:30 2 SURFAC CEMENT PULD P line. M/U landing joint and cut off below table. L/D GBR tools and casing pup M/U stinger and centralizer. RIH to 10:30 13:00 2.5 SURFAC CEMENT TRIP P 1283.48. M/U cement head. Tag in adapter and engage receiver in Float Equipment. 13:00 14:30 1.5 SURFAC CEMENT CIRC p Circulate and condition mud for cement job. PJSM Stab -In Cement Job. Continue 14:30 15:00 0.5 SURFAC CEMENT SFTY P circulating and conditioning mud for cement job. 15:00 15:45 0.75 SURFAC CEMENT SEAT p Mix wash, Circulate 10 bbls water, Test Cement Lines to 5K Pump 50 bbl Wash, 50 bbl MudPUSH,140 bbl Lead Cement and 49 bbls Tail Cement. http: //bizak. ak. ppco. com/npr- a_expl /puviaq /cgi- bin/reports /daily. asp ?wellname= Puviaq +... 3/26/2003 PAI Daily Drilling Page 2 of 2 • • Kicked plug out with 2 bbls cement on top and displaced with fresh water. Bumped plug as planned w/ 800 psi @ 16.1 bbls total displacement. Unstung from Float collar and verifiy floats holding (OK). Note: Mixed red dye in 1st 10 bbls MudPush to comfirm cement volumes. Observed red 15:45 18:00 2.25 SURFAC CEMENT PUMP P dye across shakers 115 bbls into Lead Cement displacement (75 bbls expected in gage hole). Continued pumping a total of 140 bbls lead before routing returns down diverter line into open top tank. Diverted +/- 68 bbls to open top tank for disposal. Good quality cement being diverted to tank prior to final displacement. 18:00 18:30 0.5 SURFAC CEMENT PULD p Rig down &blow down cementing equipment. 18:30 19:00 0.5 SURFAC CEMENT TRIP P POH w/ DP & cementing stinger. 19:00 00:00 5 SURFAC WELCTL NUND P Lay down landing joint, N/D surface stack. 24 Hr. RU, Run and Cement 13 -3/8" Csg. ND Diverter. NU Wellhead and BOPE Sum: Mud Data Mud lOsec / 10 FlowLine Drilling Company Density FV PV /YP min / 30 min WL /HTHP MBT PH Temp Solids Gels Baroid PolyCmer 9.8 44 10 / 16 5/9/11 7 / 0 5 10.4 60 5.7 Baroid PolyCmer 10 48 10 / 18 6/11/13 7 / 0 7.5 8.7 66 6.8 L http: //bizak. ak.ppco.com/npr- a_expl /puviaq /cgi- bin /reports /daily. asp ?wellname= Puviaq +... 3/26/2003 • • ConocoPhillips Alaska Page 1 of 3 Cementing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 1 Report Date: 3/12/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Cement Job Type: Primary Primary Squeeze Open Hole Squeeze Casing Plug Hole Size: 16.000 (in) Hole Size: Hole Size: Hole Size: TMD Set: 1,423 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 3/12/2003 SQ Date: Date Set: BTM set: (ft) Csg Type: Surface Casing SQ Type: Csg Type: Plug Date: Csg Size: 13.375 (in.) SQ TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Carl Dacar Pipe Movement: No movement Pipe Movement Rot Time Start: : Time End: : RPM: !nit Torque: (ft-lbf) Avg Torque: (ft -Ibf) Max Torque: (ft-Ibf) Rec Time Start: : Time End: : SPM: Stroke Length: (ft) Drag Up: (Ibs) Drag Down: (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: Disp Avg Rate: (bbl /min) Returns: Volume Excess %: Start Slurry Displ: : Disp Max Rate: (bbl /min) Total Mud Lost: (bbl) Meas. From: 35 BBL Start Displ: Bump Plug: Y Cmt Vol to Surf: 35.00 (bbl) Time Circ Prior End Pumping: Press Prior: (psi) To Cementing: 2.00 End Pump Date: Press Bumped: 800 (psi) Ann Flow After: N Mud Circ Rate: 250 (gpm) Top Plug: N Press Held: (min) Mixing Method: Mud Circ Press: (psi) Bottom Plug: N Float Held: Y Density Meas By: Mud Data Type: Density: 10.0 (ppg) Visc: 48 (s /qt) PV/YP: 10 (cp) /18 (Ib/100ft Gels 10 sec: 6 (Ib/100ft Gels 10 min: 11 (Ib /100ft Bottom Hole Circulating Temperature: ( °F) Bottom Hole Static Temperature: ( °F) Displacement Fluid Type:Fresh Water Density: (ppg) Volume: (bbl) Stage No: 1 Slurry No: 1 of 4 Slurry Data Fluid Type: FLUSH Description: CW100 Class: Purpose: Slurry Interval: (ft) To: (ft) Cmt Vol: 50.0 (bbl) Density: 8.40 (ppg) Yield: (ft /sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Printed: 3/26 /2003 8:58:01 AM • • 1 ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 1 Report Date: 3/12/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Stage No: 1 Slurry No: 2 of 4 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Purpose: Slurry Interval: 1,430.00 (ft)To: (ft) Cmt Vol: 53.0 (bbl) Density: 10.50 (ppg) Yield: (ft /sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Stage No: 1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Description: ASLite Class: Purpose: Slurry Interval: (ft) To: (ft) Cmt Vol: 140.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft /sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: ARCTIC SET Class: Purpose: PRIMARY Slurry Interval: (ft) To: (ft) Cmt Vol: 49.0 (bbl) Density: 15.70 (ppg) Yield: 0.93 (ft /sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Printed: 3/26/2003 8:58:01 AM • . ConocoPhillips Alaska Page 3 of 3 Cementing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 1 Report Date: 3/12/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Casing Test Shoe Test Liner Top Test Test Press: (psi) Pressure: (ppge) Liner Lap: For: (min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: (ft) Neg Test: (ppge) Tool: N Shoe and Collar: N Hrs Before Test: Hrs Before Test: Cement Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (ft) Under Pressure: (psi) How Determined: visual /dye Bond Quality: TOC Sufficient: Y Cet Run: N Job Rating: Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Hrs Prior to Log: Number of Remedial Squeezes: Printed: 3/26 /2003 8:58:01 AM ConocoPhillips Alaska Page 1 of 1 Casing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 1 Report Date: 3/12/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: General Information String Type: Surface Casing Permanent Datum: Kelly Bushing Hole Size: 16.000 (in) Hole TMD: 1,430.0 (ft) Hole TVD: 1,430.0 (ft) KB- Datum: 56.00 (ft) Water TMD: (ft) Str Wt on Slips: (Ibs) Ground Level: 26.00 (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 0.31 ( °) • Circ Hours: 1.00 (hr) Mud Lost: (bbl) KB to Cutoff: 31.75 (ft) Days From Spud: 4.50 (days) Casing Flange / Wellhead Manufacturer: FMC Model: 10k Top Hub /Flange: (in) / (psi) Hanger Model: Packoff Model: BTM Hub /Flange: (in) / (psi) Actual TMD Set: 1,423.25 (ft) Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer Model Cond. Max OD Min ID Comp. Name (in.) (Ib/ft) (in) (ft) (ft) (ft-Ibf) (in) (in) Casing Hanger 13.375 BTC 0.36 31.75 FMC NEW 18.500 Casing Hanger Casing - Pup Jt 13.375 68.00 L -80 12.259 BTC 3.04 32.11 NEW 12.347 13 3/8" 72# L -80 Cross Over 13.375 2.80 35.15 NEW Cross Over Casing 13.375 72.00 L -80 12.191 BOSS 31 1,296.70 37.95 NEW 12.347 13 3/8" 72# L -8� Float Collar 13.375 BOSS 2.67 1,334.65 Y DAVIS LYNCH 700 -TLP -PVTS NEW 14.480 Float Collar Casing 13.375 72.00 L -80 12.191 BOSS 2 83.58 1,337.32 Y NEW 12.347 13 3/8" 72# L -80 Float Shoe 13.375 BOSS 2.35 1,420.90 Y DAVIS LYNCH 501 -PVTS NEW 14.480 Float Shoe Non - Integral Casing Accessories Accessory Manufacturer Number Spacing Interval How Fixed (ft) Top (ft) Bottom (ft) Bowspring Centralizer WEATHERFORD 3 OverCollar Printed: 3/26/2003 8:58:19 AM PAI Daily Drilling Page 1 of 2 • r a b '1 PIMPS Philips Alaska, Inc. 66 Daily Drilling R eport Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prog Puviaq #1 Puviaq #1 10028348 0' 3,175' 3,175' 15.5 66 3/23/03 Supervisor Ray Springer/ Granville Rizek Proposed TMD 0' Pressure Test(s) Rig Name Nabors 16E Daily CPA Type Date TMD TVD MW 1 Press 1 Tot. press 1 EMW Field FIT 13/19/0311450'11450'19.6 ppg 1 500 Name Exploration Cumulative Cost psi 11,223.12 psi 1 16.24 ppg Current PU 5" drill pipe. Last Safety 3/23/03 BOP Tst 3/17/03 3/24/03 Status Meeting (Last I Next ) Event ODR Incident 1st 24 hrs? No Rig Accept: 3/8/02@ 00:00 Code _ Rig Release: @ : 24 HR Forecast TEST BOPE, P/U DP, TEST CSG & LOT Last TMD: INC: Azim: Last Casing Next Casing Survey 3/21/03 3,072 0.06 271.98 9.625 (in) @ 7 (in) @ 8000 3166 Operations Summary__ o From To Hours Phase Activity Subcod T i me lass r C ubleOperation p Continue running a total of 18 joints (10 more) 9 5/8" 47 ppf seal lock boss L -80 00:00 01:45 1.75 INTRM1 CASE RUNC p casing. MU 9 5 /8" 47 ppf seal lock boss L- 80 pin x 9 5/8" 47 ppf BTC L -80 box pup jpint . MU joint # 31 which is 40 ppf L -80 BTC. Circulate 9 5/8" casing while at shoe of 13 3/8 ", with Frank's fillup tool. Stage rate up 01:45 02:30 0.75 INTRMI CASE CIRC P to 7.5 bpm (90 spm) w/ 700 psi. Circ total of 2524 strokes (213.5 bbls) Continue to run 9 5/8" 40 ppf L -80 BTC 02:30 05:00 2.5 INTRMI CASE RUNC P casing f/ 1405' (joint # 31 to joint # 75) to 3133' Rig down Frank's fillup tool f/ top drive. 05:00 05:30 0.5 INTRM1 CASE RURD P Blow down top drive. MU FMC 9 5 /8" hanger w/ pup joint, make up landing joint w/ 9.75 4NA -20 Left hand 05:30 06:15 0.75 INTRMI CASE RUNC P thread. RIH f/ 3133' to 3164'. Appeared to have fill @ 3162'. RU Dowell Schlumberger cementing head, attatch cementing hose. Establish circulation, wash f/ 3162' to 3166.95' landed on hanger. Establish circ @ 4 bpm (53 spm) w/ 236 psi, stage up to 06:15 08:15 2 INTRM1 CEMENT CIRC P 5 bpm (60 spm) w/ 246 psi, final @ 5 bpm (60 spm) w/ 200 psi. Circ total of 6550 strokes (554 bbls), recip pipe 8' stroke (At 8.7' above landed position pulled up to http: //bizak. ak. ppco.com/npr- a_expl/puviaq /cgi- bin / reports /daily. asp ?wellname = Puviaq +... 3/26/2003 PAI Daily Drilling Page 2 of 2 i 280k - - -BOP stack). PU wt 185. SO wt 170K. PJSM w/ Dowell while circulating. Dowell pump 10 bbls CW 100 © 8.4 ppg, test lines to 2000 psi, pump 30 bbis CW 100, shut down, drop Davis Lynch anti rotation bottom plug, pump 61 bbls mudpush © 11.7 ppg w/ 4 bpm & 200 psi, 08:15 09:15 1 INTRM1 CEMENT PUMP P follow w/ 45.2 bbls(217 sx) class G w/ adds © 15.8 ppg @ 4 bpm, shut down, drop top Davis Lynch anti rotation plug, pump another 3 bbls(14 sx) class "G" cement w/ adds @ 15.8 ppg, follow w/ 7 bbls water. Rig displace cement w/ 9.7 ppg mud © 8 09:15 09:45 0.5 INTRM1 CEMENT DISP p bpm until 2500 strokes into displacement, slow pumps to 3 bpm, bump plug @ 2597 strokes, apply 1200 psi. 09:45 10:00 0.25 INTRM1 CEMENT OTHR P Hold pressure 5 min, bleed off to check floats. OK. 10:00 12:00 2 INTRMI CASE RURD P Rig down casing tools and cement tools. Drain stack. Continue rigging down casing tools. 12:00 13:00 1 INTRM1 CASE RURD P Change bales back to shorter drilling bales and attatch drill pipe elevators. PU /MU FMC 9 5/8" packoff on running and 13:00 15:00 2 INTRMI WELCTL OTHR P retrieving tool. Set packoff. RILDS. Test packoff to 5000 psi. OK. Pull FMC R &R tool, RU test joint. MU test plug, attempt to set test plug, wrong one, MU right test plug (13 1/2" 15:00 19:00 4 INTRMI WELCTL OTHR P OD), set test plug. Change rams f/ 9 5/8" to 3 1/2" x 6" variable top pipe and 5" lower pipe. Removecheck valve ball for testing ROPE: PU tools, fill stack and choke manifold w/ 19:00 21:00 2 INTRM1 WELCTL OTHR P water. Held PJSM. MU floor safety valve, dart valve and ported sub f/ testing. Test 13 5/8" BOPE & choke manifold. Testing all to 250 psi low and all but 21:00 00:00 3 INTRM1 WELCTL BOPE P annular to 5,000 psi high (annular to 3500 psi high). Chart test. Hold test for 5 min. Koomey test. 24 Hr. Continue run csg, m/u hgr & land, circ, r/u dowell, mix & pump 40 bbl chem wash, 61 bbl mud push, Sum: 45 bbl cmt, drop plug w/3 bbl cmt on top of plug, displace w /rig, bump plug, floats held, set packoff, r/u & test bope. Mud Data Mud 10sec / 10 FlowLine Drilling Company Type Density FV PV /YPmin / 30 min WL /HTHPMBT PH Temp Solids Gels KL Baroid polymer 9.65 47 16 / 16 5/29/39 7 / 0 7 11.9 70 6.1 Baroid Polymer_ 9.85 50 16 / 15 5/22/29 6 / 0 8 9.1 65 7.3 http: //bizak. ak.ppco.com/npr- a_expl /puviaq /cgi- bin/reports /daily. asp ?wellname= Puviaq +... 3/26/2003 0 ConocoPhillips Alaska Page 1 of 3 Cementing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 2 Report Date: 3/23/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Cement Job Type: Primary Primary Squeeze Open Hole Squeeze Casing Plug Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 3,167 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 3/23/2003 SQ Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing /Li SQ Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) SQ TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: Intermediate Casing /Li Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Carl Dacar Pipe Movement: Reciprocating Pipe Movement Rot Time Start: : Time End: : RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:06:15 Time End: 09:40 SPM: 1 Stroke Length: 8.0 (ft) Drag Up: 185 (lbs) Drag Down: 170 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 08:45 Disp Avg Rate: 8.00 (bbl /min) Returns: Full Volume Excess %: 10.00 Start Slurry Displ: 08:52 Disp Max Rate: 8.00 (bbl /min) Total Mud Lost: (bbl) Meas. From: none Start Displ: 09:12 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 09:42 Press Prior: 400 (psi) To Cementing: 2.00 End Pump Date: 3/23/2003 Press Bumped: 1,200 (psi) Ann Flow After: N Mud Circ Rate: 210 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Batch Mud Circ Press: 200 (psi) Bottom Plug: Y Float Held: Y Density Meas By: scales Mud Data Type: KCL Polymer Density: 9.8 (ppg) Visc: 50 (s /qt) PV/YP: 16 (cp) /15 (Ib/100ft Gels 10 sec: 5 (Ib/100ft Gels 10 min: 22 (Ib/100ft Bottom Hole Circulating Temperature:65 ( °F) Bottom Hole Static Temperature: 82 ( °F) Displacement Fluid Type:Mud Density: 9.8 (ppg) Volume: 230.00 (bbl) Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: CW100 Description: CW100 Class: Purpose: Slurry Interval: 1,132.00 (ftjto: 1,763.00 (ft) Cmt Vol: 40.0 (bbl) Density: 8.40 (ppg) Yield: (ft /sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other VoI:40 0 Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Printed: 3/26/2003 8:57:48 AM • 10 ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 2 Report Date: 3/23/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: Mudpush XL Description: MUDPUSH XL Class: Purpose: SPACER Slurry Interval: 1,763.00 (ft)To: 2,666.00 (ft) Cmt Vol: (bbl) Density: 11.70 (ppg) Yield: (ft /sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol:6,148 () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: Cement Class G Description: Cement Class G Class: G Purpose: ZONAL ISOL Slurry Interval: 2,666.00 (ftjro: 3,166.00 (ft) Cmt Vol: 48.2 (bbl) Density: 15.80 (ppg) Yield: 1.17 (ft /sk) Mix Water: 5.09 (gal) Water Source: MO207 Slurry Vo1231 (sk) Water Vol:28.0 (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: ( °F) Compressive Strength 1: ( °F) (psi) Free Water: ( %) Temperature: ( °F) Compressive Strength 2: ( °F) (psi) Fluid Loss: (cc) Temperature: ( °F) Fluid Loss Pressure: ( °F) Stage No: 1 Slurry No: 3 of 3 - Additives Trade Name Type Concentration Units Liquid Conc. Units S1 ACCELERATOR 1.50 %BWOC D -65 DISPERSANT 0.30 %BWOC D -46 DEFOAMER 0.20 %BWOC Printed: 3/26 /2003 8:57:48 AM ConocoPhillips Alaska Page 3 of 3 Cementing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 2 Report Date: 3/23/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Casing Test Shoe Test Liner Top Test Test Press: (psi) Pressure: (ppge) Liner Lap: For: (min) Tool: Pos Test: (ppge) Tool: Cement Found between Open Hole: (ft) Neg Test: (ppge) Tool: Shoe and Collar: Hrs Before Test: Hrs Before Test: Cement Found on Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Cement Top: (ft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: Cet Run: Job Rating: Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: Remedial Cementing Required: Hrs Prior to Log: Number of Remedial Squeezes: Remarks Establish circulation, wash f/ 3162' to 3166.95' landed on hanger. Establish circ @ 4 bpm (53 spm) w/ 236 psi, stage up to 5 bpm (60 spm) w/ 246 psi, final @ 5 bpm (60 spm) w/ 200 psi. Circ total of 6550 strokes (554 bbls), recip pipe 8' stroke (At 8.7' above landed position pulled up to 280k - - -BOP stack). PU wt 185. SO wt 170K. PJSM w/ Dowell while circulating. Dowell pump 10 bbls CW 100 a 8.4 ppg, test lines to 2000 psi, pump 30 bbls CW 100, shut down, drop Davis Lynch anti rotation bottom plug, pump 61 bbls mudpush @ 11.7 ppg w/ 4 bpm & 200 psi, follow w/ 45.2 bbls(217 sx) class G w/ adds @ 15.8 ppg @ 4 bpm, shut down, drop top Davis Lynch anti rotation plug, pump another 3 bbls(14 sx) class "G" cement w/ adds @ 15.8 ppg, follow w/ 7 bbls water. Rig displace cement w/ 9.7 ppg mud © 8 bpm until 2500 strokes into displacement, slow pumps to 3 bpm, bump plug © 2597 strokes, apply 1200 psi. Hold pressure 5 min, bleed off to check floats. OK. Printed: 3/26/2003 8:57:48 AM ConocoPhillips Alaska Page 1 of 2 Casing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 2 Report Date: 3/23/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: General Information String Type: Intermediate Casing /Liner Permanent Datum: Kelly Bushing Hole Size: 12.250 (in) Hole TMD: 3,175.0 (ft) Hole TVD: 3,175.0 (ft) KB- Datum: 56.00 (ft) Water TMD: (ft) Str Wt on Slips: 185,000 (Ibs) Ground Level: 26.00 (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 0.31 ( °) • Circ Hours: 2.00 (hr) Mud Lost: (bbl) KB to Cutoff: 29.33 (ft) Days From Spud: 15.50 (days) Casing Flange / Wellhead Manufacturer: FMC Model: 5K Top Hub /Flange: (in) / 5,000 (psi) Hanger Model: P 143329 A Packoff Model: P100371 -0002 BTM Hub /Flange: (in) / (psi) Actual TMD Set: 3,166.95 (ft) Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer Model Cond. Max OD Min ID Comp. Name (in.) (Ib /ft) (in) (ft) (ft) (ft - ibf) (in) (in) Casing Hanger 9.625 SL BOSS 1.51 29.33 N FMC P 143329A NEW 13.062 8.679 Casing Hanger Casing - Pup Jt 9.625 40.00 L -80 8.679 BTC 2.87 30.84 N US Steel NEW 9.625 8.679 9 5/8" 40# L -80 Casing 9.625 40.00 L -80 8.679 BTC 45 1,727.97 33.71 US Steel NEW 9.625 8.835 9 5/8" 40# L -80 Cross Over 9.625 47.00 L -80 8.525 BTC x BOSS 9.79 1,761.68 US Steel NEW 9.625 8.681 Cross Over Casing 9.625 47.00 L -80 8.525 BOSS 18 837.39 1,771.47 US Steel NEW 9.625 8.525 9 5/8" 47# L -8 Casing 9.625 53.50 L -80 8.379 BOSS 10 461.33 2,608.86 US Steel NEW 9.625 8.535 9 5/8" 53.5# L -8 Float Collar 9.625 53.50 L -80 8.500 BOSS 2.28 3,070.19 Y DAVIS LYNCH Type 700 -LAP /N NEW 10.680 8.535 Float Collar Casing 9.625 53.50 L -80 8.379 BOSS 2 91.83 3,072.47 Y US Steel NEW 9.625 8.535 9 5/8" 53.5# L -8 Float Shoe 9.625 53.50 L -80 8.500 Boss 2.65 3,164.30 Y DAVIS LYNCH Type 501 DV PVT NEW 10.690 8.535 Float Shoe 9.625 53.50 L -80 3,166.95 10.690 bottom of shoe Non - Integral Casing Accessories Accessory Manufacturer Number Spacing Interval How Fixed (ft) Top (ft) Bottom (ft) Bowspring Centralizer WEATHERFORD 3 OverCollar Stop Collars WEATHERFORD 3 Bolted Bowspring Centralizer WEATHERFORD 7 OverCollar Printed: 3/26/2003 8:58:10 AM ConocoPhillips Alaska Page 2 of 2 Casing Report Legal Well Name: Puviaq #1 Spud Date: 3/8/2003 Common Well Name: Puviaq #1 Report #: 2 Report Date: 3/23/2003 Event Name: ROT - DRILLING Start: 1/17/2003 End: Remarks MU Davis Lynch type 501 float shoe, (2 joints) 9 5/8" 53.5 ppf seal lock boss L -80 casing, Davis Lynch type 700 float collar, (10 joints) 9 5/8" 53.5 ppf seal lock boss L -80 casing, (8 joints) 9 5/8" 47 ppf seal lock boss L -80 casing. Total of 20 joints casing in hole CO midnight 931.80' Continue running a total of 18 joints (10 more) 9 5/8" 47 ppf seal lock boss L -80 casing. MU 9 5/8" 47 ppf seal lock boss L -80 pin x 9 5/8" 47 ppf BTC L -80 box pup jpint . MU joint # 31 which is 40 ppf L -80 BTC. Circulate 9 5/8" casing while at shoe of 13 3/8 ", with Frank's fillup tool. Stage rate up to 7.5 bpm (90 spm) w/ 700 psi. Circ total of 2524 strokes (213.5 bbls) Continue to run 9 5/8" 40 ppf L -80 BTC casing f/ 1405' (joint # 31 to joint # 75) to 3133' Rig down Frank's fillup tool f/ top drive. Blow down top drive. MU FMC 9 5/8" hanger w/ pup joint, make up landing joint w/ 9.75 4NA -20 Left hand thread. RIH f/ 3133' to 3164'. Appeared to have fill @ 3162'. RU Dowell Schlumberger cementing head, attatch cementing hose. Establish circulation, wash f/ 3162' to 3166.95' landed on hanger. Establish circ @ 4 bpm (53 spm) w/ 236 psi, stage up to 5 bpm (60 spm) w/ 246 psi, final @ 5 bpm (60 spm) w/ 200 psi. Circ total of 6550 strokes (554 bbls), recip pipe 8' stroke (At 8.7' above landed position pulled up to 280k - - -BOP stack). PU wt 185. SO wt 170K. PJSM w/ Dowell while circulating. Printed: 3/26/2003 8:58:10 AM l PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: Puviaq # 1 I Rig: Nabors �'r 16E Date: 3/19/2003 Volume Input I Volume /Stroke Pump Rate: Drilling Supervisor: Ray Springer/ Granville Rizek Pump used: BOP Test Pump v Strokes 0.8160 Gal /Strk Strk/min Type of Test: Casing Shoe Test LOT /FIT v Pumping down drillpipe. v __ Casing Test Pressure Integrity Test Hole Size: 12 -1/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 31.8 Ft ,423 Ft -MD 1,423 Ft -TVD 1,450 Ft -MD 1,450 Ft -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: Other - See Comments v 0 0 `'530 0 490 Casing Test Pressure IntegritvTest 540 1 _330 5C 0.25 490 Mud Weight: 9.6 ppg Mud Weight: ppg 70 2 2620 6C 0.5 480 Mud 10 min Gel: Lb /100 Ft2 Mud 10 min Gel: it 3.. Lb /100 Ft2 05 1500 3 ^620 h. 9C 1 480 Test Pressure: 2,630 psi Rotating Weight: 14.5,000 Lbs 87 2000 4 _o20 14 95 1.5 475 h Blocks/Top Drive Weight: .000 Lbs _ 1 09 2630 5 2620 16 100 2 465 Rotating Weight: 000 Lbs B s/T e 9 9 � p Blocks/Top Drive Weight: 65,000 Lbs Desired PIT EMW: 16.0 ppg 6 2610 18 100 2.5 4F' Estimates for Test: #REFI als Estimates for Test: 474 psi #REF! 7 2610 20 105 3 45_ � - L J 8 2600 22 110 3.5 450 EMW = Leak -off Pressure + Mud Weight = 500 PIT 15 Second 9 X00 24 115 4 -140 0.052 x TVD 0.052 x 1423 + 9.6 Shut -in Pressure, psi 10 80 26 ' ^5 4.5 440 EMW at 1423 Ft -MD (1423 Ft -TVD) = 16.4 ppg 490 15 4560 28 ,30 5 430 3000 - Lost 100 psi during test, held - 20 2540 30 175 5.5 425 - - 96.2% of test pressure. - 25 2535 32 190 6 4 - - - - - -- 30 2530 205 6.5 415 2500 3, ?10 7 410 38 7.5 405 2000 40 250 8 400 w 42 275 8.5 400 44 300 9 400 N 1500 46 310 9.5 395 w 48 330 10 395, a 50 375 1000 52 390 " 410 450 500 illiftrailftla 58 470 60 480 0 , i 62 500 . , 0 0 10 20 30 40 50 60 70 80 90 100 0 5 10 15 20 25 30 Gallons Shut - time, Minutes Volume Volume V Volume ■CASING TEST (LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 88.9 Gals Gals 50.6 Gals 40.0 Gals Comments: 13 3/8" 72 ppf, L -80 al lock Br Casing Test Puviaq # 1 3500 • • 3000 • 2500 • • • W 2000 re Li) cc N a 1500 1000 • • 500 •,— #REF! • 0 0 20 40 60 80 100 120 140 160 180 200 Gallons tea— CASING TEST — — — —Minimum Compressibility Maximum Compressibility mRequired Test Pressure - - - •Best Slope Fit Pressure Integrity Test Puviaq # 1 1500 ' r —a—Casing Test / — — — — Theoretical Minimum / Volume / 1 1 Anticipated Leak -off / Pressure / —M—Leak-off Test / Theoretical Maximum / Volume 0 FIT T Point III 1000 1 / — — Maximum Pressure / W / N i W / cc / a / r / 500 / O r r / r III 1 i 0 , 0.0 50.0 100.0 150.0 200.0 250.0 Gallons PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: Puviaq # 1 I Rig: Nabors Rig 16F Date: 3/24/2003 Volume Input Volume /Stroke Pump Rate: Drilling Supervisor: Ray Springer/ Granville Rizek Pump used: BOP Test Pump I —_1 v Strokes II 0.8160 1 Gal /Strk V 10.0 Strk /min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down a nnulus. V '' 1 p g Casing Test Pressure Integrity Test Hole Size: USE PICK LIST V Casing Shoe Depth 1 Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 31.8 Ft , 1,423 Ft -MD i, -12,5 Ft -TVD 2,666 Ft -MD oou Ft -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: I 1 USE PICK LIST v 0 0 0 2630 0 0 160 Changes for Annular Adequacy Test Pressure IntegrityTest 22 540 1 ;30 8 0.25 150 Enter outer casing shoe test results in comments Mud Weight: ppg 1070 2 2620 2i.; , 0.5 140 Casing Description references outer casing string. Inner casing OD: In. ;3 1500 3 2620 30 J0 1 130 Hole Size is that drilled below outer casing. 87 2000 4 2620 40 160 1.5 125 Use estimated TOC for Hole Depth. 109 2630 5 320 50 150 2 1- . Enter inner casing OD at right. Desired PIT EMW: ppg 6 2:6- 60 200 2.5 1 kJ Estimates for Test: 481 psi -18 gals 7 26 7(` 225 3 105 �I- L . 8 2600 3.5 100 EMW = Leak -off Pressure + Mud Weight = Go to PIT Plot. + 9.5 PIT 15 Second 9 26" 9�. 34u 4 100 0.052 x TVD 0.052 x 1423 Shut -in Pressure, psi 10 258, 100 390 4.5 95 EMW at 1423 Ft -MD (1423 Ft -TVD) = # # ## 150 15 2560 110 410 5 95 3000 . Lost 100 psi during test, held 20 340 120 -3 5.5 90 96.2% of test pressure. 25 335 130 405 6 80 •www.•vm■mm 30 2530 140 305 6.5 2500 " 15C 285 7 250 7.5 65 III, 0 8 60 2000 180 0 8.5 55 Lu cc 190 210 9 50 N 1500 200 200 9.5 45 w 210 200 10 450 a 220 200 1000 230 195 ?40 195 190 500 . • , .1 26 190 ■ ■ - r 270 170 o( — 272 170 0 50 100 150 200 250 0 5 10 15 20 25 30 274 160 Gallons Shut - time, Minutes o ume Volume Volume Volume CASING TEST —II—LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 88.9 Gals Gals 223.6 Gals Gals Comments: 16.4 ppg test on 13 3/8" casing shoe Pressure Integrity Test Puviaq # 1 1500 fil / / — a—Casing Test / I — — — — Theoretical Minimum / Volume / Anticipated Leak -off Pressure / —M—Leak-off Test / Theoretical Maximum iii / Volume / 0 FIT Point Mr 1000 i — — Maximum Pressure w / v) / v) / w / a ' 1 I 500 �' / i r I .' 7......11."---14 0 1 0 1,1 1 i 0.0 50.0 100.0 150.0 200.0 250.0 Gallons • ConocoPhillips Alaska, Inc. P. O. BOX 100360, ATO -1454 ANCHORAGE, ALASKA 99510 -0360 Telephone 907 - 265 -1505 Facsimile 907- 263 -4966 To: Commissioner, AOGCC From: Wayne Campaign Petrophysicist Subject: Shallow Injection in Puviaq Date: March 26, 2003 This letter will present the case for shallow injection in the annulus of the subject well. Surface casing was set in this well to a depth of 1430', within the sandy section of the Nanushuk interval. Drilling continued to a depth of 3175', where 9 5/8" casing was set and cemented. Calculated top of cement is at 2667'. The formation is open to the annulus from 1430' to 2667', contains several sands, and is the focus of this document. We acquired LWD Neutron /Density /Resistivity /GR logs over this section of the hole and have analyzed them for lithology, porosity, and salinity using standard petrophysical techniques. I define sands as less than 35% shale and effective porosity > 15 %. I have also calculated permeability with an algorithm developed from Nanushuk rotary cores in another NPRA well. Results are presented on the attached plot. Within the given criteria and interval, I have calculated 103' of net sand. Salinities are > 20 Kppm throughout the interval. Effective porosity ranges 15 => 28% (average of 20.5 %) and average perm is > 60 md. In conclusion, there is no fresh water within this interval and enough sands are present to easily handle the fluids. If you have questions or comments, feel free to contact me. Thank You. Wayne Campaign Principal Petrophysicist 1. Puviaq Progress Report- CONFIDENTIAL o Subject: Puviaq Progress Report- CONFIDENTIAL Date: Fri, 21 Mar 2003 18:27:59 -0900 From: "Tom J Brassfield" < Tom. J .Brassfield @conocophillips.com> To: greg_noble @ak.blm.gov, Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Paul Mazzolini" < Paul .Mazzolini @conocophillips.com> Greg/Tom, apologize for the dealy in updating our progress. Spudded the Puviaq well on 3/8/03. Ran & cemented 13 -3/8" to 1423' MD. Stab -in cement job, good returns throughout job, cement to surface. Took 5.2 days to NU & test BOPE's. Tested casing to 2500 psi- good test. Drilled firm cement from top of FC to FS. Drilled out & 5' of new hole, performed LOT. Drilled another 15', performed a 2nd LOT. Currently drilling ahead, looking for casing point very close to permitted depth. Thanks, Tom 265 -6377 (w) 275 -7352 (p) 265 -6916 (f) 1 of 1 4/7/2003 10:37 AM Re: Puviaq Surface Casing 1 Subject: Re: Puviaq Surface Casing Date: Tue, 11 Mar 2003 11:31:05 -0900 From: Tom Maunder <tom_maunder @admin.state.ak.us> To: Tom J Brassfield <Tom.J.Brassfield @conocophillips.com> CC: greg_noble @ak.blm.gov, Paul Mazzolini < Paul .Mazzolini @conocophillips.com >, AOGCC North Slope Office < aogcc_ prudhoe_bay @admin.state.ak.us >, Jim Regg <jim_regg @admin.state.ak.us> Thanks much Tom. I will put this note into the file. As discussed, please have Ray stay in touch with Chuck on the slope so the arrangements can be made to get to the site for the BOP test. Tom Maunder, PE AOGCC Tom J Brassfield wrote: > Tom /Greg, just a quick update on the Puviaq operation. > Spuded well 1200 hrs 3/8/03 > Drilled to surafce casing shoe at 1430' 3/11/03. Note: this is approx. > 130' deeper than noted in the PTD's. Required to find a decent shale > below the permafrost. > Upcoming operations: make wiper trip this afternoon- run & cement > 13 -3/8" casing tonight/tomorrow. > Thanks, Tom > 265 -6377 (w) > 275 -7352 (p) > 265 -6916 (f) Tom Maunder <tom maunder(aadmin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 3/11/2003 11:32 AM FRANK H. MURKOWSKI, GOVERNOR 40 To[E ALASKA OIL AND GA 333 W. 7"' AVENUE, SUITE 100 II CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Paul Mazzolini Drill Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage Alaska 99510 Re: NPRA Puviaq #1 ConocoPhillips (Alaska), Inc. Permit No: 202 -248 Surface Location: 1703' FNL, 451' FWL, Sec. 35, T16N, RIOW, UM Bottomhole Location: 1703' FNL, 451' FWL, Sec. 35, T16N, RIOW, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Weekly drilling progress reports must be supplied to Mr. Thomas Maunder at the letterhead address. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty -four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659 -3607 (pager). Sincerely, Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this G '-'` day of January, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • STATE OF ALASKA W A ‘' qS ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill 0 Redrill ❑ ib. Type of well. Exploratory Q Stratigraphic Test ❑ Development Oil ❑ Re -entry Deepen ❑ Service ❑ Development Gas ❑ Single Zone ❑ Multiple Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ConocoPhillips Alaska, GL 26 & 30' RKB feet 3. Address 6. Property Designation Exploration P.O. Box 100360 Anchorage, AK 99510 - 0360 AA081854 / L32589 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1703' FNL, 451' FWL Sec. 35, T16N - R1OW, UM Exploration NPRA Statewide At top of productive interval 8. Well number Number 1703' FNL, 451' FWL, Sec. 35, T16N UM Puviaq #1 #59 - 52 - 180 At total depth 9. Approximate spud date Amount 1703' FNL, 451' FWL, Sec 35, T16N - R1OW, UM February 1, 2003 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1762 @ TD feet South Simpson #1, 15 miles 5120 8000 ' MD / 8000 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: na MD Maximum hole angle 0 deg° Maximum surface 3201 psig At total depth (TVD) 4160 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H -40 PEB 80' Surface Surf. 136' 136' 250 sx AS I 16" 13.375" 72# L -80 Boss 1244' Surf. Surf. 1300' 1300' 480 sx AS III Lite & 210 sx AS1 12.25" 9 -5/8" 40# L -80 BTC 1844 Surf. Surf. 1900 1900 300 sx Class G+ additives 12.25" 9 -5/8" 47# L -80 Boss 740 1900 1900 2640 2640 12.25" 9 -5/8" 53.5# L -80 Boss 560 2640 2640 3200 3200 8.5" 7" 26# L -80 BTC 7944 Surf Surf. 8000 8000 540 sx Class G+ additives 19. To be completed for Redrill, Re -entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED DEC 17 2002 Perforation depth: measured Malta Oil & Gas Cans" Commission ncliorif'itr true vertical 20. Attachments Filing fee 0 Property Plat ❑ BOP Sketch ❑ Diverter Sketch ❑ Drilling program 0 Drilling fluid program El Time vs depth plot Detraction analysis Q Seabed report ❑ 20 AAC 25.050 requirements ❑ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Tom Brassfield 265 - 6377 Signed Q✓3(t Title: Drilling Team Leader Date 12/g. /?.0 1 Paul Mazzolini / T.IR Commission Use Only Permit Number API number p� Approval date See cover letter 2-62. ^ 29'g 50- '2', / - 20608 - b) , i, � l v ', for other requirements Conditions of approval Samples required % Yes ❑ No Mud log required t ' Yes ❑ No Hydrogen sulfide measures ❑ Yes No Directional survey required ❑ Yes ® No Required working pressure for BOPE 02M; ❑ 3M; [X 5M; ❑ 10M; ❑ ❑ XI .c.It►, ♦'zow S()f' �l �'.it fr • Other: J 4 � ORIGINAL SIGNED BY by order of i , , 1 /t Approved by M L Bill Commissioner t the commission Date 1 L L !) Form 10 -401 Rev. 12/1/85 • 0 $ 1 ; . 4 i 1 f ' L Submit in triplicate ConocoPhillips Alaska, Inc Drill and Case Plan for Puviaa #1 General Procedure: 1. Mobilize CATCO to Puviaq and construct ice airstrip and drilling pad. Set the 10' diameter cellar. Move Nabors 16E from the oversummering ice pad to the Puviaq drilling pad. Set 80' -20" conductor (driven or drilled /cemented) 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 16" hole to the surface casing point at 1300' MD /1300' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 13 -3/8" 72# L80 Boss casing string to surface. • Employ lightweight permafrost cement lead slurry and Dowell Arcticset 1 15.7 ppg tail slurry to assure cement returns to the surface in a one -stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 12 -1/4" bit and BHA and RIH to top of float equipment • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 8. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 16 ppg equivalent) • Record results and fax to town 9. Drill 12 -1/4" hole to ±3200' MD / ±3200' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Run mixed string of 9 -5/8" 53.5/47/40 ppf L -80 Boss /BTC intermediate string. Cement casing to bring cement ±700' above 9 -5/8" shoe. 11. Make up 8 -1/2" bit and BHA and RIH to top of float equipment • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 12. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 16 ppg equivalent) • Record results and fax to town 13. Drill wellbore to ±8000' MD / ±8000' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. • Condition hole and mud for e-line logs. 14. Log 8 -1/2" wellbore as required. 15. Run and cement 7" 26# L80 BTC -M production string. 16. Make a cleanout run with bit and scrapers • Displace to filtered seawater • Pressure test well to 3000 psi for 30 minutes • Record results and fax to town 17. Run and land 3 -1/2" tubing with gas lift completion 18. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 19. Secure well, release rig. 0 ; " I i, ;i1 1 L ConocoPhillips Alaska, Inc, 20. MI well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or transported to Kuparuk or Alpine production facilities. 21. Upon completion of testing or if the well is not completed, plug and abandon the well per applicable regulations. Thoroughly dean location and secure wellhead if needed. Or-i1:1;;IAL ConocoPhillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Puviaq #1 Drilling Fluid Properties: Spud to surface Drill out Production Hole casing point to 9 -5/8" Csg point (Intermediate shoe to TD Density 10 ppg 9.5 — 10.2 ppg 10.5 - 11 ppg PV 13 -23 8 -24 14 -24 YP 20 -45 10 -26 18 -26 Funnel Vis 50 - 100 40 - 65 40 — 65 Initial Gel 10 -15 4 -8 4 -8 lO Minute Gel 14 - 24 6 — 14 6 — 14 API Filtrate 5 - 15 < 6 <6 pH 8.5 — 9.5 9.0 — 9.5 9.0 — 9.5 % Solids ± 10% ± 10% ± 10% Drilling Fluid System: Equipment on file with AOGCC for Nabors 16E. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Pore Casing Casing Fracture Pressure Pore Size Setting Depth Gradient Gradient Pressure MASP Drilling 20" 136' MD / 136' TVD 11.0 ppq 9.0 ppq 64 NA 13 -3/8" 1300' MD / 1300' TVD 12.8 ppg 9.0 ppq 608 63 psi 9 -5/8" 3200' MD / 3200' TVD 14.6 ppg 9.0 ppg 1498 722 psi 7" 8000' MD / 8000' TVD 17.6 ppg 10 ppg 4160 3201 psi Expected Maximum Mud Weights: 16" surface hole to 1300' MD / 1300' TVD: 10.0 ppg 12 -1/4" hole to 3200' MD / 3200' TVD: 10.2 ppg 8 -1/2" production hole to 8000' MD / 8000' ND: 11.0 ppg (for shale stabilization) , ,a >, . ConocoPhillips Alaska, Inc Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the 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) MASP = [(FG x 0.052) — 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi /ft 0.11 = Gas Gradient in psi /ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP — (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 20" Conductor Casing MASP = [(FG x 0.052) — 0.11] x D = [(11.0 x 0.052) — 0.11] x 136' = 63 psi OR MASP = FPP — (0.11 x D) = 608 — (0.11 x 1300') = 465 psi 2. Drilling below 13 -3/8" Surface Casing MASP = [(FG x 0.052) — 0.11] x D MASP = [(12.8 x 0.052) — 0.11] x 1300' MASP = 722 psi OR MASP = FPP — (0.11 x D) = 1498 — (0.11 x 3200') = 1146 psi 3. Drilling below 9 -5/8" Intermediate Casing MASP = [(FG x 0.052) — 0.11] x D MASP = [(14.6 x 0.052) — 0.11] x 3200' MASP = 3201 psi OR MASP = FPP — (0.11 x D) = 4160 — (0.11 x 8000') = 3280 psi ConocoPhillips Alaska, Inc. Casing Design Performance Properties Size Weight Internal Tensile Strength Grade Connection Yield Collapse 20" 94 ppf H -40 PEB Conductor Casing Joint Body 13 -3/8" 72 ppf L -80 Boss 5380 psi 2670 psi 1973 M 1661 M 9 -5/8" 53.5 ppf L -80 Boss 7930 psi 6620 psi 1244 M 1477 M 9 -5/8" 47 ppf L -80 Boss 6870 psi 4760 psi 1086 M 1289 M 9 -5/8" 40 ppf L -80 BTC 5750 psi 3090 psi 947 M 916 M 7" 26 ppf L -80 BTC -M 7240 psi 5410 psi 641 M 604 M 3 -1/2" 9.3 ppf L -80 EUE 10160 psi 10530 psi 207 M 207 M Casing Setting Depth Rational: 20" @ 136' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 13 -3/8" @ 1300' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling intermediate 12 -1/4" hole to 3200'. Designed to be set approx. 300' MD below base of the permafrost. 9 -5/8" @ 3200' MD RKB Intermediate casing is being set in a shale zone below the base of the Nanushuk. This should leave open sufficient sand intervals between the 13 -3/8" & 9 -5/8" shoes for annular injection without having to drill a long section of 12 -1/4" hole. 7" @ 8000' MD RKB Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if Togs indicate the well is a dry hole. Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Puviaq #1 area are surface interval clays /gravels and lost circulation, intermediate interval shales and lost circulation, and lost circulation /breathing potential above and through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached drilling hazards summary. See attached mud weight versus depth graph for the offset wells South Simpson #1 and Ikpikpuk #1. Mud /Cuttings Disposal and Annular Disposal: All cuttings generated will be stored temporarily on site and hauled to the Prudhoe Bay Field for eventual processing for injection down an approved disposal well. Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well i.e. either Alpine or Kuparuk 110 to 145 Rolligon miles away. As mentioned above, to reduce fluid hauling time and to reduce the potential for waste drilling fluid spills; CPAI is planning to make the Conoco Phillips Alaska, Inc. 13 -3/8" by 9 -5/8" annulus available for drilling waste disposal early in the drilling program. GR/Resistivity/Neutron /Density LWD logs are planned thru the intermediate 12 -1/4" hole to provide the necessary technical analysis to meet the requirements of 20 AAC 25.080. CPAI will be submitting an application for Sundry Approval for annular disposal as soon as the required data is available. The Puviaq #1 surface /intermediate casing annulus will be freeze protected with diesel after setting intermediate casing and prior to the drilling rig moving off of the well as required. Geology: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE, psi Permafrost 1000' 200' 468 Base Nanushuk/Top Torok 2900' 200' 1357 Base Topsets 3615' 200 1692 Top Torok Fan 6000' 200 Possible Oil or Gas 2808 Base Torok Fan 6495' 200 3107 LCU 6810' 200 3364 Top Simpson Sand 7200' 150 Probable Oil and /or 3744 Gas J2 7520' 150 3949 TD 7944' 4131 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 — Surface Casino etting depth) LWD: GR/Res iWeutron/Density ;1. 7 7 o 12 -1/4" Intermediate Hole (Surface Casing setting depth to 3200' MD) LWD: GR/Res /Neutron /Density 8 -1/2" Production Hole (3200' to TD) LWD: GR/Resistivity/Neutron /Density Wireline: GR/Res/PEX/Dipole Sonic /CMR/FMI (Contingency: MDT /RSWC /Percussion /VSP) II. Coring Full Diameter 4" Core in Top Torok Fan and /or Simpson Sands (1 — 2, 90' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful III. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Sixty-foot (60') wet and dry samples will be collected from surface to 4500' subsea. Thirty-foot (30') wet and dry samples will be collected from 4500' subsea to well TD and ten -foot (10') wet and dry samples, or continuous, collected across hydrocarbon shows. I1 1 410 ConocoPhillips Alaska, Inc! IV. Flow Testing (Contingency Operaqtion) Flow testing and pressure build -up tests may be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build -up. The flow period will be determined on -site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be moved to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build -up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. Oh ti ConocoPhillips Alaska, Inc Puviaq #1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13 -3/8" Casing Interval Event Risk Level Mitigation Strategy Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, increased circulating times, controlled drilling rates, low mud temperatures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, controlled running speeds. 12 -1/4" & 8 -1/2" Hole Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre - planned LCM pills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Sloughing Shale, Tight Medium Increased mud density and fluid Hole composition according to plan, controlled trip speeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Pt Li 1411 GI 6 1 ...., 1.„-- APPROVED Plan C ono c xP h i IIip s SHL (1703' FNL & 450' FWL, SEC. 36- T16N -R10W) ConocoPhillips Alaska, Inc. North Slope, Alaska 0 - - - - - - NPRA (Exploration) 20' Conductor , 136.00 MD 136.00' TVD Puviaq 1 (wp01) Begin Drilling ... Maintain Vertical in 16" Hole: 600.00 136.00ft MD, 136.00ft TVD Scale: 1 inch = 100ft 1000 - - -100 0 100 Bernurlrost, 1056.00 I I 1 1200 . 00 13-3/8' Casing 2 1300.00 MD 1300.00 TVD 13 -3/8" Csg Pt ... Drill out 12 -1/4" Hole: 1800 00 1300.00ft MD, 1300.008 TVD Puviaq 1 Target Square, Sides: 300.008, 100 - Thickness: 1800.008 - 100 =t 2000 - 6056.00 TVD, 0.00 N, 0.00 E 1 O 2300.00 b V - Z ti. M 2900.00 0 - - ♦ - - - 0 0 J co 3000 Base Nannslluk /Top Tory k 2956.00 9 5B Casing 0) v 3200.00 i 3200.00 9-5/8" Csg Pt ... Drill out 8 -1/2" Hole: 1 t 3500.00 3200.008 MD, 32008 TVD Z Y CC Base Topsets. +7,71.00 .0 -100 - - -100 Q 4000 - o 7, II RTI V c r > I I m 4700.00 - o - 100 0 100 r j C • d 5000 - Eastings(1703' FNL, 450 FWL) 8 5300.00 -- Target Top: 6056.008 MD, 6056.0011 TVD {I� 5900.00 (1703' FNL & 450' FWL, SEC. 35- T16N -R10W) -4- 6000 - 7bpYorokFan, 6056.r - Reference is True North Current Well Properties _ Well : Puviaq 1 Base Torok Fan, 656.55°I.'17 Puviaq 1 Target Horizontal Coordinates: Ref. Global Coordinates : 6105710.00 N, 450554.00 E Square, Sides 300.00ft, Ref. Geographical Coordinates : 70° 41' 58.5335" N, 150° 24' 30.3052° W !.(b. 6866.00 Thickness: 1800.00ft 1703' FNL 8 450' FWL, SEC. 35 - T16N - R1OW 0 7000 - 0 710. 6056.00 TVD, 0.00 N, 0 RKB Elevation : 56.008 above Mean Sea Level �� 30.00ft above GL Elev. 26 MSL Top Simpson Sand, 72.6.0 North Reference : True North .5 Units : Feet (US) c, 1.7576 . .r'rt 770 00 Target Bottom: 7856.008 MD, 7856.0011 TVD 00 ( 1 &450'FWL,SEC.35- T16N -R1OW) SI:Mr 7' Casing Ofti4 Lthiti SEIR3lICUS 8000 - 8000. MD Total Depth : 8000,008 MD, 8000.0011 TVD 8000.00' TVD (1703' FNL & 450' FWL, SEC. 35 -T16N- R10W ) IIlticln °°- 11f11j @;" I I -1000 0 1000 Scale: 1inch = 1000ft DrillQuesl 3.03.02.002 0 Fl I GliVAL ConocoPhillips Alaska, Inc. Puviaq 1 (wpO1) MD Inc Azim. SSTVD TVD N/S EMI Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) (ft) 0.00 0,00 0.00 -56.00 0.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 SHL 136.00 0.00 0.00 80.00 136.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Begin Drilling ... Maintain Vertical in 17 -1/2" Hole 1056.00 0.00 0.00 1000.00 1056.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Permafrost 1300.00 0.00 0.00 1244.00 1300.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 13 -3/8" Csg Pt ... Drill out 12 -1/4" Hole 2956.00 0.00 0.00 2900.00 2956.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Base Nanushuk / Top Torok 3200.00 0.00 0.00 3144.00 3200.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 9 -5/8" Csg Pt ... Drill out 8 -1/2" Hole -„ 3671.00 0.00 0.00 3615.00 3671.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Base Topsets 6056.00 0.00 0.00 6000.00 6056.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0 .00 0.00 Top Torok Fan (Target Top) 1 6551.00 0.00 0.00 6495.00 6551.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Base Torok Fan .. 6866.00 0.00 0.00 6810.00 6866.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 LCU - . 7256.00 0.00 0.00 7200.00 7256.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Top Simpson Sand .:., " ,�. 7576.00 0.00 0.00 7520.00 7576.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 J2 ` 7856.00 0.00 0.00 7800.00 7856.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Target Bottom I"""' 8000.00 0.00 0.00 7944.00 8000.00 0.00 N 0.00 E 6105710.00 N 450554.00 E 0.00 0.00 Total Depth III Puvia. Schlumberger Cern - ° DE Preliminary Job besign ` 13 3/8" Surface Casin Preliminary Job Design based on limited Input data. For estimate purposes only Rig: Nabors 16 Volume Calculations and Cement Systems Location: Wildcat Volumes are based on 350% excess in the permafrost and 45% excess below the Client: ConocoPhillips Revision Date: 12/6/2002 permafrost. The top of the tail slurry is designed to be at 1,100' MD. Prepared by: Mike Martin Location: Anchorage, AK Lead Slurry Minimum pump time: 210 min. (pump time plus 90 min.) Phone: (907) 265 -6205 ARCTICSET Lite @ 10.7 ppg - 4.28 ft3 /sk Mobile: (907) 229 -6012 email: martin13@slb.com 1.0190 ft /ft x (80') x 1.00 (no excess) = 81.5 ft 0.4206 ft /ft x (1100' - 80') x 4.50 (350% excess) = 1930.6 ft < TOC at Surface 0.4206 ft /ft x (1100' - 1100') x 1.45 (45% excess) = 0 ft 81.5 ft + 1930.6 ft 0 ft = 2012.1 ft 2012.1 ft 4.28 ft /sk = 470.1 sks Round Ann 1-� nuurIu up to 'FO J sks Have 430 sks of additional Lead on location for Top Out stage, if necessary. Previous Csg. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) s < 20 ", 91.5# casing ARCTICSET 1 @ 15.7 ppg - 0.93 ft3 /sk at80'MD 0.4206 ft /ft x (1300' - 1100') x 1.45 (45% excess) = 122 ft 0.8407 ft /ft x 80' (Shoe Joint) = 67.3 ft 122 ft + 67.3 ft = 189.3 ft 189.3 ft 0.93 ft /sk = _ 203.5 sks Round up to 210 sks BHST = 35 °F, Estimated BHCT = 58 °F. (BHST calculated using a gradient of 2.4 °F /100 ft. below the permafrost) < Base of Permafrost at 1,100' MD (1,100' ND) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5 50 10.0 10.0 < Top of Tail at Drop Bottom Plug 3.0 13.0 1,100' MD MudPUSH XL 5 50 10.0 23.0 Lead Slurry 5 366 73.2 96.2 Tail Slurry 5 35 7.0 103.2 Drop Top Plug 3.0 106.2 Displacement 5 163 32.6 138.8 y ,u Slow Rate 3 20 6.7 145.5 < 13 30, 68.0# casing in 16" OH MUD REMOVAL Recommended Mud Properties: XX ppg, P < 15, T < 15. As thin and light as possible to aid in mud removal during cementing. TD at 1,300' MD Spacer Properties: 10.5 ppg MudPUSH* XL, P = 17 -21, T = 20 -25 (1,300' ND) Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. * Mark of Schlumberger OR Puviaq Schlumberger Cem. ° BE Preliminary Job Design 9.625" Intermediate Casino Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nabors 16 Location: Wildcat Client: ConocoPhillips Alaska Volume Calculations and Cement Systems Revision Date: 12/12/2002 Volumes are based on 40% excess. Tail slurry is designed for 700' shoe track. Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265 - 6205 Tail Slurry Minimum thickening time: 160 min. (Pump time plus 90 min.) Mobile: (907) 229 - 6012 15.8 ppg Class G + 0.2 %D46, 0.3 %D65, 0.1 %D800 - 1.17 ft3 /sk (adjust retarder to give email: martin13@s1b.com desired thickening time) I .3132 ft /ft x 700' x 1.40 (40% excess) = 306.9 ft 0.4257 ft /ft x 80' (Shoe Joint) = 34.1 ft 306.9 ft + 34.1 ft = 341.0 ft 341.0 ft 1.17 ft /sk = 291.5 sks Round up to 300 sks Previous Csg. < 13 3/8 ", 68.0# casing BHST = 85 °F, Estimated BHCT = 73 °F. (BHST calculated using a gradient of 2.6 °F /100 ft. below the permafrost) at 1,300' MD PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 3.0 11.0 MudPUSH XL 5 50 10.0 21.0 Tail Slurry 5 63 12.6 33.6 Drop Top Plug 3.0 36.6 Displacement 5 217 43.4 80.0 Slow Rate 3 20 6.7 86.7 < Top of Tail at 2,500' MD MUD REMOVAL Recommended Mud Properties: XXX ppg, Pv < 15, T < 15. As thin and light as possible - to aid in mud removal during cementing. < 9 5/8 ", 40.0# casing Spacer Properties: XXX ppg MudPUSH* XL, Pv = 19 -22, Ty = 22 -29 in 12 1/4" OH Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. t TD at 3,200' MD (3,200' TVD) * Mark of Schlumberger + I a� a NA L ' � � Puviaq CemCMDE Preliminary Job Design' SPbI1Imberger 7" Lone stria 6 Casino o Preliminary Job Design based on limited Input data. For estimate purposes only. Rig: Nabors 16 Location: Wildcat Client: ConocoPhillips Volume Calculations and Cement Systems Revision Date: 12/5/2002 Volumes are based on 60% excess. Tail slurry is designed for 3000' annular length. Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265 - 6205 Tail Slurry Minimum thickening time: 180 min. (Pump time plus 90 min.) Mobile: (907) 229 - 6012 15.8 ppg Class G Additives - 1.16 ft3 /sk email: martin13 @slb.com 0.1268 ft /ft x 3000' x 1.60 (60% excess) = 608.6 ft 0.2148 ft /ft x 80' (Shoe Joint) = 17.2 ft 608.6 ft + 17.2 ft = 625.8 ft 625.8 ft 1.16 ft /sk = 539.5 sks Round up to 540 sks BHST = 203 °F, Estimated BHCT = 154 °F. Previous csg. (BHST calculated using a gradient of 2.4 °F /100 ft. below the permafrost) < 9 5/8 ", 40.0# casing at 3,200' MD PUMP SCHEDULE Pump Rate Stage Stage Time Cum Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 3.0 11.0 MudPUSH XL 5 50 10.0 21.0 Tail Slurry 5 112 22.4 43.4 Drop Top Plug 3.0 46.4 Displacement 5 283 56.6 103.0 Slow Rate 3 20 6.7 109.7 < Top of Tail at 5,000' MD MUD REMOVAL Recommended Mud Properties: XX ppg, P < 15, T < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, P = 19 -22, T = 22 -29 proper cement m li C Recommend 1 per joint across zones of interest for ro < 7 ", 26.0# casing p 1 p in 8 1/2" OH placement. TD at 8,000' MD (8,000' TVD) Mark of Schlumberger 0 R i CI i IVA I. Puviaq #1 • • Ill.'" Proposed Completion Schematic 20"x30" conductor @ Subject to change onocoPhillips C +/- 136 MD 1 ' 1 1 ' • 5 M 3-1/2" tubing hanger 1 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required e 0 e 5 13-3/8" Surface 5 5 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. csg 72 ppf L-80 5 5' @ 1300' MD/TVD ,,,,' , 0 Use of port collar at the discretion of the drilling team. 5 5 0 0 0 0 0 0 ';`' &, ,•i,... .91 5 5 wpt, „,;,, Surface csg. 0 / e 9-5/8" 53.5/47/ 40 ppf string set at 3200' MD/ TVD 1 / / / / / GLM Placement: ? / 5 / To be determined 5 / 5 0 ,e •', ,I.',' 5 ,5 5 5 5 , 5 1 .% 5 5 , 5 5 5 int 44 5 5 At 2.4- 5 , 5 - 5 51 5 5 1.1 Baker PBR. 5 .......,.... 5 , .. EnNIPM le Baker 7" x 3-1/2" Permanent Packer set +/- 100' MD above top planned perf. 1 r; III 5 0 iff"Tt '; GLM Placement: P' 0 . 5 To be determined 3-1/2" Camco 'D' nipple w/ 2.75" No-Go profile. 5 ...,■,, 5 Baker 3-1/2" WL Re-entry Guide w/ shear out sub. Tubing tail 50' above top planned perforation. „,,,i,.= ,,,,,, 5 --....:4 Perforation —.east 5 Interval % unknown --- -•-.~15 - coCC.Kg 4 0 fl , . 0 0 . : . : . : . : . : . : . : . : . • 0 Production csg. es, :q!Mell:: 7” 26# L-80 i! 5 TD @ 8000' MDTTVD BTCM (+/- 8000' MD) TJB 12/16/02 Ohit;iii4 A L c- Q.. _t) '-Li../ , DRILLING TIME AND MUD WEIGHT CURVE —.- - Depth Ikpikpuk #1 —Mud Weight 0 20" set @ 535' 13 , , LL I L L 1 -- - -� I- 1- --- - -+ y 13 - `Drill &Log 17 -1/2" Hole - - - – 12 8 r r r 2000 i i T i 1 7 i i r i r M L___ 1 _ L L 1 1 J J L L 1 ____ 12.6 13 -3/8" set @ 2623' _ _ ' ' ' 1 1 1 1 1 1 1 I 1 I 1 - 12.4 r T 1 r r r r 1 1 r r r I 1 1 1 1 1 1 1 1 1 1 1 - -- 12.2 I '�I I I 1 I I I 1 I I 1 I 4000 � � + + + i - F + r r – 12.0 I 1 I 1 1 1 1 1 1 TT T 1 - -- r r r 1 1 - 1 r r r - -- 11.8 1 I 1 1 1 I 1 1 1 _ -- Cored from 1 L 1 1 1 I 1 1�J__ L L 1 J J J L — 11.6 1 Plugging Back for 6000 2930' to 7501' in 6 runs 1 1 1 1 1 1 DST #1 & #2 — 11.4 1 - - --i r r r - r W L 1 J _ Drill 12 -1/4 Hole L L I J i J L - ---- - --- - - w , " Um - +--- i - - - -�- - 11.0 (9 (42 of 69 sidewall cores) i - 8000 ` 10.8 LI = 1 I– 1 - 10.6 2 a L 1 1 _ 7 L I L o + i .1 - 10.4 r r -- -1 - - -- - r r r ■ - 10.2 10000 ` ' I 1 1 1 1 1 I I I 1 I 1 1 1 L 1 L ___L____ I 1 1 -J- L___ _ '7 10.0 1 1 1 1 Log Hole &set 9 -5/8" @ 9373 Drill 8 1/2" Hole � _ _ , r (13 of 30 sidewall cores) - -- Well Suspended Until - 9.8 I r— 1 I - -- , , , , 1 , , Following Winter 1 -- - - - - - - 9 12000 ' - + - - -- + - 1 Cored from -- -- +----- + ---- -I - - - - -1 - �- -- 1 — 9.4 ID - -r -+ 1 1 0,270' to 12,753' - -- 7 - - 7 - -- Log, Run? "Liner - - 9 --, , 1 , in 6 runs 1 1 to 14,210' - - 1 1 - - -- _ _L J L_ 1 .- 9.0 14000 1 1 V Drill & Log _ _ - - 5 -7/8" Hole - 8.8 r r T • f 1 r r T 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 -- - - 8.6 1 , , 1 1 1 1 1 Cored from - 1- 1 L 1 7' J 1 1 IL L _-- __1 ___- J1 ___ J_- 14,971 ; L - - - - 1 -- - - - -- 8.4 1 I 16000 1 in 4 runs 8.2 0 50 100 150 200 Spud 3/14/99 TIME TO DRILL (DAYS) Rig Release 4/5/99 ORI ORIGINAL prepared byTJB 5/24/99 7V VC- � °- t Depth DRILLING TIME AND MUD WEIGHT CURVE —Mud Weight S. Simpson #1 0 20" set @ 495' I 1 I I I 1 1 1 I I I I 1 1 1 1 1 I I I 1 I 1 I I 1 I 1 1 I 1 I I 1 1 I 10.8 _L L L 1 I I 1 -I J J 4 4 1 1 4. 1 L L 1 L 1 1 1 1 -I J J J _ 4 4 1 1 1 L _ L L L 1_ 1_ _ 1_ 1 I I I I 1 1 I I 1 I 1 1 I 1 1 I 1 1 1 1 1 I 1 I 1 I 1 1 I I 1 I 1 1 1 1 Well P &A I 1 I I I 1 I I 1 I 1 1 1 1 1 1 I 1 1 1 1 - I I I 1 1 1 1 1 1 1 1 1 - i- 1- +--- t- +-+-+- - + - F -F - F - -I 1 - -1 1___ y_ y_ i_ y___+_- }_+_ +_ _ +_*_ +_F_ _1- - 1-_1__1__ _�_ __ Drill &Logged J_1_1___1 _ L_L_L_L _ II _ -1-1-1 JJJ _1 1 1 1 L L L L 1 1 1 1 1 J— 10. I I I 1 I I I I 1 I i I 1 I I I I I I I I I I I I I I I I I I 1000 (LC problems); 1 I I 1 1 1 I I I I I I I 1 I 1 1 I I 1 1 1 1 1 1 1 1 I 1 _ _ _ _ I _ 4 4 4 _ 4 4 4 4 L L L L I 1 1 I I J J 4 - 4 - L 1- 1- 1.- I I I I 1111 I I I I I I 1 I 1111 1111 I I I 1 1 1 1 1 1 1 1 I I I 1111 I I 1 I 1 1 1 1 1 1 1 1 1 1 1— 1 0.4 - - F- F - I - -i - - -- - 1 - - I --I - t + + + I- F F 1- 1 I 1 - H -1 -1 -- - + -+ - +- - -4-- - - - - -- -1 -1 -- 1 IIII 16 se @ 198 1 ' i 1 1 i L i i i i _J i - i i - L ', Plugged Back for - -- , 2000 1 1 1 I 1 _ 1 I I I I L I I I I I I 1111 I DST #2 & #3 1 L L L 1 4 - -- 1 -1 4 -4_ - L 1 1 L_L 1 1 I 1 1 1 1_ 4 4 4 4 _ I J 1 1 1 1 I I I I I I I I 1 1 1 I 1 1 1 I I I I I I I I I I 1 1 1 — 1 0. 2 I 1 1 I 1 I - -,- i I T- T I 1 I I I 1 I I 1 I 1 1 I 1 1 1 I 1 1 1 I 1 1 F4 ------- -1-4-1 - - - -- + - - - +- -+ - +- - - FFI1I11- H- 1 i + - + - + - +- -- 4- --- - F- F---------- 1 1 I J 441 _ _ 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 I L L I 1 1 1 1 1 1 - I 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 I 1 I 1 1 1 1 1 1 1 1 1 I I 1 3000 1 I 1 1 1 1 1 1 I 1 I I 1 1 1 1 I L L I i I 1 I 1 L 1 1 1 — 10.0 _ _ 4 4 4 _ 4 4 4 4 L L 1_ I_ I_ I_ L 4 4 4 _ 1 1 1 1. 1 L L L 1 - - L - J 4 I _ I L 1 I I I 1 I 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 I 1 1 1 I I 1 1 1 1 I 1 - � - I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 I 1 1 1 1 1 1 1 1 1 1 I 1 I I I 1 - - - -F i - - - - 1-- I-- -1 --I - 1 - - +- + - + - +- - 1-- F -F -F- - 1-- I-- 1-- 1--- -I- 1- 1- 1 - 1 + - + - + - +- + - +-F 1_ 41.1_114 - - F- F -1 - -- --1----1-1- - __ _ _ 1 1 1_1 1 L L L L L 1 1 I 1 1 1 J 1 1 1 1 1 L L L L L L 1 1 1 J I 1 I I I 1111 I I I I I I I I I I I I I 11 1 I 1 1 1 1 1 1 1 1 1 1 9.8 4000 1 ^` I I I I II _ _ _L - - 4_ J 4 4 4 1 1 1 L L L L I- I I I_ _ 1 4 4 _ 1 1 1 1 1 L 1 L L L I_ _ I_ J J 1 1 I 1 1 1 1 1 1 ' ' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I— W I- -� -- 1 1 1 1 - I - I Drill 13 -1/2" Hole 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 m W - - + -- 1---- 1- -1 1 1 + + - + - + - i- - +- +- r - - F -F -1 -- --- 1--- -1 -1 -� 9.6 LD u_ __ ___ I_ 1 J J ._ 1_ _ 1_ _ 1 (tight -hole & LC problems) I J J J 1 1 1 J. L L L L 1 1 1 1 J I I 1 I 1 1 I 1 1 1 1 1 1 1 I 1 1 1 W 1 5000 1 1 1 I I I 11 1 1 1 1 11 1 1 1 1 1 1 1 1 Plugged Back for DST #1 1 1 1- 1 1 4 4 4 4 1 4 1_ L L L I 1 1 1 I J J 4 4 4 4 1 . . 1- a I 1 1 I I I I 1 I I I 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 — 9.4 0 I 1 1 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 W I- 1- 1- 1- -- -1- + -+ -t- - +- +- +- I-- - -F -1- --- -I -1 __ __ __ 1 I _ I _ J _ _ 1 _ _ _ 1_1_ L L I I I 1 1 1 1 1 1 1 1 1 J CI 6000 - I I 1 I I I I -- I I I I I I I 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 11 I 1 1 1 1 1 1 1 1 I 1 1 1 11 - 9.2 -- - 1- - - -I -1 4 4 4 44 4 4 I_ L L L _ 1_ 1_ I_ 1_ J J J 4 4 4 4 4 4 L L L L 1 -I -1 1 I I ii I I I 1 I 1 1 I I 1 I 1 I 1 I 1 1 I I I 1 I I 1 1 1 ii - - -- I - I 1 ii 1 I I 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 II I- I 1 1 ii + - +- +- +- +- - -+ - F- - F - - - i -- 1.10 -3/4 "set @7206' _ + - i + - i - - +- - + -F -- F -F - -- - - -1 - -- -1 1 7000 1 1 I I 1 1 L ogged &Sidewall Cores ; — 9.0 I 1111 1111 11 -- _L 1 1 4_ 4_ . _ (25 of 27 r ecovered) L -L - -- 1 4 4_ 1 1 1 1 1 1 L_ L L I- - I- __4,-J I 1 I 1 1 1 i I 1 1 1 1 1 I 1 1 I I I 1 1 1 I 1 1 1 1 1 i 1 I I 1 1 ■ I I 1 1 I I 1 1 1 1 1 1 - -- - ---- 1-- --I --I- 1 --4 - + - - + -- - 1 -- F F F- I-- 1 I I -- --- 1 --- i- + - + - +- - + -+ +-1- ---I- -F -I -- --- 1--- - --i -- 1 1 1 1 J _1_._1_ ___ L L L 1 1 1 1 I J J _ 1_1_1_1_ _L_L L_L L 1 1 1 1 J II I I I 1 I I I I I I I 1 1 I I 1 I I I I 1 I I I 1 I 8000 I 1 1 1 1 1 I 1 1 1 1 1 1 1 I I 1 I I I 1 , I I - - -L I 1 -1 4 4 . 4 _ 4. 1 1 1 _ L L L L _ I_ I_ 1_ 1 - - 1 4 4 J 4 4 1 4 1 1- L L L I I 4 1 1 I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I - 1 - � _ _ 1 11 I I 1 1 1 1 1 I 1 Drill 8 -1/2" Hole _ 1 1 1 1 1 I 1 1 1 I 1 — 8.6 ---,- -- ----- - I -- 1 --4- -+--- +- +- +- +--- F- F- F- F--- I - - I -- - + - +- - -+ - F- F--- F -F -I -- ------ -1 -1 -- 1 1 11 J_J_ _ 1 _ _ _ 1 1 1 1 L L L L I 1 1 1 1 1 J J 1 1 1 1 _L L 1 1 1 1 1 I J 1 I I 1 I 1 I 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 9000 1 1 1 I , 1 1 1 1 I 1 I 1 1 1 1 I 1 I I 1 I 1 1 1 Logged & Sidewall Cores 1 1 I I 1 1 _L 1 4 4 1 _ 1 4 4 4- _ L L L L _ 1_ 1_ 1_ 1_ -1 J J J 4_ L_4_ 1 - - 1 1 1 4_ 8.4 1 I I 1 1 I 1 I I - 1 1 I 1 1 1 1 1 1 1 1 (1 3 of 19 recovered) 1 1 1 1 1 1 1 I 1 I I 1 I I 1 I 1 I 1 1 1 1 I 1 I 1 1 1 1 I I 1 I 1 1 1 1 1 - - - F - - - 1 1 - 1 1 1 . - +- + -+ -1 1-- F- F- F--- I-- 1-- 1-- 1---- 1- 1 1 1 --- + - + - + - + r- F--- r -F- - r - ----- 1 --I --I - 1 1 1 I J _ 1 _ _ 1 _ _ _ 1 1 1 1 L L L L 1 11 1 1 1 4 1 _ 1 1 1 1 1 L L L L L I I 1 I J 10000 1 I 1 I 1 I I 1 1 1 I 1 I 1 I 1 11111,111 I 8.2 0 5 10 15 20 25 30 35 40 45 50 55 Spud 3/14/99 TIME TO DRILL (DAYS) Rig Release 4/5/99 ORIGI I 1 �, L prepared by TJB �1 5/24/99 Puviaq #1 Exploration Expected Drill and Complete Time 1000 Estimated Time to Drill & Complete 73.3 days 2000 • 3000 E 4000 o a CI 5000 6000 • 7000 8000 9000 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 Time (Days) OR1GINIL Conoco Phillips 700 G Street [99501] Post Office Box 100360 Anchorage, Alaska 99510 -0360 Monte D. Mabry Staff Geophysicist New Field Core Areas Telephone: (907) 265 -1653 Facsimile: (907) 265 -1608 Email: mmabry@ppco.com To: Tom Brassfield ATO -1550 From: M. D. Mabry, T. K. Kan Subject: Pre -Drill Seismic Pore Pressure Prediction for NPRA Proposed Puviaq 1 Well Restricted CONFIDENTIAL Date: November 2002 Summary Extracted velocities from 3D seismic data were used to predict pore pressure trends for the Puviaq 1 well. A local compaction trend and a pressure calibration model was established using control from the South Simpson 1 well and checked against the Ikpikpuk 1 well to the south. The compaction trend and calibration model established was applied to velocities from the Puviaq 3D seismic survey to predict pore pressures. These predictions show no apparent shallow hazards or large pressure anomalies at the proposed well location. All apparent pressure buildups in the area surrounding Puviaq 1 were investigated carefully to determine if they were the result of a local lithology change, a missed velocity pick or poor quality shallow seismic data. Pressure Calibration from Well Logs: ConocoPhillips PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the Normal Compaction Trend Line and predict pore pressures. (See Fig 1.) A pressure calibration model was established by comparing transit time differences (MT) in S. Simpson 1 and Ikpikpuk 1 to their respective mud weights. This model calculates pressure gradients (PP) using the equation: PP = C2 *MT * *2 + C1 *MT + CO Where C2 = 0.00154, C1 = .0365, CO = 8.94 Sonic transit time deviations from the compaction trend in S. Simpson 1 are graphed against the sonic derived pressure in the right half of Figure 1. The higher - pressure predictions of 11 Ibs /gal at 6200 ft. subsea are due to the pebble shale (HRZ), an organic -rich condensed section prevalent in this area. This is a well- documented lithology effect. Because of Puviaq's close proximity to the S. Simpson 1 well and the fact that S. Simpson 1 is located on the same 3D seismic dataset as the proposed Puviaq 1 well, the S. Simpson compaction curve was used to calibrate pressures for Puviaq. Seismic Processing: Geopressure analysis from seismic data is entirely dependent on the accuracy of the input velocity field. The velocities used in this analysis were generated using ConocoPhillips' AVEL program, an automated high - resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very detailed velocity field defined at every sample in time. The output RMS velocities are smoothed over 9 CDPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in CDP fold. • Seismic Pore Pressure Prediction: Pressure gradients were predicted at the Puviaq 1 well location from 3D seismic velocities. (Fig. 2) This report includes displays of pressure gradient predictions on a 3D inline, a 3D crossline and a composite line tying the Puviaq location with the South Simpson 1 well. (Figures 3 -6) All are plotted in depth. In addition, horizontal depth slices of the calculated pressure gradient are shown in Figures 7 and 8. These slices were taken at 800 feet and 1500 feet and show the respective aerial distribution of predicted pressure. Warmer colors indicate higher predicted mud weights (pore pressure gradients). Conclusions: 1. Moderate pressure buildup is expected below the proposed TD of the Puviaq 1 well starting at a depth of around 8000 ft subsea. These buildups are not expected to exceed 11 lbs/gal. 2. Normal hydrostatic pressure (9 lbs/gal) is expected along the entire length of the Puviaq 1 well. 3. A subtle apparent pressure buildup is seen in the vicinity of the S. Simpson 1 well (Fig. 7) but looking further at the seismic data, this is likely the result of a questionable initial velocity pick. No evidence of shallow pressure was noted while drilling the well. 4. Permafrost appears as a dark blue band between from surface to 1200 ft depth. This zone causes calculated apparent mud weights of 10 -10.5 lbs/gal. 5. Methane hydrates may be encountered in or around the base of permafrost. These hydrates do not exhibit acoustic properties sufficiently different from the permafrost zone to be detected seismically. Nevertheless, they can pose a drilling risk if proper safeguards are not in place. Feel free to call me if you have any further questions regarding pore pressure or hazard assessments for the Puviaq 1 well. Monte D. Mabry ConocoPhillips Alaska, Inc. n PI Pore Pressure and Fracture Gradient PUVIAQ 1 ANALYSIS M. Mabry and T.K. Kan, November 2002 ono � � � l � ps DEPTH (Datum sett MSL) South Sim •son 1 FEET MSL . • • .. _ _ SL • 1.- __._ +_ {___S- ___•_fit...__.: —i .d. 8.- I r. -.. d_�_a. /T T4 .._ ._•- •___•. __' 1 1000 � . . . .�. - __ - ____ -_ - r.--- ___. 01 1000 — _.__ +- -- --- -_- - - -_ —_ - __.. =: . tW_� _ = _... woo ..._, qx � � .� -. ..- ...3..._ .t. - . , . Y j 4 . ... ......... _.._... -.... ..._.. .. - • _....__ _---- .:. S._ _,- ..._.- 3 .- _. j 2000 - = �t r ; . , +. =. ^ _.._._ _._ _ _....__ -4- - - _ -... :t - 2000 ' 1 t. -- -- y _ _'1_ t - r N -o-+3- _. .._ _. "'__. -__ ._ - 4._____'. - �_." L _ i ._. -..y. . _ . :.__.__ _ f - � a ' - '- ._...___ ... • -h-� -eight - - --- � - -~ - --! .. �1 ..•. 1. 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'+ "M _. _I . _ __. _ _. i -, .. -... __.. ..._..__3.._._ _.. __ 7 } tyre ti trr _ ; �. i 151 7000 - -- -- _, -- -- - -- - _.. _.. pore: __. 7 1 ` 7000 --- . -- 1 — — — _ _ : ... -_.. �..... .._ ._... ... 1 .. _....... - - 3 6000 - - -- - -- - -- -- - ( - �_ - } :._. i ._.._ 8000 —L _ fi ._.__ _. ._.___..� _._.. _. ._ ..__. ._._ ._ 9000 - -- - -- -- - -- - - 1 , __: = ::r:_.. -.._. ..."....:... ti Figure 1 '- s000 __.. } 40 200 9 11 13 15 17 19 LBS /G ORIGINAL Pore Pressure and Fracture Gradient PUVIAQ 1 ANALYSIS M. Mabry and T. K. Kan, November 2002 11 . Conoco Phillips DEPTH (Dalin 564to RiT MSI4 Puviaq No. 1 predrill prediction FEET MSL MSL PERMAFROST } - . ... i __ ;...„ „___ , : .,...:. ,... • . i..... _ .4.4 .. _,_4.I..4.i..4. ,(4 -,. : -- - , , r 4 ' 1- ' ' 4.--- 1- 1 i • • - i -- i-t-t - ii ' -- .1.--- — 1 4-- --- . --- - -- : _,.. - +-- - )--- - 4 - , ; , - , • • ' . 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' / / ' ' sommaimau ' / ' ' ' . . . , / ' / / / ' ' ' ` / / / / ' / . , . . l00000- ------ ` ` � / / / ' ` / / ' / ' ' / 4 4 � ` ' ^ ' / / SS I �� . _~- 00000 - - - - - - - � . 4 Location Map . . : showing extracted . . , composite seismic profile ' 60000 --- ---- ' ------ -------- , ' ` ' ' ' / / ' . / . ` _---_--~� ' . ' PEN zaQ_1 ' '------------ - ' / / / 40000 r - -- -�--------�--'----- / ' / ' / ` ' / () / ` / / / ` ' ' prWzm� 2 / / . . .__ ^ . / . ' ��� 20000 - --- ----�---- ----� ' ' - - - ' ���� . . � / -~ ' ' ` j I 0 ' � . . / ' / ' ' ' ^ / ' / / ' ' / ` / / ' / . . . . . ' ' Figure ' ` �� UnS3 ` / ' ' / " -20000 ~, o 1 o " " -40000 -20000 0 20000 40000 60000 60000 ORIGINAL Pore Pressure and Fracture Gradient PUVIAQ 1 ANALYSIS /I�� '` { {{ M. Mabry and T. K. Kan, November 2002 / ono �s.A Ph . l l i ps Si r' Composite seismic profile: S. 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I) J , 1 , 4 ; } 1= s �P 1 . , 1 �� d { ' r 17.50 t n r 8 �' .n 18.00 14000 :,. y{ • 1 i I M -F . - ,�` •;.. 11 : : v ({ 19.00 il 1 , ; 0 - 112 , , Il � , t . fO, . Figure4 ORIGINAL • Pore Pressure and Fracture Gradient IV s PUVIAQ 1 ANALYSIS M. Mabry and T. K. Kan, November 2002 ��; Puviaq Pore Pressure Analysis 3D ne PuviacL1 5 5 5 S S S S S S S S S S 5 5 5 5 5 5 5 S 5 5 5 5 5 5 5 5 5 5 555 Xli 5 5 5 5 30352 5 5 S S 5 5 S 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 A' A 5 5 5 5 5 5 5 5 5 5 6 6 6 6 6 b 6 6 6 6 7 7 7 7 7 7 9 7 4 7 8 0 8 B 6 B B B 0 0 9 9 9 9 9 9 9 9 9 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 0 1 2 3 4 5 6 7 6 9 0 1 2 3 4 5 6 7 6 9 0 1 2 3 4 5 4 7 6 9 0 1 2 3 4 5 6 .613 8 9 0 1 2 3 5 6 7 8 9 0 12 3 4 5 6 7 8 9 0 1 2 3 4 5 6 7 8 9 in line 0 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 4 4 4 4 4 4 6 6 6 6 6 8 8 0 0 8 0 0 0 0 0 0 0 2 2 2 2 2 2 2 4 4 4 4 4 4 6 6 6 6 6 6 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 2 3 1335 33 5 23 5 835 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 X line 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 2 5 5 5 5 5 5 5 5 5 5 5 5 5 5 ppg 0 t s; ,! ° nt }r n �,. 0.00 { ! , } i�:`,4 4 t fit, !tt 4 tPi t 3 !!S j ''':'!!''','•','.1 1. 1 �� T . � ,� �s �1 s �� 3 � � �t} # ass {f , � t � �, il S ( I 1a f 1 �S rlt }t „t Q r.��; ti i : r rr�i ' .,.. s B. 50 �4i�� littrill t i w .. 4910.4 �� { j "t { � � ct � ` di t }�. 1 {tffi 1 d s���� i }7 s 1 l ilt :;� 1 ''F; 2000 ) i'ii it ¢ . ,;; '. t'l ii' 1 ':'''1 t",' 1 d {5i i 'lit'll0": 9.00 9.50 , 10.00 10.50 4000 11.00 11.50 III • 12.00 6000 _ 12.50 i ^' 1 " tr' { s ..3 \i 1 ' , '..--.4. ! , { �• ��� } �f� Y»:+k`"_�� v 3.00 f i ". , r i -.,. 1; w 4.1 fl t(5' �'t - A% f ; -,N � ”' . .., �4.-.,+. 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Y � � Y t t I l , flf t 7 �s , li g 14975 --' O RIGINAL I L _ 3 c .rTY. l I arn+- - -_- Pore Pressure and Fracture Gradient PUVIAQ ANALYSIS noco ulkk M. Mabry and T. K. 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M. 120000 - �iivlaq era a. o0 • 110000 - / e .. _ _ f . ! .... 8.50 - . 9.00 ,, 100000 , , • - �, h 10.50 \ \ " ;1 '..--1,... Y 11.00 60000 - .: t - _ ., _.. ..___.. 11.50 ....:::-.4.,1/41:. 1 • 70000 , s 12.00 t M ti �R ,. z, '�`r . 12.50 60000 - e„ 7.771,:w ' _ .... _ .. _ v 13.:505°000:0 \ t . ` • i., d -, 5 1� �'. .g } . 13 . 50000 --- -- y . , ;} - - i4 � va` V..,,:,.::‘,.`4,.' .. -r;ti _ __. 14 f 1 / ' ` k t - '' .. =s\' '' e .' . ' 14 < �a �3 40000 - i r :� - ^ 4 d z - - - - n - Is . ' e • 15. O r ■ 30000 - - . .. .. .. .. .. . ... - _`' � � $, h __ � h "_. x5 4, �, �' � � - 16.00 ' k 16.50 • 20000 { 5' ' ° ■ 504 17.00 17.50 10000 .. .. 1 . 10.00 Puviaq Pore Pressure Analysis PPG Depth Slice at 800 ft 10.50 19.00 -10000 -� , I .1 • -40000 -30000 -20000 -10000 0 10000 20000 30000 40000 500 60000 70000 Figure 7 ORIGIiVA L Pore Pressure and Fracture Gradient PUVIAQ 1 ANALYSIS 1 M. Mabry and T. K. Kan, November 2002 Co co illips 120000 - now ,,,,�;a�, ',Fa Alaska, Inc. WillaiilliillNti 1 0.00 110000 - .. - ... _ ._. .. _ - B 50 9.00 100000 . . ......... ... . .�. ` . ..... 9.50 '. 10.00 ■ 90000 - .. - - - _ .. .. • 11.00 ., 80000 '` +_ 11.50 12.00 10000 - \ y' __1 -_ . ,-__ .. _.. -.. :- •••-:` + 12.50 \ 13 00 60000 - _ ..___ -. ..___ .___+ , ... . 4 ,F }xvTrYc� ; _ 13.50 r r it ',....k.: 4 , s + + 50000 - _ Y .LF a� '' Z ' .. _ . .. 14.00 t ,. • ''''';'-7 z 14.50 r k 40000 _. -, -.. . r ___.. _ ___. -f _ +' 15.00 341 r�.; f y ' # i 15.50 30000 _. _ .___-+ .h "` F _: •'+. -._ L. .. F _ .___ + .._.. _ 16. 00 - 16.50 r 20000 - . .. .. .... ... .. ... 1 ' r - .... __.._ 17.00 t� : , 17.50 10000 - + , x. . .. 19.00 0 Puviaq Pore Pressure Analysis PPG Depth Slice at 1500 ft 18 50 19.00 . . . , -10000 -, -40000 -30000 -20000 -10000 0 10000 20000 30000 40000 50000 60000 100 Figure 8 ORIGINAL • ConocoPhillips Box 100360 Alaska 99510 -0360 RECEIVED December 16, 2002 DEC 1 7 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7 Avenue, Suite 100 Anchorage Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Puviaq #1 (Exploratory Test) Surface Location: 1703' FNL, 451' FWL, Sec 35, T16N -R1OW X= 450554, Y= 6105710 ASP5 NAD27 Target Location: 1703' FNL, 451' FWL, Sec 35, T16N -R1OW Bottom Hole Location: 1703' FNL, 451' FWL, Sec 35, T16N -R1OW Dear Commissioner Taylor: ConocoPhillips Alaska, Inc. (CPAI) hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve — Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8 -1/2" wellbore through the objective with a full LWD logging suite for evaluation. Depending on results the well could be P&A'd or cased and completed thru the zone of interest. Cores could be cut thru the Torok Fan and /or the Simpson Sands. The proposed casing program will utilize a 13 -3/8" surface casing string, a 9 -5/8" intermediate casing, a 7" production string and 3 -1/2" tubing. Due to the remoteness of the Puviaq location (approx. 145 Rolligon miles from Kuparuk), the primary reason for setting two strings of casing at the indicated depths is to establish an annulus for waste fluids injection early in the program. See additional comments under "Annulus Pumping Operations ". CPAI would request authorization for the disposal of drilling waste via the annulus by filing with the AOGCC a 10 -403 supplemented with additional information as required under 20 AAC 25.080. Please find attached information as required by 20 AAC 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 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 1 A"�RA ORiohiAL 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Nabors 16E) as required by 20 AAC 25.035 (a) (1) and (b) are on file at the AOGCC office. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). 8) PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Complete mudlogging operations such as type log generation and sample catching are planned. The following are CPAI's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon Allsup- Drake, Drilling Technologist (20 AAC 25.070) 263 -4612 2) Geologic Data and Logs Greg Wilson, Geologist (20 AAC 25.071) 263 -4748 The anticipated spud date for this well is February 1, 2003. If you have any questions or require further information, please contact Tom Brassfield at (907) 265 -6377 or Paul Mazzolini at (907) 263 -4603 Sincerely, NJ"— n Tom Brassfield Staff Drilling Engineer cc: CONFIDENTIAL — Puviaq #1 Well File Paul Mazzolini ATO -1570 RECEIVED DEC 17 2002 01? / G " Alaska Oil & Gas Cons. Cotrtmissipn Anchorage ConocoPhMips Alaska, Inc. P. O. BOX 100360, ATO -1454 ANCHORAGE, ALASKA, 99510-0360 Telephone 907- 265 -1505 Facsimile 907- 263 -4966 JAN 0 6 ZOOi To: Robert Crandall &Gas C ons. Gomm`tsstot Steve Davies �nC� Subject: Shallow Salinities, Puviaq Prospect Area From: Wayne Campaign Petrophysicist Date: October 24, 2002 This document will discuss shallow salinity calculations and issues from the NW NPRA area around the upcoming Puviaq well. Figures and attachments include a locator map and salinity presentations of offset wells. I will also reference a USGS paper by Lachenbruch ( et.al), "Temperature and Depth of Permafrost on the Arctic Slope of Alaska ", 1988 (Reference 1). The proposed well is located in section 35 of township 16 -N, range 10 -W. Nearest offsets for this report are Drew Point #1, Ikpikpuk #1 and South Simpson #1. These wells were drilled by Husky Oil during the 1977 -82 phase of NPRA exploration and have sonic and resistivity logs in the shallow sections for quantitative calculations. A locator map is included as figure 1. Analyzed plots are included as attachments 2 -4. Plots include raw logs plus Volume shale, effective porosity and TDS curves. The TDS curve in track 1 is highlighted in blue (magenta and green for x5 backup scales) in sands, defined as Vshale < 30 %. Illustrated on the plots are geologic tops for the Nanushuk and Torok horizons, and the 0 ° C depth and temperature gradients in the permafrost, from Reference 1, when available. Salinity may be calculated 2 ways; Rwa ( "Apparent Rw "), using porosity and deep resistivity, or the SP method. Both systems work best in sands. When there are good sands in the section, I have used the SP method as a check. One must first derive a pseudo- static SP value. This is the theoretical SP response in sand with zero clay. The best way to look for this value is to calculate a shale volume from SP that best fits the accepted Vshale log in the interpretation. Then the difference between SP clean and SPshale represents this theoretical value. Just assign the formation temperature for the cleanest sand in the horizon and proceed. These spot -check values are also noted on the attachments. Both methods have been previously discussed in prior memos. The Torok interval shows very little sand, and what is present (S. Simpson) already calculates 14 -20 Kppm NaCI equivalent. One Torok sand in this well also has a gas show. The Nanushuk interval is present in all of the wells. It consists of several sequences of topset marine sands. Lachenbruch, et.al. Ref 1 . put the freezing point around 1100' +/- in the wells. All salinity calculations below this depth exceed 14 kppm NaCI equivalent and are not considered fresh water aquifers. Only Ikpikpuk has 3 sands from 820' -940' that indicate any low apparent salinity. These are likely frozen and not considered 1 Wane Campaign • Y Page 2 aquifers. Several of the Nanushuk sands actually show low resistivities and elevated salinities. These may be a product of the permafrost development. In conclusion, we see no fresh water aquifers in the area of the proposed well, and do not expect them to be present in our location. If you have questions or comments, feel free to call on me. Thank you. J a r ) au Wayne Campaign Petrophysicist ConocoPhillips, Alaska Ref. 1.) Lachenbruch, A.H., Sass, J.H., Lawyer, L.A., Brewer, M.C., Marshall, B.V., Munroe, R.J., Kennelly Jr, J.P., Galanis Jr, S.P., Moses Jr, T.H., "Temperature and Depth of Permafrost on the Arctic Slope of Alaska ", USGS Professional Paper 1399, Geology and Exploration of the National Petroleum Reserve in Alaska, 1974 to 1982, US. Government Printing Office, Washington DC, 1988, pgs. 645 -656. 2 0 IV Wayne Campaign Page 3 �� — ----- Drew # t #1 r o I , ,,,, .,,, ,,, , ... _ ."" ; , ,,,, , -4f, i .. - A, )" ;r. " r 1 ,\ ) i ,-. e 0 I ‘ 5,4 • `""` : 0 ). "Pgviaq # r r l ''/ „,--_, r ... ( . V - f -/ 1 43\1 1 Is 4 s � i j 3 r i ' y 3 ti � ra ♦ r } ,,,...e_, 1 ' - 0 ' 1 :,- l i i pkp t son, over m a for proposed Puviaq location. Nearest well is S. Simp Figure 1. Locator p 15 miles away. 3 SENT BY: DIV OF GOV COORDINATI ; 272 3829; NOV- F a2 12:29PM; PAGE 1/21 IF FAX TRANSMITTAL STATE OF ALASKA v tit T 4, DIVISION OF GOVERNMENTAL OFFICE OF THE GOVERNOR Ce= A1 "V S`� COORDINATION JOINT PIPELINE OFFICE TONY KNOWLES �� - r , " 11 411 W. 4 AVE, SUITE 2C GOVERNOR ; _ _ =; ANCHORAGE, AK 99501 -- -_ FRAN UI.MER 1 � -tom- -. _ j " Telephone! (907) 257 -1353 LIEUTENANT GOVERNOR ^`- 1t. P 0 9 ?' Fax: (907) 272 -3829 Date: November 6, 2002 RECEIVED Pages: 20 + cover From: Serena Sterrett NOV 0 6 2002 Phone: 907 -257 -1353 E -mail: ssterret@jpo.doi.gov jpo.doi.gov �>Oil &A chorags amllliss an Regarding: Nuviaq #1 & #2 Exploratory Wells (AK 0210-01.0G) To: . Harry .Bader Fax No.: (907) 522 -9583 Leon Lynch, Gary Schultz, Larry Byrne 451 -275• Jim Baumgartner 465 -5129 • Larry Bright 456 -0208. Peter 1)itton 267-1267 M.ike Holley, Joy Earl, Jim Wolfe 753 -5567 Jeff Mach, Ron Doyel 465 -5070 Lydia Miner 269-7687 Don Meares 474 -2386 Rosa Meehan 786 -3816 Al Ott, Jack Winters 456 -3091 Matt Rader 269 -8938 Steve Schmitz 269 -8943 Leslie Simmons 269 -7655 Kellie Westphal, Patricia Bettis 269 -8947 Tom Maunder, Steve Davies 276 -7542 Sharmon Stambaugh, Man Kukla 269-7508 Steve Schmitz, Bruce Webb 562-3852 Ted Rockwell 271 -3424 Mike Stahl, Mark Major 265 -1608 Comments; Comments from Arctic Connection and Trustee's for Alaska If yu revel.. td this FAX In error, pleuse' • lintel.$ notify the sender by tulephunc, and return this rAX iu the sender at the above addros %. Thank ynu_ 1 . SENT BY: DIV OF GOV COORDINATIO,, ; 272 3829; NOV- 6 12:30PM; PAGE 2/21 ARCTIC CQNNECrioNs 819 W W' Ave. Suite 212 Anchorage, AK 619510 (907)272.7000 lax 272 -9058 pammider &atka.com • FAX COVER SHEET TO: 1_ C iff) FR: Pamela A. Miller r , D RE' u..Arl' G�-� � Vre-C . , - C"" . 1 f" DA: 11 `( /0 • �'I SENT BY: DIV OF GOV COORDINATti ; 272 3929; NOVo2 12:30PM; PAGE 3/21 ARCTIC CONNECTIONS ALASKA, WILDERNESS LEAGUE November 4, 2002 Ms. Kaye Laughlin Project Review Coordinator Ms. Leslie Simmons State of Alaska, Office of the Governor Solid Waste Division Office of Management and Budget Alaska Department of Envit+anmental Division of Governmental Coordination Conservation Pipeline Coordinator's Office 553 Cordova Street 411 West 4th Avenue Suite 2C Anchorage, AK 99501 Anchorage, Alaska 99501 -2343 By fax to (907) 272 -3829 Ms, Lydia Miner Spill Prevention and Response Division Ms. Kellie Westphal Alaskan Department of Envionmental Alaska Department of Natural Resources Consnrvatian Division of Muting, Lined, and Water 555 Cordova Street Water Resources Sactian Anchorage, AK 99501 550 W. 7 Ave., Suite 900A Anchorage, AK 99501 Mr. Harry Bader Alaska Department of Natoli Resources Division of Mining, Land, and Water 3100 Airport Way Fairbanks, AK 99709 Re: CanocoPhill ps (aka Phillips Alaska. Inc.'s) NPR A Exploration Program (Puviaq #1 and #2 Exploration Wells), State ID No, AK 0210.010G Temporary Water Use Permits - Puviaq #1 and #2 drill sites, Drill Rig Overruing project, (TWUP A2002 - TWUP A2002-16; TWUP A2002 -50; TWUP A200243) Authorisation for Temporary Storage of Drilling Waste Amendment to North Slope Exploration Gil Discharge Prevention and Contingency Plan Land Use Pemut Application for wells, roliigon trails and i� roads Dear Ms. Laughlin: These comments are provided en behalf of our organizations and members on the Alaska Coastal Management Program (ACMP) consistency review for ConoeoPhillips' c NPIt -A Exploration Program (Puviaq #1 sad #2 Expioratim wells). Please also take these comments into account an each individual permit for this project. ConamPhillips is the company name on the most recent applications to the State of Alaska (October 11, 2002 applications ifbr two TWM); PhiLlird Alaska Inc. is the name on the Plan of Operations, Coastal Project Questionnaire, eto. SENT BY: DIV OF GOV COORDINATI. ; 272 3829; NOV-6 12:30PM; PAGE 4/21 • Ar& Cuumcdau &41a teillitako Wtkkrme f League 2 Commix on Partaq Exploration Well Program November 4. 2002 The proposed Puviaq protect entails drilling a total of eight reservoir penetrations at two dust sites in the Tethekpuk Lake Special Area of the Nat teal Petroleum Reserve- Alaska (NPR A). • There would be a new 68 mils long ice road network from Barrow, and five new raison trails including two traversing the Teshekpuk Lake goose molting areas. These are in addition to the roughly 116 miles of previously permitted ice -road network from Kuparuk and Alpine into the NPR -A, end dozes ofodmr exploratory well sites. Water withdrawals from at leant 24 new lakes — including Teshekpuk Lake — and over a hundred previously permitted lakes are prcposed for the massive ice road network. Because the draft consistency determination is not available for review, nor has the environmental impact analysis required by the Bureau of Land Management for the project been completed, it is extremely difficult to provide thotuugh comment on the as= of the NPR -A Exploration wells at Puviaq in the coastal none_ The applicant, CnnocoPhillips, provided exmenely little site - specific eaviraudenal information with their application. Our review of the records indicate that ConocoPhil ips submitted permit applications as reeentJy as October 10, 2002, yet tie 30-day public comment period for the ACMP review was not extended to take this into account. We believe that the proposed Puviaq eacplosatian program is not consistent with the Alaska Coastal Management Program, nor with the North Slope Borough's standards. The proposed project does not avoid or minimize the potential impacts to wetlands and vwiiidlife habitats or to minimize use of lands and waters, and therefore fails to meet the requirements of these standards 6 AAC 80.120 ( Subsistence), 6 AAC § 80.130 (Habitats), and 6 AAC 4 80.140 (Air, Land, and Water Quality). Please incorporate by reference the cants submitted to you by Trustees fir Alaska and others on November 4, 2002. We are particularly concerned about the proposed Puviaq wells because they will be drilled in the Teshekpuk Lake Special Area. This proposed program is a major expansion of oil exploration ac tivitiea is particularly sensitive habitats that support melting and nesting geese used by subsistence hunters ea the North Slope, Yukon Kuakokwirn Delta, and other locations along their flyway. The Pacific blade bran and other migratory birds also provide recreational *Vona to Alaskans and Americans throughout the year. There is important calving habitat for the Tesbekpuk lake herd in the Special Area. The Teshel:puk Lake watershed, including the Miguakiak River, provides important fish and wildlife habitat and is of significant concern to local cemnumiiies for subsistence use and traditional and cultural land uses. According to the law governing the NPR A, particular attendee is to be paid to protecting the surface resources m the Special Areas (PL94 - 258)_ 'The Interior Department designated the Teshekpuk Lake Special Area in 1977 (42 FR 28720 - 28722) and called for maximum proteeden of its resources. We are cemented that the proposed oil and gas exploration wells and related activities in this area do not meet the federal or state management standards. These two exploratory wells sites where a total of up to eight reservoir penetrations would be drilled are located west of Teahelgsuk take. The drilling activities, including chronic spills and potartial blowouts, air pollution, vehicle traffic, water withdrawals and ice road construdian could degrade the habitat values in this watershed, as well as alter its hydrological functions.. Two other remote camp pads are proposed to be located within the Special Area (at Camp Lonely in the Teshekpuk Lake Goose Molting area and at north side of Kogru River within the SENT BY: DIV OF GOV COORDINATE ; 272 3829; NOV- 2 12:30PM; PAGE 5/21 Arcdc ammo Won do Mask Midmost Lkigua 3 Comma am Pnviag Exploration Well Program Yamaha,. I, .1001 Teshekpuk Lake Surface Protectim Area). Four different mlligcn andfor ice road networks could cross the Teshekpuk Lake Special Area_ No explanation is given as to why these are the remote camp pads or all the rolligon or ice raid networks are needed. Three of these would traverse the Teshalcpuk Lake Surface Protegee Atea, even though this use could be completely avoided. There may be increased risk of disturbing polar bear dens, or harassment of polar bears at the getup/ staging areas and ice roads located along the coast. This proposed project would have a number of negative impacts to the Teshekpuk Lake Special Area, including interfering with the hydrological flows in the watershed, degrading wetland vegetation and agattc habitats used by ova fish, goose molting habitat, migratory bird nesting areas, threatened spectacled eiders nesting ha and caribou calving and winter use areas, in violation of the Habitats Standard. We are concerned that the later ice melt pattern of the roads in spring harm sensitive vegetation used by molting geese? Chronic, small spills and the risk of larger foal, drilling waste, or other spills could degrade the segsiuve goose molting habitat. Ice roads, rolligon trails, and remote camp pads should be completely avoided in the Teshekpuk Lake Special Area. We are =corned that having staging and camp areas at these locations and the proliferation of ice roads and rolligon routes will set in motion the pr ecedance for their repeated use due by aoutractars. The potential impacts of these routes and camps, which could be used repeatedly during the 5-year permitted period requested by the applicant, have not been addressed by the State nor BIM. We do not believe diet use of the camp and supply bases in the Special Ares, particularly in the Teshekpuk Lake goose molting and caribou calving habitats, and crossing these critical areas is needed, and therefbre the project proposal does not comply with the ACMP Habitat Standard, nor the Coastal Development Standard (6 AAC 80.040(a)(3)). BLM'S FEIS failed to address potential impacts from vehicle disturbance, aircraft use, spills and alter impacts from these two staging areas in the Teshekpuk Lake Special Area, nor from repeated use of rolligon trails traversing the Teshekpuk Lake area, and these are all serious impacts. BLM did not map nor evaluate the impacts of a can /staging area north of the ICagru River in their FEIS (BLM 1998, Northeast NPR - A, Final Integrated Activity Phan/ Fnvira rnantsl Impact Statement). The Puviaq project proposes to build as many as four major ice roads, and/ or rolligon trail networks to reach the well site ( see $g_ Remote Camp Pads and Staging areas). There are a number of ice roads and r+ollig m trails proposed to cross state lands to access Puviaq. Why should all be granted? There is no informstica provided in the Plan of Operations or any of the permit applications about why multiple access ioutes or camp staging sites are needed. Overland trail routes, other than associated with seismic surveys were not been analyzed by the BLM (1998). It is important that the ACM? consistency review also take into account the cumulative impacts of the Puviaq project exploratory wells, in combination with other exploration and development projects. Because many of the permits and a uthoriaations will be given fbr multiple years, iris impottasoa to look not only at the other activities proposed to take place concurrently this winter season, but to also other existing permed activities that could occur in subsequent years, CcnocoPhillips has requested a five-year approval from BLM for the ri On for the Barrow to Puviaq ice road and nave trails "for potenial use for other exploration drilling aperatices SENT BY: DIV OF GOV COORDINATIOI ; 272 3829; NOV -. 12:31PM; PAGE 6121 Amer Cwaeoo#Yons &Mask Memos Leapt 4 Commas on Pvrfuq Exploration Well Program November 4. 2002 near the Puviaq area," i and from the State for routes on its lauds yet these E plans are not described. The cumulative impact on fish, wildlife, habitats and subsistence needs to be assessed. On State lands, the ice roads, rolligon trails, related water withdrawals, spill risks., air pollution, and disturbance to wildlife and subsistence uses for Puviaq are additive to oil and gas activities taking place in the save vicinity for other exploratory wells (e.g. ConocoPhillips Cronus, Oberon and Placer wells; Anadarko's Hot Ice wells; Armstrong Resources Thetis Island exploration wells, etc.) as well as ice roads, rolligon trails, aircraft overflights and other activities related to the Alpine development. How much traffic will there be an the ice roads, especially to averwintering fish habitat due to Colville River crossings, other stream crossings? How much traffic will interfere with subsistence access to hunting grounds in the winter and spring. How much air pollution from rolligms and other vehicles, be added to the existing Alpine development drilling and Production omissions? Why are multiple ice mead networks needed fbr the Alpine and Nuigeut area? Which ones will actually be built? how does this relate to the ice road networks, and water withdrawals permitted by TWIJPa float existing permits? Furthermore, other oil and gas activities may be taking place throughout the NPR-A, both by ConocoPhillips and other oil companies, in addition to the Puviaq wells. ConocoPhillips' Plan of Operations stated that up to eight reservoir penetrations (two wells and two sidetracks at each of 2 Puviaq ) would be drilled by lime 2004. However, this year, ConocoPhillips also staked many locations fbr additional NPR -A exploratory wells (Grandview, Kokoda, and Summit Prospects). There are also dozens of other exploratory wells sites, ice roads, rolligon trails, etc. and related permits from 1999, 2000, 2001, and 2002 that am still active and may be drilled in the future by ConocoPhillips, a; well as BP's Trailblazer project. There is also seismic exploration activity expected to occur in the NPR -A, and on State lands, that will have cumulative impacts on vegetation, permafrost, soil qualities, noise, wildlife and subsistence disturbance, air pollution. Furthermore, a development proposal for Spark and Lookout Prop= is expected soon. Why is access from Barrow starting up at all? What are the environmental differences, if any, in potential impact between, the different rolligon trail alternatives from Barrow. What would the impacts to Atkasulc subsistence resources? Why are two ice airstrips needed at the Puviaq sites? The ice road or rolligon trails connecting the sites are proposed to cross the M%guakiak River, and many water withdrawal lakes are within its flooslplain, as area that is of significant concern as a subsistence, wildlife habitat, end traditional /cultural use area (see BI.M October 1998 Record of Decision, Stipulation 62. It does not appear that effects on this sensitive area have been avoided or minimized to the maximum extant. Having so many ice road and rolligon trail routes in a complex network around the tsmdra means that industrial disturbance sources will exist at many more locations, thereby risking disturbance to dimming polar bears, doming grizzly bears, groups of muskox, wintering caribou herds, and subsistence resources and activities. Contrary to lease stipulations, the Puviaq Plan of Operations is vague and superficial regarding subsistence caneuitataoas. It fails to discuss the " trahbtiple or simultaneous operations, such as exploration and delineation well drilling and seismic activities, that can be expected to occur during operations to more accurately assess the potential for any cumulative effects," as required 2 Phillips Alaska Inc. September 10, 2002, letter to DOA Meares, BI.M, request for BLM tight-of-way. SENT BY: DIV OF GOV C00RDINATI1 ; 272 3829; NOV- a 12:31PM; PAGE 7/21 Arc* Cae+ecolatr &Alarka iPFlalarneas L.aaBu e 5 Corneas an hiving 8xplorutaN Well Progrenn Nave,rber 4, 2002 by Subsistence lease stipulatian #61 (BLM ROD 1998). In particular, the Miguakiak River which commas with Teshekpuk Lake — and where numerous lakes are proposed as water sources and • stream crossings to connect up the two Puviaq wells are plamaal- --is an area of special sensitivity which is to receive special consideration under Stipulation #61. Spills in this area may have serious aaesMNences over a large area, because "while the Miguakiak River is usually the outlet of Teshekpuk Lake, stream flow reverses when the lkpikpuk River is flooding (Sloan, 1987" (BLM FBIS 1998, p, 111 but this potential effect was nix analyzed. For these reasons, the project fails to comply with ACMP Subsistence standard 6 AAC §110-120. ConocoPhillips proposes travel using roiligaas earlier in the seasa t, yet fails to provide any iaforrnatien that this travel by many vehicles will not adversely affect the tundra. In its application, the number of trips by the various vehicles to travel the various routes, the weight of the vehicles phis cargo, the nature of the cargo (fuel hauls, drilling muds and cuttings hauling, water hauls, heavy drill rig loads, etc.), and how that will affect the expected pressure on the ground should be provided None of this information was provided. Denning polar bears are more sensitive to disturbance earher in the season, so greater conflicts may be anticipated. Please also (=eider the compacts provided to Alaska Dot of Natural Resources regarding concerns of early winter rolligon and ice road construction (incorporate by reference, Sierra Club at al. October 23, 2002, letter to Mr. Harry Bader). Water withdrawals are proposed to take place directly out of Teshekpuk Lake_ This lake is unique. Ae the largest lake in the Alaskan Arctic, it has diverse fishery resources that provide important subaistrmee values. There is not evidence that alternatives which provide maxitmnm protection to these resources in the Teshekpuk Lake Special Area was provided. We have heard that the rollig= taking the drill rig for Puviaq tipped over at Tesheelquik Lake earlier this year (pars comm. Pamela A. Miller). Liquid water was present in the lake, contrary to expectations, so more intimation about the water resources and hydrology of the lairs is needed. An inoorniplete depth survey of Teshekpuk Lake was provided (=tour lines only shown for part of the lake), For this project, no new fishily or water volume studies were done in the field for Teshekpuk Lake, according to the information provided by CoaocoPhillips (September 10, 2002 application for temporary water use to ADNR). 'There is no evidence provided to support the contention that due "western basin "of Teshekpuk Lake it hydrologically separate from the teat of the lake and that the water volume can be calculated separately. The effects of removing water from the Teshekpuk Lake watershed on fish, waterfowl habitat, and water quality needs to be determined. On the state's lands, the cumulative effects of taking water tint of lakes 'within the Colville River watershed should be determined as this habitat is important to fish, wildlife, and subsistetice. If the same exact route is used by early rolligon traffic this year, over the same well as the m uglily 150 passes from the spring movement of the Puviaq well, how will this additional travel affect the tundra vegetation? What was the effect at stream crossings and through sand dunes, where visible trails were left last year? Furthermore, how all the ice roads, rolligon trails, etc. ibr Puviaq and other exploration and development projects relate to each altar has not been shown. Can disturbance' and need for water withdrawals for ice roads be minimized by consolidation in geographic area and temporally? Due to the proliferation of access routes, we do not fund that effect; an wetlands, wildlife habitats, inter'firence to subsistence resources and access have been avoided, or • SENT BY: DIV OF GOV COORDINATIO ; 272 3829; NOV- 6 4 /1) 12:31PM; PAGE 8121 Arctic Corinactiotu & Alaska Wilderness Lwow 6 Co/mama an Ageing Aploratlon Well Program November 4, 2002 nilnienized to the eateat possible. Inforenation on past tundra damage that oil companies repotted to the Alaska Department of Natural Resources and to the Bureau of Land Maw should be reviewed. The Plan of Operations ails to disclose the necessary amount of water for ice roads located east of the Puviaq wells. The Plan lists 123 million gallons Omar proposed for use for 68 voiles of ice roads from Barrow. two ice pads, camp and drilling use, two ice airstrips, connecting road spurs near the well sites to the airstrips and water sources. However, this total does not included the water needed for connecting ice roads to Kuparuk, or the two remote camp pads. Water is proposed to be withdrawn from fish-bearing lakes for ice roads, ice airstrip, ice pads, camp use and drilling use. Very limited studies have beta conducted. and it is unknown if the standard limiting water withdrawals to 15% ofthe water below maximum ice is adequate to protect fish, including broad whitefish, least Cisco, lake trout, nine-spine stickleback and others. Given the tact that most of the lakes where water withdrawals are proposed are -bearing lakes, we believe that prior to any water withdrawals front these lakes, site - specific studies of the recharge capabilities of these lakes should be done. Furthermore, the impacts of water withdrawals to the emergent wetland zone and littoral gone of the lakes should be done. Please incorporate by reference prior comments which address concerns about the effects of water withdrawals and ice roads that have not yet be adequately evaluated.' Removal of maw may reduce the =Mint of water present in a lake during water, and this factor should not be ignored in the calculations of wear withdrawal (see Plan of Operation', p. 9). Evoo though it is being proposed, the removal of snow cover or anew removal item fish - bearing weterbodies is prohibited under Stipulation # I9 (BI ...m ROD 1998). The state and Federal governments have pieoemealed their permit reviews. The Puviaq 01 ice pad, including water needs was permitted earlier and separately eon though it is an integral part of the total project. At that time, the Corps of Engineers permit application said the site was just going to be used for as a "temporary storage pad," and that "no drilling operations are planned for this site.' Now, ConuocoPhillips says the "Puviaq #1 location is adjacent to the insulated ice pad where the drill rig is stored," (Plan of Operations, p. S). And now, "the new ovversutmneratg Pad would ntiline a portion of the ice pad constructed for the Puviaq exploration drilling operations. In effect, the "temporary" pad is being expanded for the drilling activities, and in fact, the new 3 Northern Alaska Environmental Center. January 24, 2002_ Luger to Don Meares, US Bureau of Land Management Re: Envies Assessment on 2001 -2006 Winter Exploration Program in the National Petroleum Reserve-Alaska by Phillips Alaska, lac. (PA!) [AK-023 .02-0051; Northern Alaska Environmental Center. December 4, 2000. Letter to Don Meares, US Bureau of Land Management re Environmental Assessment on 2000 - 2005 Trailblazer Winter Exploration Drilling Program in the National Pethvieuto !reserve -ARad of by OP Exploration (Alaska), Inc. (A1(423 -01-001). Northern Alaska Environmental Center. November 26, 2000. Letter to Glenn Gray, Division of Governmental Coordination, RE: Alaska Coastal Management Program (RCMP) Celaistonhcy Review all 15 New Exploratory Wells in the National Petroleum Reserve - Alaska by Phillips Alaska. Inc. (PAl) Doming the 2001 -2006 Winter Drilling Seasons (A/0110- 040G). 1 U.S. Army Corps of Engine:a, Alaska District_ March 15, 2002. Public Notice of Application fin ' Phillips ,Alaska Inc, S 10, 2002. Letter to Mr. Mike Holley, U.S. Army Corps (C Engineers, request fur COE Approval, insulated ice pod construction for 2003 rig oveisummeting Puviaq area. SENT 8Y: DIV OF GOV COORDINATI, ; 272 3829; NOV -6 12:32PM; PAGE 9/21 A,+e a Cedeectioar &Alaska Wilderness League 7 Caranen'S ar Pwiaq &pion:rim Wall Program November A 2002 overvummering rig location for 2003 could continue the 'temporary" use of virtually the same • site for three years. The effects of thie whole use should have been taken into account at the • beginning. Nowhere has the applicant., nor the State assessed the effects of the total water withdrawal needed for the isitire project, and these permits have be piecaneasled and segmented improperly. The first Temporary Water Use Permits ('1WUPs A2002 -16) was issued without a full ACMP review, even though the water was used for an ice pad that required a Corps of Engineers Permit, and other BLM and State &aliphatic= were also required. No fish studies were dime in advance, according to Phillips' application. Phillips Alaska Inc. requested 500,000 more gallons of water in May, 2002 because they had wed the water needed due to site terrain. Now, ConecoPhillips has requested Fish habitat permits far the ice road or rolligan trails be issued under GC - 5, instead of part of the stmt ACMP review, and that they be good for Eve years even though the Plan of Operations only discloses the wells they plan to drill in the vicinity during the next two winters, not for the "potential future explorations drilling in areas near Puviaq." This is basically request for a blank check, since ADFA:G easmot know the nature of potential impacts if the sites have not been disclosed. The earlier approvals for the miliaria trails were similarly granted under General Concurrences, even though they ate integral parts of the same projects. Oj1 Spill Contingency Pip. Due to its close proximity to the Ilg►ikpuk River, Miguakiek Riv en, and the Teshekpuk Lake watershed wbida are rich in fishery and subsistence resources, we are concerned that the oil spill plan needs to address how a blowout may affect these resources. A new C•Plan should be required for NPR A Exploration, especially because of the extaasive access proposed from Barrow that would require different response measures than for operations based at Kuparuk or Alpine. Much of this area is very rtenote. The sensitive goose moltintg wetlands of Teshekpuk Lake, and habits used for threatened spectacled and Steller's eider nesting, staging, and fbeding dictates that a new plan be required in order to provide the beat response in the event of well blowout, drilling mud spill, fiael tank or fuel hauling vehicle spills. If no we roads are built to Puviaq tout Kuparuk or Alpine, how will response vehicles, including waste storage tom, be delivered to the spill sites? What were the resuks of the annual major spill- response field-deployment drill required by BLM (BLM 1998 ROD, Stipulation #12)? Wastewater discharges. CoaocoPhillips has not provided specific information about how it will dispose of wanewater discharges. We do not believe that EPA may issue an approval for these discharges under the North Slope General NPDES Permit No. AKG -31 -0000 because it has. expired. Furthermore, we are unsure that it that general permit applied to the area widvo the NPR -A. Its the event that all wastewater has to be `7r ruled to approved Wilkie, for treatiueiit and disposal" as stated in the application t to EPA, then this will greatly increase the amount untt of vehicle traffic with its noise, potential fir spills, and disturbing impacts across the ice road or rolligon networks. This impact needs to be figured into the ctnnulative impact analysis for Puviaq project, as well as the overall impacts of the ice road and rolli networks on the North Slope. Q uill g Wuta Disposal. Are the best to hnolog es available being proposed to deal with the drilling waste disposal. The application does not indicate the nature of the drilling muds that will be used, if a closed system for recycling and storage of drilling muds had been considered that would minimize the amount of wastes and the risks of spiltage. We are concerned about the cumulative impacts of drilling waste disposal to be done at the Alpine site, including the increased vehicle traffic and risk of drilling muds spills in this floodplain habitat. How many SENT BY: DIV OF GOV COORDINATI ; 272 3829; NOV2 12:32PM; PAGE 10/21 8 Arctic Can.ections & Alaska Wikknoss Laps Comfits= on Pwrfiaq asplonstion WsIt Prep= November 4. 2002 Other exploratory sites will be sending drilling waste to the Alpine site this year, or in the future years of Puviaq drilling, in addition to the development drilling waste from satellite its. What will the CaaRr'bation of vrehicles hauling drilling waste be to the average and peak vehicle trips made an the ice roads? Thank you for this opportunity to comment. Sincerely, a Pamela A, Miller Par-sided, Arctic Connections P.O. Box 101811 Anchorage, AK 99510 (907)272 -1909 Cindy Shogun Executive Director. Alaska Wilderness League 122 C. Street NW Washington, DC 20002 (202)544 -5205 Amatioidcamilticaz CC: Ted Rockwell, EPA Don Meares, BLM Corps of Engineers U.S. Fish and Wildlife Service SENT BY: DIV OF GOV COORDINATIO ; 272 3829; NOV -II 12:32PM; PAGE 11121 Nov -14 -2002 03:40pm From- T -007 P.001 F -325 TRUSTEES FOR ALASKA A Nonprofit Public Interest Law Firm Providing Counsel to Protect and Sustain Alaska's Environment 1026 W. 4th Ave., Suite 201 Anchorage, AK 99501 (907) 276 -4244 (907) 276 -7110 Fax November 4, 2002 Kaye Laughlin Project Review Coordinator State of Alaska, Office of the Governor Office of Management and Budget Division of Governmental Coordination Pipeline Coordinator's Office 411 West 4th Avenue Suite 2C Anchorage, Alaska 99501 -2343 By fax to: (907) 272 -3829 Re: Phillips Alaska,Inc.'s NPR -A Exploration Program (Puviaq #1 and #2 Exploration Wells), State ID No AK 0210 -0100 Dear Ms. Laughlin: Please ( accept these comments on the above - referenced consistency review trade on behalf of The Wilderness Society, Northern Alaska Environmental Center, Sierra Club, Natural Resources Defense Council, Greenpeace and the Alaska Wilderness League. Since the public is not given the opportunity to comment on a proposed consistency determination, we cannot know how DGC might apply the ACMP's statewide Standards, and those Enforceable Policies of the North Slope Borough identified below. We must therefore assume that DGC will carefully apply all of them and the relevant law and that this careful and lawful application will be evident in the consistency determination. At the outset it is also important to note that the statewide Standards and Enforceable Policies are focused on uses and activities of the project, not on the goal of the project. See, e.g., 6 AAC § 80.130(d)(1); see also Cook Inlet Keeper v, Stare, 46 P.3d 957, 965 (Alaska 2002) (remarking on the need for a "consistency review (that] comprehensively considers or finally determines the consistency of all permitted uses and in the whole project at issue"). For example, in activities included in e prof ) P app lying the statewide Habitats Standard DOC must determine that there is a public need for each proposed roltigon trail or ice road at their proposed lotratiun(s), and than there is no feasible and Puviaq #1 and +#2 ACMP Review 1 SENT BY: DIV OF GOV COORDINATIO ; 272 3829; NOV- 2 12:32PM; PAGE 12/21 Nov -04 -2002 03:40vm From- T-007 P.002 F -325 prudent alternative for each; this might entail a study of the route alternatives and their varying impacts and discussion in the conclusive consistency determination of alternatives considered, the potential for consolidation of routes, and so on. In other words, it is not sufficient for DGC to frame its analysis around the public need for, or lack of alternatives to, oil and gas exploration generally. The focus must be on each proposed use or activity that is part of the project. Further, DGC must address the impacts from all the uses and activities associated with the project, not just permitted uses and activities. In Cook Inlet Keeper the Supreme Court held that the consistency review must be for the entire project, not just particular uses and activities subject to permitting. 46 P.3d at 962 ("As the Alaska Coastal Management Act's implementing regulations make clear, the Act's consistency review requirements apply independently of, and in addition to, any requirements that attach to the issuance of a permit authorizing a discrete activity "), id. at 963 ( "these statutory provisions unequivocally establish that consistency review must be a project - specific process" (emphasis in original)), and id. ( "a consistency determination must encompass the entire project it covers "); see also 1985 Inf. Op_ Any. Gen. 1 (May 6, 1985) ( "a stare agency is required to review an 'entire project' to ensure consistency with the ACMP of activities closely associated with the permit application. "). in what follows, we will identify some aspects of the consistency review that DGC must address and which might otherwise not be given sufficient attention, Please do not assume that our list is completely inclusive, however, since without the ability to review and comment on the proposed consistency determination, we can only guess what issues DGC may address or may miss in its analysis. Statewide Standards. The following statewide Standards must be applied by DOC in its consistency review and addressed in its proposed and conclusive consistency determinations: 6 AAC 80.040 (Coastal Development), 6 AAC § 80.050 (Geophysical Hazard Areas), 6 AAC § 80.070 (Energy Facilities), § 80.080 (Transportation and Utilities), 6 AAC § 80.120 (Subsistence). 6 AAC § 80.130 (Habitats), 6 AAC § 80.140 (Air, Land, and Water Quality), and 6 AAC § 80.150 (Historic, Prehistoric, and Archaeological Resources)_ Goastai Development_S1an.d This statewide standard requires that DGC give priority first to water- dependent use and activities, second to water - related uses and activities, and finally to uses and activities which are not water - dependent or related, but "tor which there is no feasible and prudent inland alternative to meet the public need for • the use or activity." 6 AAC 80.040(a)(3). As part of the analysis, the "agency must .. . assess possible uses for the area in question for which applications have not been submitted ...." Stare of Alaska Coastal Management Program and Final Environmental Impact Statement (1979) ("rEIS ") at 538 (emphasis added). The phrase "feasible and prudent" means "consistent with sound engineering practice and not causing environmental, social, or economic problems that outweigh the public benefit to be derived from compliance with the standard which is modified by the Puviaq #1 and *i2 ACMP itevieW 2 SENT BY: DIV OF GOV COORDINATICO ; 272 3829; NOV- 12:33PM; PAGE 13/21 Nov -04 -2002 03:400 From- W T•007 P.003 /011 F -325 term 'feasible and prudent'." 6 AAC 80.900(20)_ The FEIS indicates that the phrase is used CO describe situations when a normally applicable standard may be departed from, - 'orcin _ . • •• • ' _ ee w' , I andard would he i ossibI - • cause a worse re ; ul than non- cospliance_" FEIS at 79 (emphasis added). Mere expense or inconvenience to private parties does not excuse compliance with a statewide standard; (O]ttly environmental, social and economic problems to the public were considered by the Coastal Policy Council] capable of overriding the public benefit to be derived from compliance with the habitat and energy standards. _ . . [Alternative language] was rejected precisely because OCZM representatives feared that it would allow relatively minor adverse effects on private interests to excuse compliance with the standards. ISIS at 572. There must be a showing, therefore, not only that it "would be impossible or cause a worse result than non - compliance" for Phillips' proposed use and activities to be located elsewhere or be configured differently than it has proposed, but also that other alternatives could not possibly suffice. FEIS itt 79. In DGC's analysis in that regard, it must take into account the fact the Puviaq #I and #2 are located within the Tesshekpuk Lake Special Area, which has panicularly important wildlife and subsistence values. In 6 AAC 80.040(a)(3) the phrase "public need" means [t]he proposed activity cannot merely be convenient, though it need nor be indispensable. The need is not that of an individual or corporation, but that of the community or some larger element of the public (e.g., state or nation). Market demand may be indicative but is not determinative, of the existence of Y , public need. • 1982 Inf. Op. Atty. Gen., File No, 366 - 734 -82, 1982 WL 43672, at 5012. See also FEIS at 537 (" `feasible and prudent' deviations from the normal standards should be narrow in interpretation and result only where the public good outweighs the public costs." (underlining in original)). The foregoing definitions of "public need" and "feasible and prudent" are also important to keep in mind during the application of the Habitats Standard's tripartite test in 6 AAC § 80.130(d). Cumulative impacts, In the FEIS for the RCMP, the State asserted that the Coastal Development standards require a general balancing process taking account of public need, alternatives, cumulative effects and effects on wetlands, fish and wildlife, water quality, scenic and recreational values, public safety, water dependence, and access LO coastal waters. Pavia(' #1 and 42 ACMP Review 3 SENT BY: DIV OF GOV COORDINATIO ; 272 3829; NOV -. 12:33PM; PAGE 14/21 Nov -04 -2002 03:41pe Fran T -007 P.054/011 F•325 FE1S, at 3 - 4.' Since then in Trustees for Alaska v. Stare, DNR, 851 P 1340, 1344 (Alaska 1993), the Alaska Supreme Court (quoting Trustees for Alaska v. Gorsuch, 835 P.2d 1239, 1246 (Alaska 1992) reiterated the need for "early review of cumulative environmental impacts" and pointed out that the "environmentally protective purposes" of the ACMP require that at the time .. , [the agency] reviews any , .. permit application 1d consider the prob ble_eumulauve impact of all anticip d activities which will be a part of (the oroiect in question). whether or not the activities ar' m .of the permit under review. If , .. (the agency) determines that the cumulative impact is problematic, the problems must be resolved before the initial permit is approved_ !d n. 8 (emphasis added). A useful and oft - recognized definition of cumulative impacts comes from federal regulations governing environmental reviews. A project's "cumulative impact" is defined as the impact on the environment which results from the incremental impact of the action when added to other past, present, and reasonably foreseeable future actions .... Cumulative impacts can result from individually minor but collectively significant actions taking place over a period of rime. 40 C.F.R. $ 1508.7. One federal appellate court recently outlined what a cumulative impacts analysis must include: • meaningful cumulative impact analysis must identify (1) the area in which the • effects of the proposed project will be felt; (2) the impacts that are expected in that area from the proposed project; (3) other actions- -past, present, and proposed, and reasonably foreseeable- -that have had or are expected to have impacts in the same area; (4) the impacts or expected impacts from these other actions; and (5) the overall impact that can be expected if the individual impacts are allowed to accumulate. Grand Canyon Trust v. F.A.A., 290 F.3d 339, 345 (D.C. Cir. 2002). A useful handbook in performing a valid cumulative impacts analysis is the US. Council on Environmental Quality's Considering Cumulative Impacts Under the National Environmental Policy Act (January 1997). Whatever methodology DGC decides to use in evaluating cumulative impacts, we request that DOC identify it in the conclusive consistency determination. ' Over twenty year agn, the Alaska Attorney General opined that the ACMP stances required consideration of the cumulative impacts of a project's development. Set generally, Inf. Op. Atty. Gen. File No. 1 - 66. 502.81 (July 16, 1982). 2 The EELS for the ACMP acknuwlcdgca that while "districts would attempt to anticipate cumulative impacts through the district program development process," the state permitting agency "will be to u bettor position to assess cumulative impattus than will do districts themselves?' Id. at 572. £ uviaq #1 and X12 ACMP Review 4 SENT BY: DIV OF GOV C00RDINATI* ; 272 3829; NOV -E,. ! 12:33PM; PAGE 15/21 Nov- 04 -I002 03,4lpa From- T-407 P.4051011 F -325 In any event, in considering uses and activities associated with Puviaq #1 and #2, DOC must take into account other past, ongoing, proposed and reasonably foreseeable projects both within and near the northeast corner of the National Petroleum Reserve= Alaska ("Reserve "), quantify and evaluate their impacts, and determine what the overall cumulative impacts might be. Inside the northeast corner of the Reserve, since 1998 there already has been established a number of rolligon and seismic lines and trails, and exploration sites, which must be taken into account in this analysis. Habitats Standard. Virtually all of the habitats identified under this standard are implicated by the uses and activities proposed as part of Phillip' project. See 6 AAC § 80.130(a)(1) — (8). Thus, DOC must apply each of the applicable standards in 6 AAC § SO.130(b) and (c). The Habitats Standard applies "regardless of the use or activity under consideration," FEIS at 71. It is worth mentioning "wetlands" habitats especially, since wetlands proliferate on the lands that Phillips proposes to use. The Habitats Standard requires that wetlands "be managed so as to assure adequate water flow, nutrients, and oxygen levels and avoid adverse effects on natural drainage patterns, the destruction of important habitat, and the discharge of toxic substances." 6 AAC § 80.130(c)(3) (emphasis added). Because wetlands are "vitally important," FEIS at 74, the word "avoid" in the standard "is used to apply a strict limitation on impacts, to the point of prohibition .... The directive word 'avoid' was used to keep the habitat standards extremely stringent" FEIS at 72; accord Kachernak Bay Conservation Society, 6 P.3d 270, 288 n. 61 (Alaska 2000); FEIS at 576 ("OCZM interprets several of the standards requiring `avoidance' of certain effects as strict prohibitions. 6 AAC 80.130(d), with its `feasible and prudent' criterion, is necessary to allow for consideration of countervailing factors, though with a strong presumption in favor of adherence to the prescribed standard. "); DGC, Guidebook 3 — Contents of a District Coastal Management Program 118 (1999) ( "Standards that use the word 'avoid' are quite stringent, because the word 'avoid' means to prevent from occurring, "). This means that the Habitats Standard normally prohibits the use of wetlands for development projects. "Where the public interest requires some flexibility in the application of ... (the Habitats] standard( 1", 6 AAC § 80.130(d) "provides a series of stringent tests that divergent activities must meet to be allowed." FEIS at 72; see also id. at 76 (6 AAC 80,130(d) describes the "types of extenuating circumstances that must be demonstrated before an exception to the policies just described can be made ") and at 281 ("Because the[Habitats] standard[ ] affordts] complete protection, an exception is provided which would allow non-conformance with the standards in the case of a significant public need for the use, and no reasonable alternatives. The use or activity must still minimize degradation of the habitat, "). 6 AAC § 80.130(d), therefore, is comprised of three " 'stringent additional conditions' ", Kachemak Bay Conservation Society, 6 P,3d at 286, that are "strongly protective," Trustees for Alaska, 851 P.2d at 1344, and to which agencies must give -scrupulous attention." Id. n. 6. Under this tripartite test, DGC must first show that there Puviaq #1 and #2 ACMP Review 5 SENT BY: DIV OF GOV COORDINATI ; 272 3829; NOV-6 12:34PM; PAGE 16/21 Hoy -64-2002 2002 03:41pm Fro- T -007 P.006 /011 F -325 • I is a "Agnificant public need" for the use or activity. 6 AAC 80.130(dO(I) (emphasis added). This is an even higher standard than the "public need" standard under the Coastal Development Standard discussed above: While the distinction between a 'public need' and a 'significant public need' is necessarily somewhat subjective, factors such as immediacy of the need and the potential for loss of life or harm to health could assist in the classification. The higher standard found in 6 AAC 80.130 is reflective of the ACMP's goal of protecting Alaska's natural coastal resources. (Citation omitted.) 1982 Inf. Op. Atty Gen., File No. 366 - 734 -82, 1982 WL 43672, at 5012. DGC also must show that there is no feasible or prudent alternative for each use or activity that Phillips proposes. 6 AAC § 80.130(d)(2). IF the public need and no feasible or prudent alternative parts of the test are satisfied, DGC must still ensure that "all feasible and prudent steps to maximize conformance with the standards contained in (b) and (c) of this section will be taken." 6 AAC § 80.130(d)(3). Subsistence S1 lldgd. Whether or not uses or activities associated with the Phillips' project will be located in an Area Meriting Special Attention ( "AMSA "), under the Subsistence standard since the project's uses and activities may impact a subsistence AMSA, a subsistence impact study is required by 6 AAC § 80.120(d), See Decision and Order in The Villages of Parr Graham er al. v. State, Case No. 3AN-96-0854C1 (Sup. CE. Third kid. District, J. Sigurd Murphy). In that case the Superior Court held that even though an offshore oil and as platform was not located in a subsistence AMSA, because the platform's uses and activities (i.e., wastewater discharges) could conceivably impact the AMSA, a subsistence study was required under 6 AAC § 80.120(d). At issue here is the large Colville River Delta subsistence AMSA, which includes lands east of Nuiqsuir in the Reserve and other lands outside the Reserve that may be crossed by rolligon trails and ice roads. See map and description in North Slope Borough Coastal Management Program Areas Meriting Special Attention Phase I Report (June 1989). The subsistence study must focus on "the possible adverse impacts of the proposed po tentially co _ icting use ox ac vi y upon subsistence usage." 6 AAC § 80,120(d) (emphasis added), The study then must be used as a basis for requiring that "appropriate safeguards to assure subsistence usage" are provided. id. Air, Land and Water Quality Standard, On behalf of a number of client organizations, we have previously made comments to DEC on proposed draft air quality control permits for Puviaq #1 and #2 and amendments to Phillips' North Slope Exploration, 011 Discharge Prevention and Contingency Plan, ADEC Plan Number 024 - CP -5096 (May 2002). We hereby incorporate those comments here by reference, since DGC must ensure compliance with DEC's applicable statutes and regulations under :6 AAC § 80.140, Should you like us to send you a copy of those comments, please let us know. Puviaq 01 and 02 ACM" Review 6 SENT BY: DIV OF GOV COORDINATI ; 272 3829; NOV -6 12:34PM; PAGE 17/21 Nov -04 -2002 03 ;4Ipm Fran- T -007 P.007/011 F -325 North Slope Borough Policies. Following are the potentially applicable North Slope Borough Coastal Management Program Enforceable Policies that we believe may apply and must be considered by DGC in its consistency review and proposed and Conclusive consistency determinations. 2.4.3 Standards for Development (a) When extensive adverse impacts to a subsistence resource are likely and cannot be avoided or mitigated, development shall not deplete subsistence resources below the subsistence needs of local residents of the borough. ¥ + (d) Development shall not preclude reasonable subsistence user access to a subsistence resource. * +A (e) Development which is likely to disturb cultural or historic sites listed on the National Register of Historic Places; sites eligible for inclusion in the National Register; or sites identified as important to the study, understanding, or illustration of national, state, or local history or prehistory shall 1) be required to avoid the sites; or 2) be required to consult with appropriate local, state and federal agencies and survey and excavate the site prior to disturbance. (Descriptions of sites identified to date are contained in Appendix C of the North Slope Borough Coastal Management Program Background Report and referenced on Map 2 of the NSB Resource Atlas.)' (t) Development shall not significantly interfere with traditional activities at cultural or historic sites identified in the coastal management program. (g) Development shall not cause surface disturbance of newly discovered historic or cultural sites prior to archaeological investigation. (h) Development shall comply with state or federal land, air and water quality standards or regulations. 2.4.4. Required Features for Aoulicab fl w 400me (a) Vehicles, vessels, and aircraft that are likely to cause significant disturbance must avoid areas where species that are sensitive to noise or movement are concentrated at times when such species are concentrated. Concentrations may be seasonal or year -round and may be due to behavior (e.g., flocks or herds) or limited habitat (e.g., polar bear denning, seal haul - outs). Horizontal and vertical buffers will be required where appropriate. Concern for human safety will be given special consideration when applying this policy. Puviaq #1 and #2 ACMP Review 7 SENT BY: DIV OF GOV COORDINATI1 ; 272 3929; NOV- 12:34PM; PAGE 18/21 Nov- 04 =ZQO2 03 :4Zpm From- T -001 P.008/011 F -3Z5 (b) Offshore structures must be able to withstand geophysical hazards and forces which may occur while at the drill site. Design criteria must be based on actual measurements or conservative estimates of geophysical forces. In addition, structures must have monitoring programs and safety systems capable of securing wells in case unexpected geophysical hazards or forces are encountered. (c) Development resulting in water or airborne emissions must comply with all state and federal regulations. (d) Industrial and commercial development must be served by solid w aste disposal P Y po facilities which meet state and federal regulations. (e) Development not on a central sewage system is required to impound and process effluent to state and federal quality standards. (g) Offshore drilling operations and offshore petroleum storage and transportation facilities are required to have an oilspilI control and clean -up plan. The plan must contain a risk analysis indicating where oilspills are likely to flow under various sets of local meteorological or oceanographic conditions. Impact areas must be identified and strategies fully developed to protect environmentally sensitive areas; the spill control and clean -up equipment which is available to the operator and the response time required to deploy this equipment under the various scenarios must be contained in the risk analysis. (j) Residential development associated with industrial and resource extraction development must be removed and the area rehabilitated to standards consistent with the coastal management program when the industrial or extractive use is completed, unless removal is more environmentally harmful than nonremoval. (k) Impermeable lining and diking is required for fuel storage facilities with a capacity greater than 660 gallons. ILIA Best Effort Policies All development must comply with each of the policies set out in sections 2.4.5.1 and 24.52 unless 1) the following criteria have been established; or 2) the policy is not applicable to the development. (1) There is a significant public need for the proposed use and activity; and (2) The development has rigorously explored and objectively evaluated all feasible and prudent alternatives to the proposed use or activity and cannot comply with the policy. When alternatives are eliminated from consideration, the reasons for their elimination shall be briefly documented by the developer. Puviaq #1 and #2 ACMP Revitw 8 SENT BY: DIV OF GOV COORDINATI ; 272 3829; NOV -8 12:35PM; PAGE 19/21 Nov -04 -2092 03 :42pm From- T -007 P.309/011 F -325 2.4.5. I Development of the following categories or types will be allowed only if the development has met the criteria under 2.4.5 above, and the developer has taken all feasible and prudent steps to avoid the adverse impacts the policy was intended CO prevent. • (a) Development that will likely result in significantly decreased productivity of subsistence resources of their ecosystems. (b) Development which restricts subsistence user access to a subsistence resource. 4' (d) Development on or near a shoreline that has the potential of adversely impacting water quality (e.g., landfills, or hazardous material storage areas, dumps, etc.). (Near, as used in the phrase near the shoreline, is defined as that area within a 1,500 foot setback from the inean high water mark along the coast, Lakeshore, or river). (t) Transportation development, including pipelines, which significantly obstructs wildlife migration. w (h) Duplicative transportation corridors from resource extraction sites. * (j) Placement of structures in floodplains subject to a 50 year recurrence level and in geologic hazard areas as identified on the following coastal management craps in the NSB Resource Atlas: Map 6 - Areas of moderate and severe ridging and historic ice override. Map 7 and 22 - Areas of moderate and severe ice ridging. 2.4.5.2 The following are required of applicable development except where the development has met the criteria of 2.4.5 above, and the developer has taken all feasible and prudent steps to maximize conformance with the policy. (b) Development is required to be located, designed, and maintained in a manner that prevents significant adverse impacts on fish and wildlife and their habitat, including water circulation and drainage patterns and coastal processes. (e)12esource extraction support facilities, including administration offices, operations, residences, and other uses not absolutely required in the field, must be located in a designated service base which is sited, designed, constructed, and maintained to be as compact as possible and to sharp facilities CO the maximum extent possible. (1) Transportation facilities and utilities must be consolidated to the maximum extent possible. (g) Development within the Alaska Coastal Nlanagcrnent Program defined coastal habitats rnust be conducted in accordance with ACMP Standard 6 AAC 80.130(b), (c), and (d), and applicable policies of the North Slope Borough Coastal Management Program. These habitats include the following: Puviaq 01 and 02 ACMP Revizw 9 SENT BY: DIV OF GOV COORDINATI* ; 272 3829; NOV- 12:35PM; PAGE 20/21 Mow04 -2002 03:42om From- T -007 P.010 /011 F -3Z5 1. Offshore areas; 2. estuaries; 3. wetlands and tideflats; 4. rocky islands and seacliffs; 5. barrier islands and lagoons; 6. exposed high - energy coasts; ?. rivers, streams and lakes; and 8. important upland habitat. (h) Development is required to be located, designed, and maintained in a manner that does not interfere with the use of a site that is important for significant cultural uses or essential for transportation to subsistence use areas. 2.4.6 Minimization of Native Impacts. Applicable development is required to minimize its impact as follows: (b) Siting, design, construction, and maintenance of transportation and utility facilities (including the ice roads) are required to minimize alteration of shorelines, water courses, wetlands, tidal marshes, and significant disturbance to important habitat and to avoid critical fish migration periods. (c) Development is required to maintain the natural permafrost insulation quality of existing soils and vegetation. (d) Airports and helicopter pads are required to be sited, designed, constructed, and operated in a manner that minimizes their impact upon wildlife. (e) A means of providing for unimpeded wildlife crossing shall be included in the design and construction of structures such as roads and pipelines that are located in areas used by wildlife. Pipeline design shall be based on the best available information and include adequate pipeline elevation, ramping, or burial to minimize disruptions of migratory patterns and other major movements of wildlife. Aboveground pipelines shall be elevated a minimum of 5 feet from the ground to the bottom of the pipe, except at those points where the pipeline intersects a road, pad, or caribou ramp, or is constructed widen 100 feet of an existing pipeline that is elevated less than 5 feet. Temporary pipelines (not to exceed 6 months) are exempt from this policy. (t) Development in floodplains, shoreline areas, and offshore areas is required to be sited, designed, and constructed to minimize Ioss of life or property due to riverin.e flooding, icings, streansbanlc erosion, oceanic storms, sea waves, ice gouging and override, and shore erosion, (g) Seismic exploration must be conducted in a manner that minimizes its impact on fish and wildlife. Puviaq #1 and #2 ACMP Review 10 • SENT BY: DIV OF GOV COORDINATIO ; 272 3829; NOV -. 12:35PM; PAGE 21/21 Nov-IA-202 43 :42pm Prow T -001 P.011/011 F -325 Thank you for considering these comments. Should you wish further information with respect to these comments, please feel free to call me. Sincerely, Michael k Staff Attorney Puviaq #'L and #2 ACMP Review 11 SENT BY: DIV OF GOV CO0RDINATI010 ; 272 3829; OCT -1 1:33PM; PAGE 1/30 y ! FAX TRANSMITTAL STATE OF ALASKA DIVISION OF GOVERNMENTAL OFFICE OF THE GOVERNOR C � COORDINATION r° ��� �' JOINT PIPELINE OFFICE 'PONY KNOWLES 4.? re5 411 W. 4 AVE., SUITE 2C GOVERNOR ' - _ ANCHORAGE, AK 99501 FRAN ULMER LIEUTENANT GOVERNOR o Telephone: (907) 271 -4317 �' d Agµ Fax: (9071 272-3829 Date: October 16, 2002 Pages: 29 + cover From: Serena Sterrett Phone: 907-257-1353 E -mail: ssterret a jpo.doi.gov Regarding: Puviaq #1 & #2 Exploratory Wells (AK 0210-010G) To Harry Bader Fax No.: (907) 522 -9583 Leon Lynch, Gary Schultz, Larry Byrne 451 -2751• Jim Baumgartner 465 -5129• Larry Bright 456-0208. Peter Ditton 267 -1267• Mike Holley, Joy Earp 753 -5567 • Jeff Mach, Ron Doyel 465 -5070 Lydia Miner 269 -7687 Don Meares 474 -2386 • Rosa Meehan 786 -3816 Al Ott, Jack Winters 456 -3091 Matt Rader 269 -8938 Steve Schmitz 269 -8943 Leslie Simmons 269 -7655 Kellie Westphal, Patricia Bettis 269 -8947 Tom Maunder, Steve Davies 276 -7542 Sharman Stambaugh, Alan Kukla 269 -7508 ' Steve Schmitz, Bruce Webb 562 -3852 Glenn Gray 465 -3075 Comments: Letter from Native Village of Barrow Ifynu received this FAX in error, phase Immediately notify the sender by telephone, awl return this FAX to the sender at the above address. Thank you. SENT BY: DIV ?OF GOV COORDINATIO. ; 272 3929; OCT -111 1:33PM; PAGE 2130 pci THE NATIVE VILLAGE OF BARROW i..s./ ,,,-:7--r7 INUPIAT TRADITIONAL • '' .' , `. .. :'.;\ GOVERNMENT F\ ,..), ........, cm, c— wk** aF . lijaC VED October 8, 2002 --; 77, ms Alaskauki G Kaye Laughlin, Project Review Coordinator won -. - n Division of Governmental Coordination ati c Joint Pipeline Office - . . 411 W. 4 Ave., Suite 2C Anchorage, Alaska 99501 RE: NPR -A EXPLORATION PROGRAM (Puviaq #1 & #2 Exploration Wells) State ID No. AK 0210 -01OG . Initiation of State ACMP Review Dear Ms. Laughlin: ,. The Native Village of Barrow is the Northern most Federally recognized tribe incorporated under the Indian reorganization Act of 1934, as amended in 1936 for the Alaska Natives. It's Corporate Charter and Constitution and By -Laws were certified on March 21, 1940. Our Mission Statement is to protect and promote Inupiat Rights, self- determination and self-sufficiency; as well is preserve and strengthen inupiat Culture and Traditions for tribal members by providing quality services in a fair and accountable manner. We also represent our Tribal Members that hunt around the area of the proposed site. The Native Village of Barrow has the responsibility as trustee for restricted native lands to ensure protection of the individual property. rights. The Native Village of Barrow strongly objects to this project to be done by PhillipsConoco Alaska, Inc. . a The proposed project is in and around the subsistence hunting areas of our Tribal Membership. The Bureau of Land Management claims they own land, but there are • numerous Certified Native Allotments and cabins belonging to our membership and these are Trust Property protected by the Federal Government. Has the State of Alaska Department of Governmental Coordination had its public hearings on the proposed projects in Barrow .1AfitlitheRcal people that will be affected? P.O, Box 1139 • Barrow. Alaska 99723 • Phone: (907) 852 -4411 or 1400 - 475-4412 • Fax: (907) 852 -8844 SENT BY: DIV.OF GOV COORDINATION ; 272 3820; OCT -1 1:33PM; PAGE 3/30 Kaye Laughlin, Project Review Coordinator Division of Governmental Coordination October S, 2002 Page two We have submitted our comments to the Corp. of Engineers objecting to the ice airstrip that is being proposed because we don't know which lakes they will be obtaining water from for their ice pads. We don't know how much damage will be done to our environment because of such activity. It stated in their notice that there are no listed or eligible properties that are of historical or cultural value in this area. In whose standards, did they determine of the area having no historical or cultural value? How will all the Tundra travel affect the migratory routes of the caribou? 1 am enclosing a copy of letter dated 10/7/02 addressed to U. S. Army Corps of Engineers in reference to #4- 2002 -0988 Waterway #lkpikpak River 2 Project from our office. One of our concerns was on the fish bearing and non - fish bearing lakes, who did the study on which lake bears fish and which doesn't? I am also enclosing a comment letter dated 10/07/02 addressed to the North Slope Borough regarding NSB 03-042 Draft Development Permit, NPR -A Puviaq Ice Airstrip, Puviaq Exploration Wells, Conservation District. The Permit Application submitted by Philips Alaska to the NSB Land Management Administrator states that a maximwn of 10.22 millions of water withdrawal will be done for the purpose of construction and maintenance of airstrip, but in the scope of project submitted to the State of Alaska states a very different number of one hundred twenty -three million five hundred twenty - thousand gallons (123,520,000). Which number is the true number? Why do they conflict? On the very same permit submitted to the North Slope Borough Land Management Administrator, on the fuel/hazardous material section, it states that less than one thousand (1,000) gallons will be stored for small generator for airstrip, AND in the State of Alaska Scope of Project, it states another very different number of seventy -five thousand (75,000) gallons of diesel fuel at each well site and another three hundred seventeen thousand (317,000) gallons of crude oil. Again, which number is true? Why are they not being consistent? These are just a very few issues of our concerns that we are expressing to you and relaying to you our objection to the Puviaq #1 & #2 Projects. • SENT BY: DIV.OF GOV COORDINATIO1 ; 272 3829; OCT -1 1:34PM; PAGE 4/30 Kaye Laughlin, Project Review Coordinator Division of Governmental Coordination October 8, 2002 Page three If you have any questions or comments, please do not hesitate to call or write us. A 4 )orothy • sen Realty Director Cc: Lloyd Leavitt, Executive Director Tribal Council, Native Village of Barrow Mayor George Ahmaogak, Sr., North Slope Borough Rex Okakok, Sr., North Slope Borough Planning Sheldon Adams, North Slope Borough Permitting Anthony Edwardsen, Ukeagvik Inupiat Corporation Bill Tegoseak, Inupiat Community of the Arctic Slope Jim Wolfe, U.S. Army Corp_ of Engineers, EFB, Anchorage Niles Cesar, Regional Area Director, BIA, Juneau Jim Howard, Regional Realty Director, BIA, Juneau Pearl Chanar, Realty Rights Protection, BIA, Anchorage Tom Brower, EPA/Wildlife, Native Village of Barrow Files • SENT BY: DIV,OF GOV COORDINATION ; 272 3826; OCT -1 1:34PM; PAGE 5/30 NATIVE VILLAGE OF BARROW 7.;%...." w' .r INUPIAT TRADITIONAL i • V� October 7, 2002 US Army Corps of Engineers Alaska District Regulatory Branch (1145b) P.O. Box 898 Anchorage, Alaska 99506 -0898 REFERENCE #4- 2002 -00988 WATERWAY #IKP'UK RIVER 2 The Native Village of Barrow is the Northern most Federally recognized tribe incorporated under the Indian reorganization Act of 1934, as amended in 1936 for the Alaska Natives. It's Corporate Charter and Constitution and By -Laws were certified on March 21, 1940, Our Mission Statemem is to protect and promote Inupiat Rights, self- determination and self - sufficiency; as well as preserve and strengthen Inupiat Culture/Traditions for tribal members by providing quality services in a fair and accountable manner. We also represent our Tribal Members that hunt around the area of the proposed site The Native Village of Barrow has the responsibility as trustee for restricted native lands to ensure protection of the individual property rights. All transactions are considered within the long - range best interest of the owners and that native landowners are fully informed of options and services available to them in achieving self - determination in the exercise of their property rights. The Native Village of Barrow Realty Department is to provide to the landowner competent. impartial and unbiased advice, professional guidance, and sound judgment on diversified problems in the real estate field. The Native Village of Barrow strongly objects to this permit filed by Phillips Alaska, Inc. for an ice pad to over- summer a drilling rib We don't know which lakes they will be obtaining water from for their ice pad_ We don't know how much damage will be done to our environment because of such activity. It states in the notice that there are no listed or eligible properties that are of historical or cultural value in this area. In whose standards, do you determine of an area having no historical or cultural value? • P.O. Box 1139 ■ Barr.ivt', Alus4:a 99723 ■ J'Iwihe: (titf7) ? >52 -- 7.:,11 ur 1- 80'.1--7 - 4412 a Fax: (9(U) 852 -8•44 SENT BY: DIV. OF GOV COORDINATIO, ; 272 3829; OCT -1, 1:34PM; PAGE 6/30 • Corp of Engineers October 7, 2002 Page two We know that there is a lot of historical and cultural value according to our elders and young hunters alike. We have a lot of published Traditional Land Use Inventory books and a lot of oral history that our elders have passed on to us regarding the area that we live in. On the Essential Fish Habitat portion of the notice, it is stated that they will not adversely affect the habitat and that they have read the assessment but it does not guarantee anything. We are very concerned that disturbing habitat in these waters may be contributing to the decline of fish and other subsistence resources that our Tribal Members depend on. This area is also known as the historical range and critical habitat of the threatened Spectacled and Stellers Eiders and therefore we strongly object to the permit filed by Phillips Alaska, Inc. We hear from the Tribal Members for the Native Village of Nuiqsut on the permitted lakes for ice roads in that area and how these lakes are now, the fish have died off causing the empty lakes to stink because too much water was taken out and not enough precipitation or runoff to refill the lakes. We would like to know on the maps provided by Phillips (sheet 2 of 5 of the Public Notice) who determined which lakes are fish bearing and non -fish bearing? Who did the study? When the study was done? These are questions being asked by our membership. A majority of our Native Allotment holders (people that hold title to land) and our membership that do their hunting activities in the proposed area do not know of this or any other project developing in or near their subsistence grounds and we strongly oppose any development in this area that will affect the wildlife and environment that is a habitat for our subsistence resources. incere , L roth4 ar• �- Realty Director Cc: Niles Cesar, Superintendent, Juneau Area Office Jim Howard, Acting Regional Realty Office, Juneau Area Office Pearl Chanar, Realty Rights Protection, Lloyd Leavitt, Executive Director, Native Village of Barrow Tom Brower III, Environmental Program Manager/Wildlife, NVB Carolyn Edwards, Realty Director, ICAS Files SENT BY: DIV,OF GOV COORDINATIO, ; 272 3829; OCT -f 1:34PM; PAGE 7/30 Public Notice US Army Corps Al D aka District of Application for Permit Regulatory Branch (1145b) Post Office Box 6898 Elmendorf APB, Alaska 99506 -6898 PUBLIC NOTICE DATE: September 25, 2002 EXPIRATION DATE: October 25, 2002 • REFERENCE NUMBER: 4- 2002 -0988 WATERWAY NUMBER: Ikpikpuk River 2 Interested parties are hereby notified that an application has been received for a Department of the Army permit for certain work in waters of the United States as described below and shown on the attached plan. APPLICANT: Phillips Alaska, Inc., Post Office Box 100360, Anchorage, Alaska 99510 -0360. LOCATION: The insulated ice pad is proposed to be located at either Puviaq #1 in section 35. Township 16 N, Range 10 1Q, Umiat Meridian, Latitude 70° 42' 3.996" N, Longitude 154 24' 19.770" W, or at Puviaq #2 in Section 16, Township 15 N, Range 10 W, umiat Meridian, Latitude 70 39' 37.071" N, Longitude 154 29' 7.586" W, in the National Petroleum Reserve (NPR -A), west of Teshekpuk Lake, approximately 67 miles southeast of Barrow. WORK: Phillips Alaska, Inc. is proposing to construct and utilize a 1.5 acre insulated ice pad to oversummer a drilling rig in waters of the United States. The dimensions of the pad will be approximately 245 feet by 265 feet by-6 inches thick. The ice pad will be covered with standard 8 -foot by 24 -foot by approximately 4 -inch to 6 -inch thick, 25 psi expanded polystyrene foam insulation. The panels weigh approximately 700 pounds each. The panels will be sandwiched between 8 -foot by 24.foot sheets of 7/16 -inch thick oriented strand board. Reinforced polyethylene film (visa - ueen) would be laid under the panels to prevent them from bonding to the ice pad to ensure easy pick -up. Exposed panel surfaces will be covered with a white, opaque surface fabric that is designed to minimize thermal gain, minimize rainwater infiltration to the ice surface, and minimize thermal erosion of the ice pad. Standard rig mats will be placed on the insulated panels with the drilling rig sitting on the mats. Ice berms may be constructed to divert spring runoff from the pad. Berms will he approximately 3-foot high, roughly trapezoidal in cross- section with an 8 -font wide base and 4 -foot wide top. PURPOSE: To create a temporary storage pad to oversummer a drilling rig. ADDITIONAL INFORMATION: The drill rig that may be stored at this site is slated to drill exploration wells at two locations (Puviaq #1 and Puviaq #2) during the winter of 2002 -2003. If drilling operations are not completed during this winter, Phillips Alaska proposes to oversummer the drill rig at either site in order to be able to initiate exploration drilling in the winter of 2003 -2004. The new SENT BY: DIV OF GOV COORDINATION ; 272 3820; OCT -i 1:35PM; PAGE 8/30 Puviaq exploration drilling operations. The ice pad used for oversummering the drill rig in 2002 will not be used for oversummering of a drill rig for the 2003 season. The rig will be left at this new site until winter tundra travel is opened in the NPR -A. After that time, the drilling rig will drill one or more wells in the vicinity of the storage site before moving to other areas. Rope anchors will be utilized to resist wind uplift forces on thole panels not protected by the rig. Ten or more thermistor sensors would be installed to monitor ice - surface temperatures. The site will be monitored every 2 to 3 weeks over the summer to collect thermistor sensor data and to provide site maintenance. WATER QUALITY CERTIFICATION: A permit for the described work will not be issued until a Certification or waiver of certification as required under Section 401 of the Clean Water Act (Public Law 95 -217), has been received from the Alaska Department of Environmental Conservation. COASTAL 2ONE MANAGEMENT ACT CERTIFICATION: Section 307(c)(3) of the Coastal Zone, Management Act of 1972, as amended by 16 U.S.C. 1456(c)(3), requires the applicant to certify that the described activity affecting land or water uses in the Coastal Zone complies with the Alaska coastal Management Program. A permit will not be issued until the Office of Management and Budget, Division of Governmental Coordination has concurred with the applicant's certification. PUBLIC HEARING: Any person may request, in writing, within the comment period specified in this notice, that a public hearing be held to consider this application. Requests for public hearings shall state, with particularity, reasons for holding a public hearing. CULTURAL RESOURCES: The latest published version of the Alaska Heritage Resources - Survey (AERS) has been consulted for the presence or absence of historic properties, including those listed in or eligible for inclusion in the National Register of Historic Places. There are no listed or eligible properties in the vicinity of the worksite. Consultation of nhe AHRS constitutes the extent of cultural resource investigations by the District Engineer at this time, and he is otherwise unaware of the presence of such resources. This application is being coordinated with the State Historic Preservation Office (SHPO). Any comments SHPO may have concerning presently unknown archeological or historic data that may be lost or destroyed by work under the requested permit will be considered in our final, assessment of the described work. ENDANGERED SPECIES: The project area is within the known or historic range of the threatened Spectacled and Steller's Eiders. Preliminarily, the described activity will not affect threatened or endangered species, or their critical habitat designated as endangered or threatened, under the Endangered Species Act of 1973 (67 Stat. 544). This application is being coordinated with the United States Fish and wildlife Service and the National Marine Fisheries Service. Any comments they may have concerning endangered or threatened wildlife or plants or their critical habitat will be considered in our final assessment of the described work. ESSENTIAL FISH HABITAT: The proposed work is being evaluated for possible effects to Essential Fish Habitat (EFH) pursuant to the Magnuson Stevens Fishery Conservation and Management Act of 1995 (MSFCMA), 16 U.S.C. et seq and associated federal regulations found at 50 CFR 600 Subpart K. The Alaska District includes areas of EFH as Fishery Management Plans. We have reviewed the January 20, 1999, North Pacific Fishery Management Council's Environmental. Assessment to locate EFH area as identified by the National Marine Fisheries service (NMFS). We have determined that the described activity within the proposed area will not adversely affect Em, including anadromous fish and federally managed fishery - resources. SPECIAL AREA DESIGNATION: None. -2- SENT BY: DIV.OF GOV C00RDINATIO ; 272 3920; OCT -1 2 1:35PM; PAGE 0/30 EVALUATION: The decision ...tether to issue a permit will be eased on an evaluation of the probable impacts including cumulative impacts of the proposed activity and its intended use on the public interest. Evaluation of the probable impacts, which the proposed activity may have on the public interest, requires a careful weighing of all those factors which become relevant in each particular case. The benefits, which reasonably may be expected to accrue from the proposal, must be balanced against its reasonably foreseeable detriments. The decision whether to authorize a proposal, and if So, the conditions under which it will be allowed to occur, are therefore determined by the outcome of the general balancing process. That decision should reflect the national concern for both protection and utilization of important resources. All factors which may be relevant to the proposal, must be considered including the cumulative effects thereof. Among those are conservation, economics, aesthetics, general environmental concerns, wetlands, cultural values, fish and wildlife values, flood hazards, floodplain values, land use, navigation, shore erosion and accretion, recreation, water supply and conservation, water quality, energy needs, safety, food and fiber production, mineral needs, considerations of property ownership, and, in general, the needs and welfare of the people. For activities involving Section 404 discharges, a permit will be denied if the discharge that would be authorized by such permit would not comply with the Environmental Protection Agency's 404(b)(1) guidelines. Subject to the preceding sentence and any other applicable guidelines or criteria (see Sections 320.2 and 320.3), a permit will be granted unless the District Engineer determines that it would be contrary to the public interest. The Corps of Engineers is soliciting comments from the public; Federal, State, and local agencies and officials; Indian Tribes; and other interested parties in order to consider and evaluate the impacts of this proposed activity. Any comments received will be considered by the Corps of Engineers to determine whether to issue, modify, condition or deny a permit for this proposal. TO make this decision, comments are used to assess impacts on endangered species, historic properties, water quality, general environmental effects, and the other public interest factors listed above. Comments are used in the preparation of an Environmental Assessment and /or an Environmental Impact Statement pursuant to the National Environmental Policy Act. Comments are also used to determine the need for a.public hearing and to determine the overall public interest of the proposed activity. Comments on the described work, with the reference number, should reach this office no later than the expiration date of this Public Notice to become part of the record and be considered in the decision. Please contact Mr. Jim Wolfe at (907) 753 -2716 or toll free in Alaska at (600) 478-2712, if further information is desired concerning this notice. AUT1ORITY! This permit will be issued or denied under the following authorities: (x) Discharge dredged or fill material into waters of the United States - Section 404 Clean Water Act (33 U.S.C. 1344). Therefore, our public interest review will consider the guidelines set forth under Section 404(b) of the Clean Water Act (40 CFA 230). A plan, Notice of Application for Certification of consistency with the Alaska Coastal Management Program, and Notice of Application for State Water Quality Certification are attached to this Public Notice. District Engineer U.S. Army, Corps of Engineers Attachments O (*) elio P . i . CD ^ ar I ... Il . LLI CD 4 4 At k O A i i € ; .` Ni Beaufort SeaSeaS htJlcupe r - : E 1 y 4 � 1 ��w� PoheiilRU�pa1 Ms ,` ��•tom �� 'rpJ� arr r MP to Audi LO C. I i I 1 ' 7 ' _ '" a,1 a ■ r .0 ►alMttlm7C.9mi b fipsi (T' ..r1} ' A _ tE ' e + IN 41 >m02 VOW tows.* r l i �tw I '; melon ' DM Locums S' 111 L 1. ii° ; r)[- . a a. 5 E�r}; 4, •� J ►....� r• a➢9&PLOl flare a rat u } C � 1! v 1111111. „r + u �� p `� l 1 11 1 91 1 41:01 remr.ro NO MO r 1 .. 4 : _ err ' r' „Ai `1 . ,... . L a rt-41 hijet L . .. . . L )..., .1"y% airf..441X411Ww.....FARPlit � `F ir: . 1`d S� a r °E a • it r r: ” iIJ �� l , F - r T '-/ ' '1 ' ' ' . L ' r) a U - 1 a';t , O . f INIV414111111 - l - . � . L -” _., 1' a i . y } � 5C ti 10, , 'l, r v r. �' 0 j •ct jai .., ) I l r ` e : ' " J�ti ,.A., C i 7 . ott :1 c 0 1 ` © 1 � n _ O .� J;: •h ; L � ' ' n ]a }'•� y 4 , Z i ,° , 1 l � . 7 r f r ti � ' +�M r 8, N .t. f r _ l i ' r r . . • - u :'4 t . P� �� � i `) !" y 1 5 .t3 �n @� r� r at wi nitimy 0. AiiIIIIII4 co 1 1• \ i irs11 ; . J -. �? 1 _ , cn - Qa41'.L r, -n I /� � , ,!'� CV +57p.. V i1!� . $"''- , -.-• -� ' t 1 •.a, CU ,.13,;...... #'� ex .,,,.... a• - ',-� ' " �'� - I�,r.'1i�7•. d a, -l: Eq , iii:.. ' . - v A 1/4-,- 7, at r V id I .. : .... 4 .rk 1., i , ilL ''' 1' k ' 0,,.. . ...a ,. -_ 1.1 (,,, ) 4 xi r ... i J c o i. '�! r - � t ' I '�p '� L RAZ ; f: lv Ci . l �. �c , .l - ► ".`R r �.,.. I .S n � : 'del ,. � 4 . ' � � ` ? . `-6 • SS �, rt� c '1 1 �,; "s•".1 _ 1 ' - ir' 1-3-'" j .~_ _ _ y'• C+ �1 0 / St E. 4 G L , r a � j Le tri r ` FU'rk a • ,' C: . -� • _� + � .. • s . r f J '��i 1A ,U ;.% Mil /Ili ,+ - T y" +r `4 � r r �`r f - ,6 � - A r' RiPliggikrildpillAirdi � i:. �•'- - - -- +.poi 0 Inge P' :: , . ... i �� `�• `' yt . )gZ V in es- 5 � , r� . t, irgiv,--,„-=.1y,,,r PHILLIPS Alaska r� . ��i,.. � ��� CD : s � ■�rNrt rnawa*etwww i Inc. Il , arww c Inilleti cl it w en s � i :,, , , r 1!'?' r='� i PR-�A Pavia • �., r� ` � ti d�� n Weil Locations I— co ' Ikpikpuk River 2 e L.� - a.. I r r ..., - • • SENT BY: DIV.OF GOV C00RDINATIOl ; 272 3829; OCT -116 1:36PM; PAGE 11/30 . - Ai - 4r ki 6- ; " -1 c �.i :.4 ? - t.�. '' + f ■ - / d t, .. 6 I'•' f. z : ..- IIPL i :-.,,21 46 — 4: :') _b re r \ 4 ' 1 ell '''' ° - ir, ,, . L - al 0 4 " ;V D % r d i ) . P.. ' I L, l' • 4 + .. ;* '',.. • i .. J : • ' 444 V. : ' ie .. :, ..-( 1: 1L.,. 1. + 9 4 : 't 0 , ,, 4 ) ...te • Y ■ �• � ' sa l . - • �',C r. -.. ` a • Al- �'r i '{• c t t,.._,-, T� i O -1 `, r ■i ce- -. .. , ,` °! �i t ham 4) , 0 ,,,, ...-..r: p„..3, " . ":. r _ :d.c: , -:-• `".•., " ' •- - , .+. \ \) 4 Y L q-'''` 2, ,- *4 11 . , dl „_. „,,,0 • . _ 4,, tk i • cc' V . , di y MI it; e9 ■Nkit- Ai air ‘ A, , - i 19 ■ 4 ' f lika '5 NM cf7g '' ( T _ `� . .a I .L.,. ' ', $ , o ^ y , a �� ii , ...... , F o r 4 , , If 116- i ill!' .....W 1 0 Itit Al 010 ^ . ' , 1 -r 44 712T ° . 14'6 S NAN* t . 0 algae, iliT2ria.., 4 ' IIP4 4411e ... PHILLI 1 . , a, Inc nc. +p't f 7 „ -[ Non rii Lakes EXhibit 3 r , 1,, M 4 1 ng Puviaq I &` 2 rfffflititir;51.71•IStli t nti l W r Sc r , a ate u ce r Location Map o E P it Alaska ocation Map ,MLES 8a -02 02082401C00 tkpikpuk RiVar 2 Sheet: 2 of 5. Date: 9/7/02 CD CO CV ul Pam Wow of Pod carver, No Sad. CD -ct 1• w riL•Ib,r \ ' IM F lrtrhrar MOM p6rt ` Ice Mention lo on Bel '. I CO 1 r eOWmletWooF4 r Wisher ail amp Amiga 1 i ...... .m .w.. I I A A Nab tatllip�A,rpaN � � tad1A91e�d. Panel Panel nilrtl�aWwgaPwt an _ , i 1 V I • ' : € • . '•' • • i • • aI Plan View of Insulated Pad Corner Conceptual Location Ice Diversion Berm CO N Elevation Section A-A, No Same . ^ 1'x 4'Lwnber 1.25' to r Steel Pipe WitlOe Sodom Fabric e (Edge of Parlm Mkt) t) 0Vet Panels _______ Polyelhylene 1111 _ Foet core insulated Panel -. Ikpikpuk River 2 - — _ --- Panels 1-1 F - . T Phillips Alas r _ T ,. • r s, :a, inc. • z :.: d ' .r , :fir:'' ,:.' Pad i 66' 1-1 in � a - - .- - - �•_ _ t1= .: c;.. a ...�_...... �. A Subsidiary alPhillips P noleurnCcmpe y CC : .. .A A n A. A. A ✓\ A A A A A. A AA A A. A. A A. A A A f' .. CS - n A A A .'\ A A A A A A A A A A A A A A A A A A A A CS A A A A A A n n A A n A A A A is A A A. A A n A A A - (_) n A A A A A A A A A A A A A A A A A A A A A A A A. A A A A A A A A A A A A • 1 L1 laL lli� iit./4 icc Pad , N. A A A A. A A A A A A A A A A A A. n A A A n A A A J 1 /\ A ..-.. /5 A A A A n /\ /n p n t A A A A n A A A A A A A A A A A n n n n A A n A A }yam /�y� c (..D A A n n D A A A A A A A A A A A A A A A A A A A A A, Insulation Details C3 Insulated Panel, Ice pad and Tundra Cross - Section H Shee 3 of 5 Date: 9/7/02 in r m • I— z w CO C3 ' C7 CO ■ U.1 CD . d CL 4' Length of 3/4' Manilla' Rope 2'x8' [Amber 4' Diameter White, m Wooden Washer Tail of Rope Stapled n to Washer areenamerrow 10 4 --. 1 . U � _ :4 i i• 6 Thi c 1 Ce Pa O ate.: %411,5...„,,,,,b,...illril; , n n n i\ 6' /\ ' /\ n 4+ f y et J .,.' -414a" y4 , .Mt1.1461 � M� � . " /•• " /\ /\ /\ /\ /\ -� 4 6 4 ' ' ~ Qi CV � _ �� a 3.5' Diameter Hole. m '�! Sada!! with N � N :b�+.:; - .;.�;{ r. Cuttings &Ice = Schematic Design of hope Anchor a ,. ~ 1 / • V e * 1 F fy rfe All 1 1 4.4, , F y i tar • � � 't ^ f I • L .. O _ r -i S? fdt ,. r s r ♦ Ikpikpuk River 2 1 o 'IA i i . i . ; r ` s 3 Phillips Alaska, Inc. im 0 0 A Subsidiary of Phillips Pelrolcum Company ci > Photo of Rope Anchor Schematic Design and o Photo of Rope Anchor > H n • Sheet: 4 of 5 Date: 9/7/02 } - m• 1— z' L1.1 0 w cD OVFJPALL LENGTH r s Is'-a ' k / � 1115? ♦* * Y CL r I co.:* KUF7. BEO 11d11EA5. Flgir Plk1F5 � imam PIM P% ETC- SSA Ems. , 1 hi Ili , gUIRURRUI II * � • r sue e�9E 4 /11.5'-0' . VOW 1 III PPE SHED III 1111 F r oat_ PPE t ~ i I :nhInIuI! k IUIiUU • t • • ♦ ■e Si !t !�! �I ^ Ir! i i ' °mc PIPE •+♦* 1 !a k AR = -- z H i ♦ i • i i ♦ • • % i i *•i ♦•♦ i• ♦••e • ♦ Oi i' ♦ ♦ ♦ .!._ + ,i.�..W .. �.. ♦• •i•i . ♦� to �.s ...4.7 i * *. nett, ♦ +. * . ♦..• time o° Ikpikpuk River 2 12 FOOT POTENTIAL ' Al i :. 8.7 ; ' o PAD MELTING ZONE Nolan AWL) 2s a i. 4 i (VW TYPICAL NABOBS ALASKA DRILLING RIG - J " LL OVERSUMMERING STACKOUT CONFIGURATION "a OUTUAISPIS EP Roll COMMIE% o w EV it r1 sew auckw-socx m sheet: 5 of 5 Date -: 917 /92 . I— z : w U7 ' SENT BY: DIV OF GOV C00RDINATIO• ; 272 3829; OCT -16 1:37PM; PAGE 15/30 • TONY KNOWLES, GOVERNOR STATE OFALASKA OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION SOUTHCENTRAL REGIONAL OFFICE 550 W. 7` Avenue, Suite 1660 ANCHORAGE, ALASKA 99501 PHONE: (907) 269- 7470/FAX: (907) 269 -3981 NOTICE OF APPLICATION FOR CERTIFICATION OF CONSISTENCY WITH THE ALASKA COASTAL MANAGEMENT PROGRAM Notice is hereby given that a request is being filed with the Division of Governmental Coordination for a consistency determination, as provided in Section 307(c)(3) of the Coastal Zone Management Act of 1972, as amended [16 U.S.C. 1456(c)(3)], that the project described in the Corps of Engineers Public Notice No. 4 -2002 -0988, Iknikuuk River 2, will comply with the Alaska Coastal Management Program and that the project will be conducted in a manner consistent with that program. The Division of Governmental Coordination requests your comments, particularly on the proposed project's consistency with the affected local coastal district management program. For more information - on the consistency review process, comment deadlines, and the affected coastal district status, or to submit written comments, please contact the Division of Governmental Coordination at 550 W. 7'' Avenue, Suite 1660, Anchorage, Alaska 99501, (907) 269 - 7470. Attachment 2 • SENT BY: DIV OF GOV COORDINATIOo ; 272 3829; OCT -142 1:37PM; PAGE 16/30 TONY KNOWLES, GOVERNOR S TATE OF ALASKA OFFICE OF THE GOVERNOR DEPT. OF ENVIRONMENTAL. CONSERVATION DIVISION OF AIR AND WATER QUALITY Non -Point Source Control Section 401 Certification Program NOTICE OF APPLICATION FOR STATE WATER QUALITY CERTI Any applicant for a federal license or permit to conduct an activity that might result in a discharge into navigable waters, in accordance with Section 401 of the Clean Water Act of 1977 (PL95 -217), also must apply for and obtain certification from the Alaska Department of Environmental Conservation that the discharge will comply with, the Clean Water Act, the Alaska Water Quality Standards, and other applicable State laws. By agreement between the U.S. Army Corps of Engineers and the Department of Environmental Conservation, application for a Department of the Army permit to discharge dredged or fill material into navigable waters under Section 404 of the Clean Water. Act also may serve as application for State Water Quality Certification. Notice is hereby given that the application for a Department of the Army Permit described in the Corps of Engineers' Public Notice No. 4_-2.00 - 0988, Ikoikpuk River 2 serves as application for State Water Quality Certification from the Department of Environmental Conservation. After reviewing the application, the Department may certify that there is reasonable assurance that the activity, and any discharge that might result, will comply with the Clean Water Act, the Alaska Water Quality Standards, and other applicable State laws, The Department also may deny or waive certification. Any person desiring to comment on the project with respect to Water Quality Certification may submit written comments within 30 days of the date of the Corps of Engineer's Public Notice to: Department of Environmental Conservation WQM/40 t Certification ' 555 Cordova Street • Anchorage, Alaska 9950I -2617 Telephone: (907) 269 -7564 FAX: (907) 269 - 7508 SENT BY: DIV OF GOV C00RDINATIO, ; 272 3829; OCT- i 1:3813M; PAGE 17/30 TH E .4 NATIVE VILLAGE BARROW ; :, ",. '- ,, � � • e I PIAT TRADITIONAL /Q., i i GOVERNMENT Irpr- ..:::.,'...„.; :.,..',..) 1 ',.. y c �IMI / 1 * r 411 O F W' October 7, 2002 Mayor George Ahmaogak North Slope Borough P.O. Box 69 Barrow, Alaska 99723 Rex A. Okakok, Land Management Administrator North Slope Borough Planning P.O. Box 69 Barrow, Alaska 99723 RE: NSB 03-042, DRAFT DEVELOPTMENT PERMIT, NPRA PUVIAQ ICE • AIRSTRIPS NPRA PUVIAQ EXPLORATION WELLS, CONSERVATION DISTRICT Dear Gentlemen: On behalf of our Tribal members, the Native Village of Barrow strongly objects to the construction of the two (2) ice airstrips on the tundra and any other ice roads that may be built in the future. The proposed airstrips are estimated to use ten million two hundred twenty thousand (10,220,000) gallons of water. That is a lot of water to take from permitted lakes. On the Essential Fish Habitat portion of the notice, it is stated that they will not adversely affect the habitat and that they have read the assessment but it does not guarantee anything. We are very concerned that disturbing habitat in the waters may be contributing to the decline of fish and other subsistence resources that our Tribal Members depend on. This area is also known as the historical range and critical habitat of the threatened Spectacled and Steller's Eiders and therefore we strongly object to the permit filed by Phillips Alaska, Inc. We hear from the Tribal Members for the Native Village ofNuiclsut on the permitted lakes for ice roads in that area and how these lakes are now, the fish have died P.O. Box 1139 • Barrow. Alaska : r3 • Phone: [90) h5 -4411 01 J- 8llil -472e -4412 • v.: (91T 852 -8844 SENT BY: DIV, OF GOV COORDINATIOo ; 272 3829; OCT -1 2 1:38PM; PAGE 18/30 NSB Mayor/Permitting October 7, 2002 Page two off causing the empty lakes to stink because too much water was taken out and not enough precipitation or runoff to refill the lakes. In the General Stipulations of the September 17, 2002 letter to Phillips, #5 states ".....In order to comply with this stipulation the permittee and its agents shall contact Me Mayor or City Manager and the village corporation of any village most affected by this permit. In this case contact the village of Nuigstit, Kuukpik Corporation, City of Barrow, and UIC. What about the Government to Government relationship with the Tribes who hold Trust Responsibility and work for the best interest of its membership? And the most affected are the Native Allottees whom the Tribes work with. Quyanagpak for your time and we hope that your decision will be for the best interest of the people that we serve. ely, Dom . , '� , ., air Realty Director Co: Lloyd Leavitt, Executive Director Toni Brower, EPA/Wildlife Director Files SENT 8Y: DIV OF GOV COORDINATION ; 272 3829; OCT -1. 1:38PM; PAGE 19/30 NoEcru SLOPE I )ROUGE sl przi PLANNING 'DEPARTMENT Res :1 l)l.;tl:uk, Sr., Director <S P.O. Box 69 �+ " • '." ::< Barrow, Alaska 99723 • -• `"" ' • Phone: 907.852 -2811 = - -� 907- 852 -0320 DRAFT p Erltll] 1'I - 1-ZEQU1± S'1' FOR ( 0M111FN'I r' ' . ' • ` , Fax; 907 -852 -0322 • • 1 y "f*Maraird IMtl3,. C'()E1lAl€NTS DUE B1 : OCTOBER 7 ?U()2 P his is a draft Development Permit only for the purposes of review and gathering comment during the comment period prescribed by NSB111C 19. It contains conditions proposed for inclusion in a final permit, if a decision is made to issue a final permit. This draft permit should not be taben to mean that the proposed project is, or will, be approved. Only upon issuance of a final permit will the proposed project be approved to commence. September 17, 2002 Mark Major, Senior Environmental Coordinator Phillips Alaska, Inc. P.O. Box 100360 • Anchorage, Alaska 99516-0360 Re: NSB 03 -042, Draft Development Permit, NPRA Puviaq Ice Airstrips, NPRA Puviaq Exploration Wells, Conservation District • Dear Mr. Major: We are in the process of reviewing your request to construct up to 2 ice airstrips on frozen tundra to provide access to the Puviaq exploration locations in the NPR -A. • Large aircraft (e.g. Hercules or other similar aircraft) may be used for provision of materials and supplies for portions of or all of the Puviaq drilling activities. An ice airstrip is planned for each Puviaq site. The airstrip at each site will be located on the frozen tundra. Only one airstrip is likely to be constructed to support Puviaq exploration drilling activities. Aircraft may be used to transport supplies from Camp Lonely, Barrow, Kuparuk, or other locations within Alaska. If aircraft are used, these items would then be transported to the well site by rolligoti or by cum entional transport equipment (e.g. trucks and trailers) if an ice road connecting the ;airstrip and ell lcc:aliO,) is construeteti. if can Ice road from Barrow is consu'ucted, the ice airstrip would primarily be used for situations such as crew change -outs and emergency access. Tlit proposed ice airstrip locations are shown in Exhibit A7. An estimated 10,220,001) gallons of water will be used from permitted lakes. We have preliminarily determined that your proposed development is consistent with Title 19 • provided that you comply with the following conditions: SENT BY: DIV.OF GOV COORDINATIO, ; 272 3829; OCT -111 1:38PM; PAGE 20/30 lute,, i (L„1: f1 Win t 4:•;)1 u-i -u.}? Project Adr isory - 1'eimitlre shall hire .t local resident tpieicrahly someone who knows the area such as someone whose cahitt or native allotment is located in the Le.neral area) to wort: as a guide during construction and to monitor the activities of the proposed project uonstructitm. Project Specific Stipulation(s) I. All industry personnel shall not be allowed in the subsistence campsites unless permission has been obtained from the cabin owner(s) and or the native allotment owners. Perniittee will he responsible for any trespass that occurs from the industry personnel. 2. PAI shall construct snow bridgecs) in the Miguakiak River where needed before hauling water from the permitted water lakes to avoid damage to the river banks and to the tundra. 3. PA! shall use a wire mesh screen during water withdrawal to avoid accidental intake of fish. Less than 15° o of the total water volume below 7 feet shall be used in these water withdrawal activities. Economic Stipulations I. The applicant is advised that the Borough strongly encourages those seeking to do business on the North Slope to conduct their operations in a manner, which enhances locally - based economic and employment opportunities for Borough businesses and residents. in order to ensure that these goals have been considered in the design and administration of project operations the applicant shall submit an economic opportunity plan to the Land Management Administrator that outlines, in detail, how the policies o tallied b elow a nd codified at NSBMC 19,70.030 have been addressed. Developers are encouraged to conduct operations to the extent practical and feasible: A. Using suppliers or subcontractors from within the Borough for work, which can be accomplished competitively by local private businesses or regional or village Corporations. B. Employing local Borough residents, unless residents on he 1 ocal villages express no interest in the work. C. Utilizing flexible employment procedures, which allow the pursuit of subsistence opportunities by Borough resident employees. U. Incorporating job - training programs targeting Borough residents. E. Generating excess tax revenues over demand for expenditures by the development. 2. The applicant shall present the economic opportunity plan to the Borough Planning Commission for consideration prior to commencement of operations. SENT BY: DIV. OF GOV C00RDINATIOo ; 272 3829; OCT -11, 1:39PM; PAGE 21/30 3 • letter it, t.t ii k NtaJtti Ril tl3.iJ4? ICE RO_)A1)S, 1 DS AND A11tSTRI I'S 1. W ;tier may he extracted only from sources approved by the Alaska Ueparinient of Fish and Game. • ?. Ice roads are not to cross Native Allotments unless authorized by the allotment owner. 3, Onshore ice road construction is not 10 commence until frost has penetrated the ground to a depth of one -Ibot. The ice road is to be ni aintaineil at a rn inim thickness of Si x (6) inches. (NSBMC 19.50.t130(J) pg 25; INSBMC I9.b0.i) pg 2$. 4. Spills of fuels, hydrocarbons, or chemicals on ice pads shall be cleaned up thoroughly prior to break - up to prevent damage to the underlying tundra when the ice pad melts (NSBMC 19.50.030) (J); (NSBMC. 19,60.040)(0). 5. In the event that an alternate ice road route is required, all surface vehicles are to confine travel as much as possible to only those areas and times of year with sufficient (6 inches) snow cover in order to protect the underlying tundra (NSBMC ] 9.60.040)(0). TUNDRA STIPULATIONS 1. Vehicles shall be operated in a manner such that the vegetative mat of the tundra is not disturbed and blading or removal oft undra o r v egetative c over i s prohibited unless specifically approved by the Land Management Administrator or his designee. Snow ramps, snow /ice bridges or cribbing shall be used to cross frozen water bodies to preclude cutting, eroding or degrading of their banks. Snow ramps and snow /ice bridges shall be substantially free of soil and debris and of sufficient thickness to support vehicles. Snow /ice bridges must be removed or breached, and cribbing removed after final use or prior to breakup, whichever occurs first. Frozen water courses shall be crossed at shallow riffle areas, if such areas exist. Where such areas do not exist, an environmentally preferred location will be identified. Vehicles shill) not be abandoned. (NSBMC 19.60.040 0., NSBMC' 19.70.050 L. 3., NSBCMP 2.4.6(c)). 2. Existing roads and trails shall be used wherever possible. Trail widths shall be kept 1n the minimum necessary. Trail surface may he cleared of timber, brush, stumps and snags (NSBMC 19.70.050 L. 1 and 1, NSBCMP 2.4.6th) and (C)). 3. Movement of equipment through willow (Salix) stands shall be avoided where possible (NSBMC 19.70.050. K 2., NSBCMP 2.4.5.2(b)). 4. Trails and campsites must be kept clean. Al] solid waste including incinerator residue shall be backhauled 10 an authorized solid waste disposal facility (NSBMC SENT BY: DIV. OF GOV COORDINATIO* ; 272 3829; OCT -itl 1:39PM; PAGE 22/30 teller h, flack t'l joi NSIi 16-u42 1 0.70.050 I. 4. and 5., NSFiCMP 2. and (e)). • 5, All haiardous material containers and fuel drums shall be marked with the contractor's initials and dated. 6. Fuel storage facilities shall not he placed within 100 feet of water bodies,(NSI3MC' 10.70.1)501. 1 NSBCMP 2.4.4(k)). 7. Tundra travel shall not cross Native Allotments unless authorized by the allotment owner. The pemiitlee shall consult BLM Status plat, and with the Inupiat Cori mtaiity of the Arctic Slope, Reality Officer (IC'AS) (907) 852- 4227), prior to all operations to ensure surface operations do not cross or impact existing or pending Native Allotment claims without prior authorization. 8. Only those vehicles approved for summer /winter travel use by the State of Alaska Department of Natural Resources, Division of Mining, Land and Water Management are permitted. 9. Vehicle maintenance, campsites, and /or storage and stockpiling of material on the surface ice of lakes, ponds, or rivers is prohibited. JO. Winter on tundra travel may begin when six inches (6 ") of snow cover and twelve inches (12 ") of frost depth conditions exist for the activities intended as determined by an authorized field representative of the Land Management Administrator. Certain on- tundra activities may begin sooner than others depending on the impact or magnitude of the operations ( NSBMC 1 9.70.050 L. 3., NSBCMP 2.4.6(c)). i I. Crossings of rivers and streams is to be restricted to only those areas where the ice is • frozen solidly to the river /stream bed to avoid impacts to potential fish overwintering areas (NSBMC 19.70.050 K. 2., NSBCMP 2.4.5.2(b)). 12. Aber April 15, 2003, on-tundra travel shall be subject In termination within 72 hours of notification by the Land Management Administrator or his/her designee for protection of surface vegetation ( NSBMC 19.70.050 L. 3., NSBCMP 2.4.6(c)) 13. A completion report shall he submitted within thirty (60) days upon termination of permit :activities. This report shall contain the following information: Actual routes of travel, and, if utilized, the location of all camps depicted on a USGS topo map. • - A list of vehicles used for any off -road travel which may have taken place. - Statement of clean -up activities. Methods of disposal of garbage and other camp debris. • SENT BY: DIV OF GOV COORDINATION ; 272 31329; OCT -1 1:30PM; PAGE 23/30 3 kH.i �n dark Ntaj „� NSB 113 -0-I2 - A report covering any known incidents of I undra damage and follow-up corrective actions that may have Laken place while operating under this permit. - Any tundra damages that have occurred shall be reported to the • Permitting Di' ision attn: Waska Williams, Jr., Field Inspector at (9197) 852 - 1)440 - Report any tundra damage within 24 hours and consult with NSB Permitting staff with any questionable activity unsure of. General Stipulations 1. The permitlee is reminded to conform to the provisions of NSBMC Chapters 9.08, 9.12 and 9,16 regarding solid and sanitary waste collection disposal and potable water. The proper and lawful disposal of waste in an environmentally sound manner is a condition of this permit. If the permittee does not anticipate using facilities operated or approved by NSB, the Alaska Department of Environmental Conservation at (907) 269 -7500 shall he contacted for an approved sanitary and solid waste disposal plan as well as a plan for potable water for temporary and permanent facilities described in this permit. A copy of the approved plans shall be submitted to the North Slope Borough Permitting and Zoning Division to become a part of this permit file. NSBMC 19.70.050(J)(4) &(5), NSBCMP 2.4.4(d) & (e) 2. Should any cultural, archeological or paleontological resource materials (including, but not limited to artifacts, house mounds, grave sites, ice cellars, and fossilized animal remains) be discovered in the course of activities conducted under this permit, the site shall not be disturbed and the North Slope Borough inupiat History, Language and Culture Commission shall be promptly notified at (907) 852 -0422. NSBMC 19.70.050(E) through (G), NSBCMP 2.4.3(e) . through (g) 3. All oil and other hazardous material spills over 55 gallons shall be reported immediately to the NSB by telephoning (800)478 -6606. The follow -up written report will be faxed to the NSB Permitting and Zoning Division fax (907) 852 -5991 and the NSB /OSEA office at (907) 852- 0327. A report of all spills shall be submitted to our office on a weekly basis. A sufficient amount of absorbent materials shall be on hand at all times in the event of any fuel, oil, or chemical spills. 5'pil)s shall be cleaned up as soon as possible. NSBMC 19.50.030(1), NSBCMP 2.4.3(h) 4. The Land Management Administrator may require that his authorized representative he on -site during any operations conducted under this permit. NSBMC 19.30.100 5. Within the constraints of federal, state and local law, the permittee and its agents are encouraged, through .a voluntary affirmative action program, to hire and train residents of the North Slope Borough. In order to comply with this stipulation the permittee and its agents shall contact the Mayor or City Manager and the village corporation of any village most affected by this permit_ In this case Contact the village of Nuigsut at (997) 489 -6727 and Kuukpik SENT BY: DIV OF GOV COORDINATION ; 272 3829; OCT -10 1:39PM; PAGE 24/30 rr Ieuer un i'.•1 iJ lttetrr NSf 1i3.04 Curporat (907 - le0- 10U0, the City of Ban at 1907) 852-5211 ,ind the 1-llypeagvik lnupiat Corporation at 1907) 852 -0440 to determine if there are qualified people available or people who could he employed lair on-the-job training. NSBMC 1 9,71).030 ti. The pcnnitlze shall comply with all local, state and federal laws and permits applicah]e to this project, NSI3MC 19.30,100 7. This permit is valid for the duration of the existence of the development and the developer's compliance with the terms and conditions herein. T his p ermit a utont,atically expires w ithin twelve months of approval if no actual dc.‘ .lupment has commenced. Failure to comply with the conditions of this permit could result in immediate revocation o f t his p remit, N SI3NI(' 1 9.30.1)70 8. The pewultee shall inform and ensure compliance with these stipulations by its agents and employees. This permit shall be posted in a conspicuous place for these individuals to see. NSBMC 19.30.100 Our review of your application dated September 10, 2002 is being conducted in accordance with NSB11'JC, Title 19. The purpose of our review is to ensure that your project achieves the goals and objectives, and implements the policies, of the Borough Comprehensive Plan, including its Coastal Management Program; to ensure that the future growth and development of the Borough is in accord with the values of its residents; to identify and secure, for present and future resi- dents, the beneficial impacts of development; to identify and avoid, mitigate, or prohibit the negative impacts of development; and to ensure that future development is of the proper type, design and location, and is served by a proper range of public services and facilities. You are encouraged to contact this office if you wish to discuss the applicability of the above conditions to this approval. By copy of this letter, we are soliciting comments from the below - listed individuals and their respective agencies regarding the adequacy of the above stipulations to meet the purpose of our review. Comments on the adequacy of these stipulations should be sent to Johnny L. Aiken, Special Assistant to the Land Management Administrator, at the address above or by telephone at ( Sincerely, • F A kakok, Sr., Land Management Administrator cc: NSB Planning Commission Doreen Lampe, Lands Officer, Planning, NSB Linda Chre >rrnan, Deputy Assessor, Assessing DIN zsion NSB Charles Brower, Director, Dept. of Wildlife hlanauement, NSB Pauline Bowersft,.eonard Lampe. Nurgsur Village ( NSB Harry Bader, AkLNK, Fairbanks M OH/Dennis +.;uauh, Ak0F4 Faurbanks .,u r.t, St/u..,, t.1SDl /F& Ws, F.u,book • SENT BY: DIV OF GOV COORDINATIOt ; 272 3920; OCT -1 , 1:40PM; PAGE 25130 7 •, letter ca Mark I\lalur NSF 03 'Jranrie HJrI. i1o, UST ) . N1.iFS. Anchorage • r_,I uii F.ir.iy .4 ki)t11f'U(.,C, Juneau l :aye f.lu_I�h r, Ahtail1B/i)CiC. Anchorage Jeff n•)at h AI:UFC, Fairbanks Tetry C:irpermer /Jay Farp'Jim Wolfe. HS Army COE N111 Terobe.ri., PreiJzn1, htupi l Community of the Arctic Slope Jac ]b .slants, President. Arctic Slain Regional r"nrporalion Anih,.>n`, FJ∎ \rrdorn, P i csi.i iit, LJ:peayvik Jnupwl Cnrporatton Isaac Mul,apiiak, President Kuukpik Villag Corporation E.Jith k >rdcr.rtru,ie. Mayor, L' by Barrow Pcre: ti.lirve Village al Thomas tlruwer 111, f PA Program Manager Name Village of 13arruw Fh Nu1.rf>rGrl,, Mayor, i'uy of NuirIsur )..h;. 1;z;;; .,i. `;t Ptpr. i'o,Irdini>h>rs Office/ IPO. S.CU.a Leonard 1 anye. Sr , N'I' ' Chairman. man. Nall e 'village of Nurgsut Arctic Ali i Alau.rgcr'. USIA/DUO n J11: A1.1.11`1K(L):)&t - >. Anchorage cr 1. ea%,ii ( bin t,)u iicr U:4ugi ahnr.ru_al t >fnn�lt�ner r'harir6 Nopsun, r:'rbrn Oikner Charlie S,ul.er>;A, C'abrn Clwncr Noah Isla, Nair% Allotment Holder /Cabin Owner Mildred Leaviil, C/O Debrah Nayakik, Cabin Owner Lawrence Ahmaoeali, Cabin Owner Thca Fine Bodfish, Cabin Owner Harry Kdleal,, Mauve Alloimcni liuldrr /Cabin Owner Warren Maiumeak, Native Allotment Holder Wyman Panrgeo. C/O Janice Richards, Natl\e Allotment Holder files Ng03- U42 /RO /sa/ja • l SENT BY: DIV OF GOV C00RDINATIO. ; 272 3829; OCT-1. 1:40PM; PAGE 26/30 d Q , ' ' . ,1 .. .; , -' Nr) Rtrt SLOPE ©oaou ch Land Man. d ement Regulations DEPARTPncrlT 1, p� ='` ,1 - Permit Application Pt: IttntrrING „Zi/ i ric Dlyfs. on 7 : 3 • � p3 6L1 ; s P 20H2 2 APPLICANT Phillips Alaska, Inc. DATE: Se•iember 10, 2002 �. ;, t - r . ADI'HESS: P.O. Box 1003611 S fA]E ID Not applicable , _• A ,zchorabc, Alaska 99516 -0360 PHONE: '107- 265.6I36 INM1t in- Px, Litt '1 L viIAC. rl'ERScn+: mark Majtr NAME: RE AIRSIRIPS, APixyla,I E ()RATION N/A I u , r A 11011: See attached map l,ir,rrtZE1) FIELI N ANTE OR & l'AU Lu A'11uN: ZONING X CONSERVATION DIS•1RiCf VILLAGE DISTRICT Di JRIC:T: RESOURCE DEVELOPMENT DISTRICT TRANSPORTATION CORR ID DISTRICT PROPOSED START -13P DATE: +/- 11/15/02 COMPLEflON DATE: +1 6/1 /04 PROPOSED DEVELOPMENT: Phillips Alaska, Inc, proposes to construct up to 2 ice airstrips on frozen tundra to provide for access . to the Puviaq exploration locations in the NPR -A. — PURPOSE OF DEVELOPMENT: To provide material and equipment transport, emergency access, and crew change -outs at Puviaq cx loration sites in the NPR - FILL/DREDCE 0 Yes [8,1No Acreage Involved: Material Source: ., OIL & GAS WELLS Yes X No No. New Surface Boles: TEMPORARY WATER USE Yes ❑ No Sources: Permitted lakes Access: Rolligons, water trucks Maximum Withdrawal: 10,22 MM gallons Purpose: Construction and maintenance of ice airstrip a OFF ROAD 'PRA VEL J Yes El No Period of Travel: Winters of 1 1/15/02 •- 6 /1 /04I Equipment: Rolligons, aircraft (Otter & Hercules or Access to Site: Rolligon trails from Kuparuk DS 2P or 3H & similar) Camp Lonely & Barrow or ice road from Barrow; airstrip (after Cnnslrltr.Iinn) FUEL/HAZARDOUS TYPE AMOUNT HANDLING MATERIAL STORAGE: X Yes No Diesel for small generator Less than 1,000 gallons Stored in tank in for airstrip lighting and secondary . 1�hls in vicinity containment _ )L11) WASTE Yes X No 'Treatment: MINJNG Yes X No Habitat: SNow REMOVAL X Yes No • SENT SY: DIV OF GOV C00RDINATIO� ; 272 3829; OCT -1 2 1 :40PM; PAGE 27/30 • Allt ntIssN)hs ❑ 1''es ❑ No Amman: •'350 Ions /year of levolat,.l Type: Vchit:I , aircraft engines, pollutants _6cncIutar ,;l)t$E/V WTI AVON Yes ❑ No Amount: Varies Type; Vehicle, aitrraft engines, gclleratnr SENSJJ1YE FJABIT}r FL.00nPl.AIN SHORELINE 1N1 01.1 Ln: Yes* ❑ Nn _ * : Portions of the proposed ice airstrips may he located in areas considered as "SenmttiN c Area ConsidLttion" by fL1v1 .A 1 1 \CH TO I IIIS APPLICATION THE FOLLOWING: • GENERAL VI1 MAP SPECIFIC LL,+'.a rum MAP, Iltir'LIII)■,1 NEARBY E7►I,ST. ;(s1r; DEVELOPMENT AND N 4,TUtIAL FE CI IVIES. -- DESIGN PLANS IYLOT PLAN), ELEVATIONS, CROSS SECTIONS, PROFILES, AS APPROPRIATE. - SUPPLEMENTAL INFolRMATION, AERIAL PHOTOGRAPHS, STUDIES, F•rc... (AS NEEDED) Sl•_NU TO: NORTH H SLOPE BOROUGH, LAN» MAr AOF7►t1 NT ADMINISTRATOR, P.O. Box 69, HARROW, ALASKA 99723 PHONE: 1907) 852 -0320 TO1.1. FREE (IN- STATE): 1804) 4713 -6606 ExT. 320 I HEREBY CERTIFY THAT TIIE FOREGOING IS TRUE AND CORRECT TO THE BEST OF MV KNOWLEDGE. Se • tember 10, 7002 Authorized Signature Date Mark Ma Sr, Environmental Coordinator Name Title FEE PAID; ❑ SPECIAL PLANNING COMMISSION MEETING... $12,080.00 O DEVELOPMENT PERMIT... $2,000.00 AND 5500.00 PER WELL © ADMINISTRATIVE APPROVALS... 51,500.00 ❑ CONDITIONAL DEVELOPMENT PERMITS... $3,000.00 ■ REZONING REQUESTS /ZONING MAPS AMENDMENTS... $10 000.00 DECISION: ADMINISTRATIVELY APPROVED; This is a minor amendment to a development permit or is a use of land listed under administrative approvals for this zoning district. REZONING APPROVE,[];, Thia proposed development substantially complies with the master flan, and a use permit is issued, conditioned on compliance with all relevant Master Plan conditions, lease stipulations, and provisions of slate and federal law and permits served thereunder. DIsYELOP141 NT PERMIT APPROVED: The proposed development meets all applicable mandatory Policies, represents the Developer's bef efforts to implement all relevant best efforts and minimization policies, and as long as any condition set forth in the accompanying letter are complied with, will represent a net public benefit. (See accompanying letter). CON.)ITIOJVL IIEVE4OP111ENT PERMIT APPROVED: This is a use of land that is listed as a conditional development for this zoning district or has been elevated by the Land Management Administrator to the Planning Commission. PERMIT 1)1?NlED: (See accompanying letter), (,and Management Administrator Date f you wish to appeal this decision, you must submit written notice to the secretary of the Planning Commission prior to the neat 'egularly scheduled meeting, stating the policy or politics in question and the reason you believe the decision is incorrect. • SENT BY: DIV OF GOV C00RDINATIO ; 272 3829; OCT -1 1:40PM; PAGE 28/30 ?S PHILLIP,J Alaska, Inc. A Subsidiary of PNILL tPS PETROL E UM COMPANY P. 0 BOX 10035n • A1'ICHORAGE, ALASKA 99510.0360 Tpleplhorit 607.265 - 613e Facsimile 907.765 -1608 • ' p 20C1 1Erveci Rr Mark A. Major t S© Plann . f Sr. Environmental Coorairraloi v 1 n CF Department f le cz Set) tenter 10, 2002 Mr. Sheldon Adams Deputy Director North Slope Borough (NS13) Planning Department P. O. Box 69 Barrow, AK 99723 Re: Development Permit Application NPR -A Puviaq Exploration,Program Ice Airstrips Dear Mr. Adams: Phillips Alaska, Inc. (PAT) hereby submits a Development Permit application for ice airstrip construction and use in support of PAI's Puviaq NPR -A exploration drilling activities. Enclosed with this permit application is PAI's check in payment of the $2,000 filing fee_ Your review and approval of this application would be greatly appreciated. The ice airstrip will be constructed on the tundra as shown on the attached map. Although two proposed airstrip locations are shown, at this time, PAI plans on utilizing only one of these locations. Enclosed ftu assistance in reviewing this application are the following documents: Coastal Project Questionnaire Plan of Operations /Operational Overview, Including Polar Bear/Personnel Encounter Plan General Waterway[Waterbody Application (for Title 16 Fish Habitat Permit) ELM Application for Permit to Drill — Surface Use Program Letter to BLM Requesting Right -of -Way for Ice Road/Ro]ligon Trails Application to CQE for Oversumr Bring of a Drill Rig on an Insulated Ice Pad Application to ADNR for Land Use Permit, including Environmental Risk Questionnaire Request for Coverage under ADEC Exploration Core Air Quality Construction Permit Ph.11.n. Al.., \• i.,- ,. a! „W A:nra nt Phihr. Onlrwb..... Cn.nw.nu SENT BY: DIV OF GOV COORDINATIO4 ; 272 3029; OCT -16 1:41PM; PAGE 29130 9- 10-()2 NPRA NSI3 Ice Airstrips Letter • Page 2 of 3 Letter to AD1"(' Requesting Authorization for Temporary Storage of Drilling Waste Letter to IJSFWS Requesting Leiter of Authorization for Incidental 'fake of Polar Bear Applications for North Slope Boron h DeN Permits Application for AL)NR Temporary Water Use Pen-nit Letter to LISEPA Providing Plans for Nl'U1 S Discharges Request for Amendments-ADE(' North Slope Exploration Contingency Plan C'crrificatcs of Financial Responsibility IT° Follow) if you have any questions, or require additional information, please contact Mike Stahl tphonc: 263 - 4766; e- mail; mstahlAa ooco.com) or me {phone: 265 -6136; e-mail mmajor@ppco_cotn) at your earliest convenience. Thank you. Sincerely, Mark Major Sr. Environmental Coordinator Attachments cc; with attachments • Jim Baumgartner, Alaska Dept. of Environmental Conservation — Juneau Harry Bader, Alaska Department of Natural Reources - Fairbanks Larry Bright, U.S. Fish and Wildlife Service •— Fairbanks Peter Ditton, Bureau of Land Management — Anchorage Anthony Edwardson, Ukpeagvik Inupiat Corporation - Barrow Mike Holley, U.S. Array Corps of Engineers - Elmendorf AFB, Anchorage Teresa lmm, Arctic Slope Regional Corporation — Anchorage Kaye Laughlin, Alaska Division of Governmental Coordination -- Anchorage Lioy! Leavitt, Native Village of Barrow - Barrow Tom Lohman, North Slope Borough - Anchorage Don Meares, Bureau of Land Management — Fairbanks • Rosa Meehan, U.S. Fish and Wildlife Service — Anchorage Lydia Miner, Alaska Department of Environmental Conservation — Anchorage George Oleinaun, Ukpeagvik Inupiut Corporation - Barrow Alvin Ott, Alaska Department of Fish and Game - Fairbanks Ted Rockwell, Environmental Protection Agency - Anchorage Steve Schmitz, Alaska Department of Natural Resources — Anchorage Leslie Simmons, Alaska Dept. of Environmental Conservation. — Anchorage Bill Tegoseak, lnupiat Community of the Arctic Slope - Barrow Edith Vordesirasse, City of Barrow - Barrow Kellie Westphal, Alaska Department of Natural Resources - Anchorage • SENT BY: DIV OF GOV COORDINATION ; 272 3829; OCT -10 1:41PM; PAGE 30/30 , I • .. . . " - ? j —.ter- � : i ,,, I I •• 1 - - . I -- ` `�� � • • ii L 't I . { 1 r +�" + _ I . '� : I ; -1 i''.: , j : _ .. . i• I .. _ y.' � r l 1 • 1. -,,,� i ti i-' / + --: • + • " t �. — • 1 i l 4 • • , -r 1f><$TI�IP r _ r + ° `} % C . U` .. 1 I J' ! 1- V A • � ' { I t �: 1-....: I 417.. 7 1 - - . ` — . 1 i I +rigid I t ' ' P. ,� _' f c 0 l . _ , _I { - ,' rt .. T s - • ? , �i -- ; _'' 0 I : Vi�l , I ) 1 4. „pi 1 { - _ " 3E" :. 3) • - • '� ;7., •: ... + r' . . r. pa 1 ,{.• i + t -' •;. f =��.' _ 't i RQU ; a t . 4't i ; # .. - 1 ' + e • `_.;_}.i - (aili Aou i , i " ... 4.• ° . j-!, • . ; A i • '__=,°,•,F /i + i a . i � n. 1 ,TV�A� s __:� "► ' y �� l '° i cre 14111-- i k , '•. �. -'�'I ' , _ , • ��„ - i - . .3 Itt ~ � • i 1 "' s . u � �7 c� " , ~ - 1 � — + c { i � y, '� -At r � ';,ii 4 ' a 1 21 f • • � .. J _ 1 , 1 ( 4 . :� 1 - • i. i' � -.` 1, w F i If';. • I , ...? — , • . r_ e , -- =a.— + .,- ".- -' 1 . .. • , ` ' I ;j — • . i ! ' ! " _- j .- . — 4� . ' ; f_ '- �- + -771.------4" = ; t � , g! 3 Z' .I .4-'-' . us? - , ; . i I :; ~ I j t --- s .l • _ �: i t � •II { r ' I -�'I F. I► -- .' . 1.1., � _ � ',+ I /'. i .' U, -1 / -1 „ . I 1 ▪ 1 - S '� •,.+ • )r , a 0: - a '. .. i t' . i',• • • r r Y — { ` ! • : 7 1 _ - ; J _ f l' i+ 1. ) I tl , I 7 a �.s.� _,- ! r ' { ` 3 � 1t • at. Or if iff HI Lp' Al SY Of a .. • ' 1 f. . • ' 1 4 - _ -...:- f ._ _. i. ' , - z s i r: - PHILLIPS Alaska, Inc. Q I �� • ' �',• - t I - �� A 4' A 1 u.Iy I.IPHO1 fl 01I7-OI FIN rammin (- _ i." 1.4 I 4 IV 11 . , . , 1 e z Puvia 1 & 2 4-` : "'mitE Potential lee Airs #rip o- ,, .. a ; z , 4 t' ' -6 ion Ma • - --7---------/----5:', L oc 1 p _ r� i FILOf4€ ( e, 4 ..... +qIa. a .uCatinn Map 1 . , ;1 9..7-02 co-432401M S. K. ALLSUP -DRAKE 1 01 1 PHILLIPS PETROLEUM COMPANY 711 ANCHORAGE GST. CHORAGE AK 99501 DATE P�, hn :792-0(.2 AN "q /3yy (y- ^� / � p}� , � �" PAY TO THE 5.r ^ C ' ` a.-� 1 /�c&c $ ORDER OF ( .. tratLARS W E CHASE Chase W h9e MaClay nhattan D Bank D I. N ewark, USA. DE N.A. 79711 Valid Up To 5000 Dollars 290 ,. • MEMO P V V r AO O I. ! _ , : 03L LOO L441:2L80000 4 27 25711° 10 L L LINNERSAL R ECE Q DEC 17 2002 • aska pil & Gas Cons. GommisSion - Anchorage • 111 TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME �� CA cv PTD# C� CHECK WHAT ADD -ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new welibore segment of LATERAL existing well Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60 -69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/10/02 C\jody \templates Eja( --ta))//Y7/r e/,c ct_c_Z-44-14LryL.4--C aus COMPANY ConocoPh WELL NAME Puviaq #1 PROGRAM Exploratory (EXP) X Development (DEV)Redriil Service (SER) ., ... LD & POOL 000000 - Exploratory Initial Class/Type EXP / 1 -OIL. GEOL AREA 890 UNIT No. NA ON /OFF SHORE On )MINISTRATION 1. Permit fee attached Yes 2. Lease number appropriate Yes M081854 3. Unique well name and number Yes 4. Well located in a defined pool . . . No NPRA exploratory well 5. Well located proper distance from drilling unit boundary . . Yes 6. Well located proper distance from other wells Yes Nearest wells are 15 miles to the NNW (S. Simpson #1), 15 miles to the S (Ikpikpuk #1), and 15 miles to the NE (Drew Pt #1). APPR DATE 7. Sufficient acreage available in drilling unit Yes 8. if deviated, is wefbore plat included NA Vertical well SFD 12/18/2002 9. Operator only affected party Yes Offset leases M081851 to S, M081849 to SE, and AA081852 to E, have same ownership. BLM owns surface & subsurface mineral rights. 10. Operator has appropriate bond in force Yes 59 -52 -180 11. Permit can be issued without conservation order . Yes 12. Permit can be issued without administrative approval Yes 13. Can permit be approved before 15-day wait Yes (For Service Well Only) 14. Well located within area and strata authorized by Injection Order # NA Not Applicable (For Service Well Only) 15. At wells within 1/4 mile area of review identified NA Not Applicable (For Service Well Only) 16. Pre - produced injector: duration of pre - production less than 3 months NA Not Applicable 17. ACMP Finding of Consistency has been issued for this project ......... ...................... Yes DGC concluded Puviaq #1 Exploration Project is consistent with the ACMP statewide standards & North Slope Borough policies on 12- 02-02. ENGINEERING 18. Conductor string provided Yes 19. Surface casing protects all known USDWs Yes No water information supplied. Conoco/PPCo plans to run necessary togs in this wet. TEM "'Yes answer by SFD. See additional notes, below. 20. CMT vol adequate to circulate on conductor & surf csg Yes 21. CMT vol adequate to tie-in long string to surf csg No 22. CMT will cover all known productive horizons Yes 23. Casing designs adequate for C, T, B & permafrost Yes 24. Adequate tankage or reserve pit No reserve pit planned. Rig has been used for other exploration wells. 25. If a re- drill, has a 10 -403 for abandonment been approved . NA 26. Adequate wetlbore separation proposed Yes Nearest well is 15 miles away. 27. If diverter required, does it meet regulations Yes 28. Drilling fluid program schematic & equip list adequate Yes APPR DATE 29. BOPEs, do they meet regulation Yes TEM 12/23/2002 30. BOPE press rating appropriate; test to 5000 psig .................... MASP estimated at 3200 psi. Normal PPCo practice is to test to 5000 psi. 31. Choke manifold complies w /APi RP -53 (May 84) Yes 32. Work will occur without operation shutdown Yes 33. Is presence of H2S gas probable . . No See 35. (For Service Well Only) 34. Mechanical condition of wells within AOR verified .............. ............................... NA GEOLOGY 35. Permit can be issued w/o hydrogen sulfide measures Yes H2S not expected, but detectors will be used & mitigation strategy /equipment are listed in Drilling Hazards Summary to be posted in doghouse. 36. Data presented on potential overpressure zones Yes Normal pressure gradient expected based on analysis of 3D seismic data and offset wet drilling records. APPR DATE 37. Seismic analysis of shallow gas zones Yes None indicated based on analysis of 3D seismic data. Hydrates may be encountered - mitigation strategy noted in Drilling Hazards Summary, 38. Seabed condition survey (if off- shore) . . NA Not Applicable SFD 12/18/2002 39. Contact name /phone for weekly progress reports [exploratory only] ..................... Yes Tom Brassfietd, Senior Drilling Engineer, 265 -6377. GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: Comments /instructions Approval letter must contain standard text concerning AOGCC requirements for well cuttings, samples, and weekly reports. Well will be mudlogged from conductor to TD " In Puviaq #1, the expected permafrost base is 1000' MDJTVD, and 13 -3/8" surface casing will be set at 1300' MDJTVD and cemented to surface. As proposed, surface casing progra RPC: TEM: JDH: COT: will protect permafrost and any aquifers within 300 feet of the base of permafrost. Annular disposal operations in the shallow sand section between 1300' MD and 2500' MD will b= contingent upon analysis of shallow well togs aquired in Puviaq #1 as well as meeting all other criteria in 20 AAC 25.080. Operator's calculations in offset wells suggest that all aquife SFD: SFD WGA: MJW: DTS. t0 1 / j 71 below base permafrost exceed 10,000 ppm TDS, and therefore fresh water aquifers win not be present at the Puviaq #1 location. However, nearest offset wells are all 15 miles away MLB: U � 404/0 > Calculated TDS values in these wells may not be representative of shallow subsurface conditions at Puvaiq #1. SFD - -- --- .................. ..... _........ J • . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ac.) a.- A ` f • Conoco Phillips Alaska Inc. Puviaq #1 Northwest N. P. R.A., Alaska Final Well Report April 08, 2003 • Craig Silva — Sr. Logging Geologist Tim Smith — Sr. Logging Geologist John Morris — Sr. Logging Geologist RESTRICTED CONFIDENTIAL ConocoPfiiiips Alaska, Inc. El EPOCH • CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • TABLE OF CONTENTS WELL RESUME 3 DISCUSSION OF PROCEDURES 5 LITHOLOGY AND COMMENTS 13 SURVEY INFORMATION 27 DAILY MUD PROPERTIES 29 • • El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • WELL RESUME Company: Conoco Phillips Alaska Inc. Well: Puviaq #1 Field: Exploration Region: National Petroleum Reserve Alaska Location: Sec 35 T 16 N R 10 W UM Coordinates: 444' FWL 1713' FNL Elevation: 57.4' RKB 28.2' Ice Pad Level 26' BPMSL County, State: North Slope Borough, Alaska API Index: 50 — 279 — 20008 - 00 Spud Date: March 2, 2003 p , Total Depth: 7900' MD 7899.85' TVD April 08, 2003 Logged Interval: Full Logging 35' to 7900' Contractor: Nabors Alaska Drilling Company Representatives: Donnie Lutrick, Ray Springer, Granville Rizek • El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • Rig/Type: Nabors #16E / Topdrive Epoch Logging Unit: #12 Epoch Personnel: Craig Silva Tim Smith, John Morris Mindaugas Kuzminskas Randy Unger, Charles Isbon Company Geologists: Greg Wilson, Dick Garrard Casing Data: Conductor @ 112' 13 3/8 "" casing @ 1423' 9 5/8" casing @ 3167' Hole size: 16" from 112' to 1430' 12 ' /a" from 1430' t0 3175' 8 1/2" from 3175' to 7900' Drilling Fluids Company: Baroid Mud Type: EZ -MUD (PHPA Clayseal, 3% KCI) to 1430' EZ -MUD (PHPA Clayseal, 6% KCI) to 7900' MWD Company: Sperry-Sun Wireline Logging: Schlumberger I El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 DISCUSSION OF PROCEDURES The objectives and results of Puviaq #1 is held in confidence by a minimum of CPAI and other "need to know" service personnel. Very few individuals have access to any or all of the data and specific information, gained by drilling, logging and testing this well, that enable a person to appraise its oil and gas potential. This remote wildcat exploration well provided the possibility of new gas and oil discoveries. During the drilling and logging, all personnel were alert to the unexpected, and each major interval was anticipated to be problematic, as well as potentially "good ". Conoco Phillips commenced augering to install the conductor on March 2, 2003 with Nabors Alaska Rig #16E. The duration of the drilling was longer than anticipated due to a multitude of minor problems and incidents which can be reviewed partially in the Rig Activitities of this report, and several other reports and files assembled for CPAI. There were no outstanding major problems, and Total Depth was reached on April 08, 2003. Epoch Well Services provided RIGWATCH 2000Tm Drilling Monitoring services and DMLTM Mudlogging Service. Hydrogen flame ionization (FID) Total Gas and (FID) Gas Chromatograph detectors were • used to detect and analyze formation gases. All mud gas was continuously extracted to the logging unit through an optimally positioned air - driven QGMTM (Quantitative Gas Measurement) gas trap and. The gas system was tested and calibrated on a regular basis. Cuttings and Gas Bag samples were collected as per the Conoco Phillips' sampling program. • El EP CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 S DAILY ACTIVITY SUMMARY 3/2/2003 Run steam in cellar. Melt ice to get 5.5' from pad level. Chip ice. Auger 30" hole for conductor. Auger 24' hole of hole from pad level (to 54'KB). Shovel out excess dirt in cellar. Back in and out of the hole with the auger to keep it clean. Auger from 24'PL to 33'PL (63'KB). Shovel excess dirt in cellar. Back in and out of the hole with the auger to keep it clean. Auger to 34'PL (64'KB) at report time and continue to auger ahead. 3/3/2003 Auger from 34'PL (64'KB) to 83'PL (113'KB). Shovel excess dirt in hole. Auger out fill dirt until hole is clean. Hold PJSM for laying down Auger and BHA with Topdrive. Cover hole (with 3x12's and 1" plywood). Remove snow bucket. Lay down auger and BHA. Hook up and rig up slings. Work on Laydown machine. Pick up 20" conductor. Cut off H -beam supporting the conductor at the rotary table. Wrap hot metal with insulation and cool down. 3/4/2003 Recheck depth of cellar box. Measure RKB. Land conductor. Line up and plumb conductor pipe. Dump bar in and around pipe. Chip ice out in cellar box around the top of the conductor. (4'x4'). Make up 2" conduit and RIH. Rig up Dowell. Hold PJSM with all involved parties. Pump cement (315 sacks). Wait on cement. Hang stabbing board. Install guard on rotary RPM indicator. Install casing snub line anchor. Hook up pressure sensors. Hold PJSM on general procedures of remaining rig up. Troubleshoot electrical problem with drawworks. Found air to electric switch not hooked up. Hook up control lines rig floor. Cut 20" conductor and set base plate on the weldout. Cut two 3" holes in the conductor to weld in two annulus nipples. Set landing ring weldout per procedure. Hang cement standpipe in derrick. Install rig floor mats. Continue hooking up sensor hoses on rig floor. Finish welding landing ring and wait for it to cool down. Hook up choke control hoses. Remove unnecessary • equipment from the cellar. Hang manual lifts. Hang offside driller air winch. Run hoist chain through floor to pick up flowline for installation. 3/5/2003 Pick up flowline and stab in pit room wall and hang off. Clean up cellar, scrap planks and pick up tools and gear. Hold PJSM. Prepare rig floor for picking up HWDP and drill pipe. Pick up and strap and stand back in derrick HWDP, jars and drill pipe. Hold PJSM for start of nipple up. Thaw out spool and start nipple up. Hold PJSM for nippling up diverter. Nipple up diverter for surface drilling. Make up annular end of flowline. Hookup flowshow. Make up casing fillup line. Install DS manual lift winch. Function test diverter element and knife valve. Hook up mud bucket hose to flow line. Make two diverter lines. 3/6/2003 Hold pre -tour safety meeting. Hook up last section of diverter line. Hook up fillup line and pressure bleed off lines. Fasten turnbuckles to Hydril. Air up flowline boot. Put hard line plug on kill line under rig floor. Hook up floor drains. Install ball valves on cement return lines. Test roll mud pumps #1 and #2. Hook up cement hose to gooseneck in derrick. Clean up cellar. Blow air through entire mud system. Clear rig floor. Fix rod oilers. Service mud manifold on rig floor. Hold pre -tour safety meeting. Change out small tugger line. Function trip tank pump from drillers console. Move turnbuckles from Hydril to bell nipple. Hook up safety line on stabbing board. Function diverter element (time to close is 24 seconds). Perform Koomey test (accumulator at 3000psi, manifold at 1700psi, and after closing at 1550psi took 21 seconds to drop to 200psi and then 1 minute 20 seconds for a total recharge with and average of 2300psi from the nitrogen bottles). Hook up casing fillup manifold. Hookup pump pressure to geolograph and choke panel. Hold PJSM. Pressure up mud system. There was leaking from a 4" valve, and also at the cyclinder #1 wear plate on mud pump #1. Break 5" cement head. • Remove pre - loaded pipe wiper load latch on wiper plug. Torque lift sub 10K. Change out paddle and seat on #1 mud pump 4" valve. E POCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 3/7/2003 Testing mud pumps and mud lines. Replace wear plate and gaskets in #1 pump. Install new liner and gasket in #1 pump. Replace kill line low torque valve. install repair kit in isolation valve on mud manifold. Fix leak in 4" valve on #1 pump. Put gasket on screen for suction on #1 pump. Take on water while continuing to work on suction for #1 pump. Begin mixing mud. Hold pre -spud meeting. Pick up BHA (16" bit, motor, logging tools and crossover). Mix mud and work on rotary table. Test pumps #1 and #2. Work on #1 pump again, replacing liner gasket. Test pumps #1 and #2. Work on #1 pump again. 3/8/2003 Finish work on pump #1. Mix spud mud. Check isolation valves on #2 mud pump. Rebuild 3" Demco bleeder on rig floor. Check 3" Demco bleeder and circulate through flow line. Check #2 popoff and 2" bleeder on #2 mud pump to insure proper function. Circulate through flow line. Fill hole and circulate to shear polymers. Continue to mix polymers into the mud. Shut down pumps to clean suction screens. Work on flow paddle. Pump through bit to shear polymers. Break out and blow down Topdrive. Shear through bleeder. Hold pre -spud meeting. Perform diverter drill. Make connection. Drill 16" surface hole from 112' to 187' (at 427gpm, 5orpm, 600psi). Shut down to clean out auger. Drill surface hole from 187' to 195' (at 427gpm, 5orpm, 600psi). Shut down to clean 10 gallon spill and fix auger flight. Drill from 195' to 253' (report depth) and continue to drill ahead. 3/9/2003 Drill from 253' to 364'. CBU twice. POOH to mudmotor. Change angle on motor. Hold PJSM. Pick up nine 8" drill collars. Repair lay down machine. Pick up DC's. CBU. Drill from 364' to 496'. Circulate hole clean. Drill from 496' to 694'. Circulate hole clean. Drill from 694' to 807' (report depth) and continue to drill ahead. • 3/10/2003 Drill from 807' to 830'. Work on #2 mudpump. Drill from 830' to 907'. Temporary shutdown to put out brief fire at #4 generator. Pick up and circulate while switching to good generator. Drill from 907' to 1043'. Circulate slow. Clean shakers and auger. Load mud onto rollagons. Drill from 1043' to 1054'. Clean suction screens on both pumps (blocked off). Drill from 1054' to 1308'. CBU. Drill from 1308' to 1350'. CBU. Drill from 1350' to 1358'. CBU. Replace seal ring on union on stand pipe. Drill from 1358' to 1391'. CBU. (Continue to drill ahead.) 3/11/2003 Drill to 1430'. CBU. Pump around weighted sweep. POOH. Make up Hanger assembly and running tool to landing joint. Rig down GBR. Rig up casing stabbing board. Hang fall arrestors at beaver slide. Tie back block hanging line. RIH from 112' to 1430'. CBU (670gpm, 8orpm). POOH from 1430' to 112'. Drop 2.6 drift down pipe. Download MWD recorded data. Lay down BHA. Rig up casing equipment. 3/12/2003 Finish rigging up GBR casing equipment. Hold PJSM with company representative. Bakerlok and makeup shoe and float collar joints. Check float. Run 13 3/8" casing (68 lb/ft), filling every 5 joints. Make up hanger, landing joint and circulating swedge. Land casing. Rig down GBR. Circulate (at 7ospm, 250gpm, 180psi). Back out landing joint. Cut hole for flow line. Make up landing joint and cut it off below the table. Lay down GBR tools and casing pup. Make up stinger and centralizer. RIH to 1283'. Pick up and RIH with two additional joints. Make up cementing head. Tag in with adaptor and engage receiver in the float equipment. Circulate and condition the mud. Test lines. Cement as per CPAI (60bbis mud push, 343bbts lead slurry at 10.7ppg, 46bbls tail slurry at 15.7ppg). Drop plug. Pump 14bbis fresh water. Rig down and blow down cementing equipment. POOH. Lay down landing 4110 joint. Nipple up surface stack. El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • 3/13/2003 Nipple down diverter. Nipple up stack FMC wellhead casing head and tubing head and test to 1000psi (metal to metal seal for 10 minutes). Nipple up BOPE. 3/14/2003 Nipple up BOPE. Set stack on wellhead. Install HCR choke and kill valves. Hook up flow line. Install Koomey lines. Install 5" rams and blind rams. 3/15/2003 Tighten blind ram doors. Open top doors and install variable ram blocks. Close doors. Install turnbuckles. Pull stack over to center. Clean up and install kill line target tee. Install kill line and choke line to stack. Tighten turnbuckles. Clean working area. Rig up to test BOPs. Thaw out ice plug in stand pipe. Function test BOPs. Fill choke manifold, kill line and BOPs. 3/16/2003 Hold PJSM on testing BOPs. Pull mechanism from kill line valve. Tighten flange on choke manifold. Tighten lock down packing nuts on casing spool. Service choke line HCR valve. Start tests on BOPs. Tighten gray locks on stack. Observe leaks from HCR valve. Drain stack. Blow down choke and kill lines. Hold PJSM on procedures for making down the choke and HCR. Disassemble choke line and HCR. Tighten gray locks on BOP stack. RIH with test plug. Fill stack and check body of BOPs. Attempt to test BOPs. Gray locks still leaking. Hold PJSM. Nipple down BOPs (to the double gate) to check API ring. 3/17/2003 Break gray lock under double gate and remove. Remove turnbuckles and lift stack from mud cross. • Inspect ring grooves. Clean and replace API ring. Hold PJSM. Set stack back on mud cross and install a new graylock. Tighten and install flowline and turnbuckles. Run test plug. Fill stack. Hold PJSM. Perform body test. Tighten FMC gland nuts on lower lockdowns. Tighten FMC wellhead clamp. Fill choke manifold. Test BOPE. (Test choke manifold valves 1 -19, upper ram variables, manual choke and kill, HCR choke and kill, dart valve and TIW, upper and lower IBOP [250psi Low / 5000psi High], test Bag [250psi Low / 3500psi High], test Koomey). Rig down testing equipment. Set wear ring. 3/18/2003 Back out landing tool from wear ring and lay down. Clear rig floor. Prepare to pick up drill pipe. Pick up 75 joints of drill pipe and stand back in derrick. Pick up rotary hose and connect to Topdrive. Hold PJSM. Start picking up BHA. Upload programming to MWD -LWD. Load sources. RIH with collars and HWDP. Circulate and condition mud. Rig up and test casing. Blow down. Tag float collar at 1337'. Drill out cement and tag shoe at 1423'. Drill out shoe. Drill 5' of new hole. CBU, circulate and condition. Rig up lines and valves for doing a Formation Integrity Test with the injection pump. Perform Formation Integrity Test, pumping to target pressures with the injection pump. Rig down and blowdown testing equipment. Run to bottom and drill from 1435' to 1450'. CBU. Start changing over mud to 9.6ppg while drilling and circulating. Rig up for using injection pump again for second Formation Integrity Test. 3/19/2003 Perform Formation Integrity Test. Bleed off and check volume. Blow down choke line and cement line. Lay down test tools. Latch on to stand set back for testing and screw in. Go to bottom at 1450'. Drill from 1450' to 1756'. Observe auger packing up with clay and fluid. Pick up and slow circulate while cleaning auger, and areas around dewater tank and pump. Drill from 1756' to 2232'. Circulate hole clean. Do 9 stand wiper trip from 2232' to 1396'. Service Topdrive. Run back to bottom. CBU. Observe spill outside on pad. Continue to circulate and clean hole. Commence clean up operations on spill. El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 3/20/2003 Circulate while all rig hands and rolligon driver clean up 50 gallon spill on pad. Get slow pump rate. Make connection and start drilling. Drill from 2232' to 2280'. Bit balling up while drilling. Work pipe and unball bit, but observe Toss of pump pressure (200psi). Circulate with #1 pump while repairing pop -off on #2 pump. Continue drilling from 2280' to 2600' (picking up and cycling pumps for MWD as needed). Change shaker screens. Drill from 2600' to 2996'. Observe leak in stand pipe. Pick up and stop circulating. Set stand back. Pull two more stands to inspect leak area. 3/21/2003 Hold PTSM. At 2797', circulate through cement line. Work pipe. Remove section of mud line. Pump up samples and fill trip tank. POOH to shoe from 2797'. Pump through tight spot at 2420'. Clean off rig floor. Install floor safety valve. Service rig. Hold PJSM. Install mud line section, circulate air out the line and test to 3500psi. Blow mud line down. RIH to 2890'. CBU. Condition mud. Wash from 2890' to bottom at 2996'. Hold PTSM. Drill from 2996' to 3093'. Pull off bottom and circulate while waiting for Rolligon to back load waste mud. Hold PJSM. Pump 85bbls waste mud to Rolligon. Move fluid to injection pit. Tag bottom and drill from 3093' to 3135'. Circulate at a minimum rate while changing screens on the dewatering shakers. Tag bottom and drill from 3135' to 3175'. Circulate and condition hole. Blow down and POOH to 3035'. 3/22/2003 Continue 5 stand wiper trip. Break circulation. Circulate and condition mud and work pipe. Do flow check. Pump dry job. POOH (with no tight spots). Hold PJSM. Start laying down BHA. Remove sources. Download MWD -LWD recorded data. Continue laying down BHA (stabilizers, motor, subs and bit). Lay down stabilizers and subs out the side door. Clear rig floor. Pull wear ring and set test plug. Hold PTSM. Clear and clean out ice in the work area in the cellar. Hold PJSM. Change upper and lower pipe rams (9 5/8 "). Hang air winch on stabbing board and anti -fall. Remove Kelly hose from Topdrive. Install crossover and hook up 2" high pressure hose to gooseneck. Run air hose for casing elevators. Fill BOPs with water. Test door seals (at 250psi Lo / 3500psi Hi for 5 minutes each). Lay down test plug crossover and joint. Remove drilling elevators and bails. Pick up franks and fillup tool. Make up and install casing bails and elevators and slips. Hang power tongs and function test. Bring necessary equipment for job to rig floor. Hold PJSM. Make up float equipment. Run 9 5/8" casing (15 joints). 3/23/2003 Pick up and run in 9 5/8" casing to show at 1423'. Break circulation and condition mud. Pick up and run remaining casing (75 joint total). Make up landing joint. Break circulation. Circulate and condition mud, (Circulate casing bottoms up and receive 50 units of trip gas). Rig up to pump cement. Hold PJSM. Batch up. Pressure test lines. Pump 40bbls water. Drop plug. Pump cement as per Conocophillips. Pump 50bbls of mud push. Pump 45bbls cement. Drop second plug. Pump 3 bbls cement. Pump 7 bbls water. Chase plug with rig pump. Bump plug at 2597 strokes. Pressure up to 1200psi. Bleed off. Blowdown and rig down all casing tools and cementing tools. Drain stack. Hold PTSM. Finish laying down casing bails. Pick up bails and elevators. Pick up pack -off equipment. Run pack -off and land out. Run in lock downs. Test flange. Pick up test joint. Make up ported sub and test plug. Hold PJSM. Change bottom and top rams to 5 ". Remove check valve ball on kill line. Set test plug. Pull test plug and change to 13.5" OD test plug. Fill BOPs and with water. Check with choke. Hold PJSM. Pick up tools. Make up TIW and dart valve and ported sub. Test BOPs (choke manifold valves at 250psi Lo /5000psi Hi, Hydril at 250psi Lo /3500psi Hi [chart tests and hold for 5 minutes], dart valve at 250psi Lo, Koomey at 250psi Lo /3000psi accumulator /1550psi manifold after closing /200psi in 32 seconds, 3000psi 3 minutes 5 seconds). • E POCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • 3/24/2003 Continue testing BOPE. Check crown -o- matic. Pull test plug. Set wear ring. Test IBOP and lower manual valve on Topdrive. Drain and blow down kill and choke lines. Rig down testing equipment. Hold PJSM. Rig up for picking up drill pipe. Warm up skate. Pick up 90 joints of 5" drill pipe. RIH and then POOH with 30stands and stand back in derrick. Perform kick drill while tripping. Pick up 69 joints of 5" drill pipe. RIH with 23 stands. Observe significant scale in pipe while tripping in. Rig up and pump through pipe to remove scale. Hold PTSM. Check crown -o- matic. Function blind rams. Service Topdrive and change tong dies while pumping through drill pipe. POOH (SLM) 23 stands and stand back in derrick. Clean rig floor. Pick up slips, lift subs and stabilizers from catwalk to rig floor. Size slips and dog collar. Hold PJSM. Pick up BHA to first non - magnetic flex collar. Set motor to 0.62 degrees. Plug into LWD -MWD tools and set program. Prepare to load radioactive sources into neuton tool, hold a PJSM on the proper procedures, and load sources. Continue picking up BHA. Drift spiral drill collar with 2" OD after using steam to clean off the ice and snow. Turn elevators back to the normal position. Clear the rig floor and prepare to RIH with HWDP. Rig up to hang kelly hose. 3/25/2003 Finish rigging up Kelly hose. Pump through BHA. Blow down Kelly hose. RIH to 3058'. Kelly up and circulate. Stand back one stand. Rig up and test casing to 2500psi. Rig down and blow lines out. Kelly up and circulate. Tag float collar at 3070' and drill out. Drill cement. Tag top of shoe at 3165' and drill out. Drill 5' of new hole from 3175' to 3180'. Pick up and circulate hole clean. Stand back one stand. Rig up and perform FIT. Bleed off and blow down. Continue drilling from 3180' to 3195'. Circulate hole clean. Stand back one stand. Rig up and perform FIT. Bleed off and blow down. Hold PTSM. Check crown -o- matic. Function test top and bottom rams. Finish blowing down choke and kill lines. Clean rig floor. Drill ahead from 3195' to 3207'. Do a flow check. Drill from 3207' to 3360'. Circulate 1 1 /2 bottoms up. Perform PWD ECD Baseline test (at 600gpm, 120/100/80rpm [120rpm= 10.63/100rpm= 10.60 /80rpm= 10.56], at 550gpm • [120rpm= 10.5/100rpm= 10.48 /80rpm= 10.47] and at 500gpm [12Orpm= 10.4 /100rpm= 10.34 /80rpm= 10.36]). Survey at connection. Drill from 3360' to 3601'. Circulate bottoms up Get ECDs. Drill from 3601' to 3635' (report depth) and continue to drill ahead. 3/26/2003 Drill from 2546' to 3676'. Pick up and circulate while EPOCH gets Rigwatch system back on line. Continue drilling from 3676' to 3975'. Circulate hole clean. Drill from 3975' to 4911'. Circulate hole clean. Do wiper trip to shoe. Function hydril and top and bottom rams. RIH. Wash and ream last stand from 4020' to 4111'. Drill from 4111' to 4515' (report depth) and continue to drill ahead. 3/27/2003 Drill from 4515' to 4544'. Pick up and cycle pumps. Slide drill from 4544' to 4580'. Ream. Get slow pump rate and make a connection. Drill from 4580' to 5132'. Change suction screen on mud pump #2. Drill from 5132' to 5146'. Circulate hole clean. Clean solids out of trip tank (36" deep). Monitor well (static for 15 minutes). Pull one stand. Blow down. POOH from 5146' to 4111' on 10 stand wiper trip. Monitor well. Function Hydril and top and bottom rams. RIH. Wash and ream last stand to bottom. Circulate bottoms up (no fill). Make a connection and survey. Drill from 5146' to 5267'. 3/28/2003 Drill from 5267' to 5654'. Pick up and circulate and change out rod oiler hole on mud pump #1. Drill from 5654' to 5931'. Check flow. Drill from 5931' to 5965'. Check flow. Drill from 5965' to 5970'. Check flow. Drill from 5970'. To 5977'. Check flow. Drill from 5977' to 6080'. Circulate hole clean. Survey. Monitor well. POOH to 5056' on 10 stand wiper trip. Monitor well. Function test annular and top and bottom pipe rams. Service Topdrive. RIH. Wash and ream last stand to bottom. (No fill). Circulate bottoms up. Survey at the connection. Drill from 6080' to 6161' (report depth) and continue • drilling ahead. El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • 3/29/2003 Drill from 6161' to 6267'. Troubleshoot Topdrive problem. Monitor well. Pump dry job. POOH to shoe. Troubleshoot Topdrive problem. POOH. Pull out with HWDP and BHA. Hold PJSM on radioactive sources. Remove sources and lay down Sperry -Sun section of BHA. Hold PJSM before rigging down Topdrive. Rig down Topdrive to change out swive. Lay down bales and elevators. Remove pipe handle and torque arrestor. Break down and lay down upper and lower IBOP. 3/30/2003 Monitor hole with trip tank while working on Top drive. Finish breaking down and laying down upper and lower IBOP. Bleed off hydraulic pressure and remove cylinders and chains from blocks. Remove gooseneck and S -pipe. Unbolt stiff arms from swivel. Rig up pick up lines from blocks to swivel. Pull swivel from Topdrive and set in mouse hole. Rig up and put swivel in rotary table and break out quill pin. Lay down swivel. Pick up new swivel. Make up quill pin. Pull up swivel from rotary table and set in the mouse hole. Grind tong marks from quill shaft. Pick up swivel and stab into Topdrive. Hook up link swivel. Lay down the rig up slings. Latch swivel into the hook. Hook up cylinder assembly to Zink swivel and hook. Chain up link and tilt. Make up upper and lower IBOP. Install torque arrestors and pipe handler. Function test Topdrive. Set pressure on cylinder assembly. Install S -pipe. Change grabber dies. Check oil in Topdrive and swivel. Grease pick -up tools and put away. Hook up Kelly Hose. Pick up bails and elevator. 3/31/2003 Clear rig floor. Pick up bit and bit sub. Pick up BHA. Upload MWD -LWD programming. Hold PJSM on nuclear sources. Install sources. RIH to 1546'. Fill pipe and break circulation (at 175bpm, then increase to 350gpm, 800psi). Do shallow pulse test of Sperry tools. RIH to shoe. Fill pipe and circulate 2500 strokes (at 175bpm, then increase to 350gpm, 800psi). Work on IBOP. Hold PJSM. RIH to 4500'. Circulate and condition mud. RIH to 6238'. Tie in MWD -LWD log depth. Continue RIH to bottom. Drill from 6267' to 6307'. Shut down for overheating of #1 and #2 cat. Drill from 6307' to 6371'. Clean suction screens on both pumps. Change out shaker screen. Drill from 6371' to 6373'. Check surface lines, valves and equipment for leaks. Suction screens plugged again. Clean suction screens on both pumps. Drill from 6373' to 6397' (report depth) and continue to drill ahead. 4/01/2003 Drill from 6397' to 6576'. CBU. Drill from 6576' to 6710'. Service Topdrive and crown (add 4 gallons of oil to the swivel). Drill from 6710' to 6946' (report depth) and continue to drill ahead. 4/02/2003 Drill from 6946' to 6969'. Change washed out liner in #2 charge pump. Drill from 6969' to 7120'. CBU and circulate hole clean. Mix and pump dry job. Monitor well for 10 minutes. POOH to HWDP. Monitor well for 15 minutes. POOH to MWD -LWD tools. Clean rig floor. Turn elevators. Hold PJSM on radioactive sources. Remove sources. Pick up and break bit. Prepare for, pick up, and then lay down MWD -LWD tools (so Sperry -Sun could connect a lead to its tools and download the recorded data). Pick up lay down joint. Open annular valve. Install a second valve to the annular, then remove the check valve's internal elements on the kill line. Pull wear bushing. Set test plug. Fill BOPs with water. Hold PJSM (and read through full testing procedure). Test BOPE (Top rams and choke manifold to 250psi Lo / 5000psi Hi). • IA E POCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • 4/03/2003 Test BOPE (Test Choke HCR, Manual Choke, Manual Kill [250psi Lo /5000psi Hi], Annular Preventer [250psi Lo /3500psi Hi], Lower Pipe Ram [250psi Lo /5000psi Hi], install check valve, do Koomey test, pull test joint, test Blind Ram [250psi Lo /5000psi Hi]); Pull test plug; Install wear bushing. Lay down test joint. Rig up and test Topdrive IBOP, Lower Kelly Cock, TIW and dart valve [all to 250psi Lo /5000psi Hi]. Rig down test equipment and blow down. Change oil in swivel and service Topdrive. Pick up first stand of BHA. Uplink and program LWD -MWD tools. Hold PJSM on radioactive sources. Load sources. RIH with LWD -MWD tools. Continue RIH with DCs and HWDP. Break circulation and test LWD -MWD tools. Observe accidental back out of saver sub. Replace electronic torque measurement sensor cartridge. Turn and retorque up saver sub with torque wrench. RIH to shoe. Circulate and Test LWD -MWD tools. Blow down Topdrive. RIH to 6999'. Circulate out gas. Wash and ream to 7092'. Pull one stand and blow down. Repair o -ring wash out in the high pressure mud line off the #2 mud pump. Make connection and survey. Drill from 7120' to 7136'. Pick up and stop circulating. Repair leaking flowline sleeve. Drill from 7136' to 7140'. Cease drilling to clean suction screens on pumps. 4/04/2003 Drill from 7140' to 7147'. Clean suction screens to pumps. (Drill bigger holes in screens). Drill from 7147' to 7156'. CBU as per CPAI geologist. Do 5 stand wiper trip. CBU and circulate and condition hole. Monitor well. Pump dry job. POOH to shoe. Slip and cut drilling line. POOH. Lay down lower BHA. Hold PJSM on radioactive sources. Pull sources. Break bit and lay down MWD -LWD tools. Pick up lay down joint. Hold PJSM. Pick up core barrel and core bit. Attempt to drift HWDP but unable to proceed (rabbit could not slide through). RIH. 4/05/2003 RIH to core point, filling pipe every 2500'. CBU. Check flow. Space out pipe length. Core from 7156' to 7223'. CBU. Lay down space out joints. Pump dry job. POOH with Core #1. POOH to shoe at 30' /min. Monitor well at shoe. POOH to HWDP at 22' /min. Monitor well. POOH to outer core barrels at 15' /min. Lay down inner core barrels. Service Topdrive and drawworks while core is being processed. Pick up inner core barrels. Start RIH for Core #2. 4/06/2003 RIH with core barrel (Core #2) filling pipe every 2500'. Tag up at 7223'. CBU. Check flow. Space out pipe length. Core from 7223' to 7313'. CBU. Set back one stand. Lay down pup joints. Pump dry job. POOH from 7313' to 6351' at 30' per minute. Note that hole fill is coming up short. Detect well flowing slowly. RIH from 6351' to 7105'. CBU. Circulate and condition hole and build mud weight to 9.7ppg. 4/07/2003 POOH with Core #2 (at 30' /min to 2500', monitor well at shoe, at 22' /min from 2500' to 1000', monitor well at HWDP, at 15' /min from 1000' to surface). Hold PJSM. Lay down inner core barrels. Lay down outer core barrels and bit. Pick up BHA. Clear ice off derrick. Upload programming for MWD -LWD tools. Load nuclear sources. RIH with DCs. Service Topdrive. RIH to 7313' (filling pipe every 2500'). CBU. Start M.A.D. pass from 7313' to 7156'. 4/08/2003 Finish mad pass and RIH from 7151' to 7313'. Drill from 7313' to 7320'. Check flow. CBU. Drill from 7320' to 7900' (Total Depth). CBU. Do 10 stand wiper trip. CBU and circulate and conditon mud. POOH to top of Sperry-Sun LWD -MWD tools. Hold PJSM on nuclear sources, clear personnel from floor, pull up collar and remove sources. Break bit. Lay down MWD -LWD tools. Pick up lay down joint. Clear and clean rig floor. Rig up SWS to run wireline logs. Pick up wireline logging tools for first run. El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 LITHOLOGY AND COMMENTS NOTE DESCRIPTIONS FROM 30' TO 110' ARE OF THE SURFACE AUGER INTERVAL. SAND / SILTY SAND (30' -40') = (85 -95 %) Pale yellowish brown with strong light gray and light brownish gray secondary hues; well to very well sorted in very fine lower range; a significant fraction crosses over into coarse quartz rich silt; 1 -2% crosses to very fine upper, and spotty grains are fine lower; after thawing first appears clayey - silty, but with only very light washing to remove the brownish gray to dark brownish gray organic -rich clay has a silty - grainy appearance that is actually the very fine lower sand; note a very strong "outhouse" odor from gases breaking out of the fine particles of frozen decaying organic material in the clay - silt -sand; entirely disaggregated; easily disintegrated silt and soluble clay and ice are the supporting matrix; very silty quartz arenite to very silty lithic quartz arenite; estimate 85 -95% quartz, trace -5% feldspar, 5 -10% lithics; some of the quartz fraction is probably structureless silica (glass) grains; all grains are dominantly subangular to subrounded, and subdiscoidal to spherical; quartz is colorless to pale brown to pale gray to very pale orange and 85% translucent and 15% transparent; common grains with patchy or spotty yellowish orange or orange (limonite ?) iron oxide staining. Observed rare second mode of well rounded very coarse grains and granules of grayish black to black highly water - polished dense chert and light gray quartzite. Note that the flecks of organic matter initially appear black when the sample is first collected, but generally dries to a light grayish brown or pale brown to brown. Plus SILT and CLAY (5 -15 %) CLAY (40' -50') = (30 %) Two major variations: One variation is very organic looking, grayish black to brownish black, very soft, rapidly soluble, has a slimy to liquid consistency, good to moderate adhesiveness, very poor cohesivenss to none - cohesive, mostly forms blackish irregular but roughly globular masses within the other clay and silt and also generally has the "slickest" appearance of the current lithologies. The second • variation is siltier overall, very closely gradational to equally abundant clayey silt, light brownish gray to brownish gray to moderate yellowish brown, soft to very soft, moderately soluble, pasty to gelatinous consistency, good to moderate adhesiveness, poor cohesiveness, occurs pervasively and has a more distinctly clayey texture than the black organic clay. All of the clay contains abundant very fine sand grains, and abundantly is gradational to the sand /silty sand described above. Generally the blacker the color of the clay, the more intense the odor of decaying organic matter. SILT (40' -50') = (30 %) Pale to dark yellowish brown to light brownish gray; abundantly very sandy and gradational to a very silty sand, and also very clayey and gradational to the silty clay described above; soft; mixed silty - clayey to clayey texture; earthy lustre; massive structureless structureless habit, mushy to pasty consistency and contains abundant sand grains; note that clay and silt form the supporting matrix for all of the sand. SAND / SILTY SAND (40' -50') = (40 %) Continued same characteristics as sand described at 40'. Generally appears to have slightly more "reflectiveness" than sample above, indicating possible slight increase in feldspar. CLAY (50' -60') = (80 %) 90% of the total clay and 70% of the entire sample is the same grayish black to brownish black very organic looking clay as described above; note that the black organic clay itself is becoming siltier, but continues to be rapidly soluble; a "hard" washing would eliminate nearly the entire sample; a trace of the lighter colored very silty clay has a slight "chunkiness ". SILT /SILTSTONE (50' -60') = (15 %) Dominant color mode continues to be dark yellowish brown to light brownish gray, but note the appearance of a fraction that is medium gray to medium dark gray and also is slightly brittle. SAND (50' -60') = (5 %) Same characteristics as first described at 40'. Note continued well sorted in very • fine lower, but increasing trace to spotty grains from fine to very coarse. EPO II CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 CLAY (60' -70') = (95 %) Very organic to silty organic looking; grayish black to brownish black; very soft; • rapidly and easily soluble; slimy to liquid to gelatinous consistency; moderate adhesiveness, none cohesive to very poor cohesiveness; massive and structureless; rare structure if well compacted; note that the silt also is generally black in color; overall has a very slick appearance; continued very gradual increase in silt (a clay section with subtle fining upward ? ?), but at same time there is less of the lighter colored clay and silt. Plus SILT (5 %) and SAND (Trace). CLAY (70' -80') = (90 -95 %) Mostly same characteristics as above but there are some changes; overall the clay is becoming slightly less organic and slightly siltier (but still would be considered primarily organic); color lightness values are shifting upward, and most clay is now dark gray to medium dark gray; consistency thickens from gelatinous to pastey; moderate to good adhesiveness and moderate to good cohesiveness; there is an apparent very gradual increase in both silt and sand; slowly soluble: requires increased washing to reduce the clay volume. Plus SILT (Trace -5 %) and SAND (Trace -5 %). CLAY (80' -90' %) = (95 %) Same characteristics as above with minor differences; overall dark gray with spotty medium dark gray; very soft to soft; pasty to mushy consistency; moderate cohesion; moderate to high adhesion; moderately soluble; massive structureless returns; slight increase in silt with slight decrease in sand. Plus SILT (Trace >5 %) and SAND (Trace <5 %). CLAY (90'- 100'): (100 %) Medium dark gray to dark gray; soft; pasty to punky consistency; moderate cohesion; moderate adhesion; low to moderate solubility; massive structureless returns with no discernible structure; less silty and sandy as previous interval. Plus SILT (Slight trace). CLAY (100' - 110'): (100 %) As above with increasing organic content; dark gray to grayish black; pasty to punky consistency; moderate to high adhesion; moderate cohesion; low solubility; slight decreasing siltiness; massive structureless returns with no discernible structure. • CLAYSTONE (110' -220') = Light gray to to very Tight gray; soft to very soft, occasionally slightly firm; moderately to very cohesive; slightly to moderately adhesive; slightly soluble during washing; mushy to curdy consistency, occasionally pasty; massive structureless returns with rare subblocky fracture; no discernible structure; noncalcareous; note locally common medium gray to medium dark gray variation that looks distinctly more organic and has a more gelatinous consistency; clayey to mixed clayey -silty texure; darker organic blebs of clay have very abundant dark brown soft organic microflakes; sand is almost entirely absent. SILTSTONE/CLAYEY SILTSTONE (200' -300') = Mostly occurs as soft very silty patches in the clay; medium light gray, often with light brownish gray secondary hues, spotty variations with darker lightness values; soft, trace to spotty slightly brittle pieces; abundantly grades to very silty claystone; silty to clayey texture, occasional soft matte textures; earthy lustre; massive; dominantly structureless and mushy; barely developed irregular subtabular habit if brittle. SANDSTONE (295' -355') = Light gray to medium light gray to Tight grayish brown; mostly well sorted in very fine lower to very fine upper range; closely grades to "coarse" quartz rich siltstone; angular to subangular and subdiscoidal to subspherical; abundant matrix support by clay and silt, minor grain supported; only trace to spotty very weak calcite cementation; silty clayey Iithic quartz arenite; 5 -10% Iithics and mafic minerals. CLAYSTONE (360' -480') = Light brownish gray to medium Tight gray; slightly firm to very soft; moderate to high cohesion; low adhesion; low solubility; mushy to punky; firmer cuttings are crumbly to subcrumbly; irregular to subblocky fracture; subtabular to wedgelike habit; dull lustre; predominantly clayey texture, locally silty; thick to massively bedded claystone with thin siltstone interbeds; occasional laminae of organic material. SILTSTONE (440' -510') = Medium light gray to Tight gray; soft to slightly firm; firmer cuttings crumbly to sub crumbly; occasional irregular to subblocky fracture; subtabular cuttings habit when slightly firm; dull to slightly earthy lustre; silty texture; thinly interbedded and gradational with thick claystone; noncalcareous. EpocH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • COAL/CARBONACEOUS SHALE (470' -580') = Consistent spotty amounts occur as either thinly bedded or as large clastic fragments or as both; coal appears to be higher grade lignite, or possibly even subbituminous: coal is black, smooth, vitreous and resinous, with a blocky and slightly irregular habit and blocky massive non - conchoidal fracture; carbonaceous shale is dusky brown to brownish black, firm to brittle, has a dense matte texture and earthy lustre, is shaly in part and displays common micro coal particles. VOLCANIC ASH (550' -630') = A spotty amount appears is consistently observed throughout the interval. Very light gray to yellowish gray to very pale yellowish brown; soft to slightly firm; ashy to clayey to mixed ashy - clayey texture; earthy to microsparkly lustre; displays minor fraction of visible glass shards, many of which appear partially devitrified. CLAYSTONE (480' -680') = Light brownish gray to medium Tight gray with strong yellowish brown to pale brown secondary hues; common variation that looks generally more organic is pale brown to grayish brown; very soft to soft; hydrophilic, easily hydrated and appears expansive in part; rare slightly brittle pieces are massive and structureless; clayey textrure; earthy lustre; pastey to gelatinous consistency; good adhesion and moderate to poor cohesion. SANDSTONE (685' -695') = (Trace to spotty fractions after 695'). Light gray to medium light gray to light grayish brown; well sorted in very fine lower to very fine upper range; grades to sandy quartz rich siltstone; dominantly angular to subangular, and discoidal to subspherical; minor rounded grains; many clear grains appear to be winnowed glass shards; grain supported, but still significant intergrain clay and silt; trace weak calcite cementation; (silty clayey) Iithic quartz arenite; <10% mafic minerals and Iithics. SILTSTONE/CLAYEY SILTSTONE (510' -900') = Occurs as soft very silty patches within the more dominant clay; medium Tight gray to Tight brownish gray to pale brown; many trace local variations of secondary hues • and lightness values; soft, trace slightly brittle pieces; massive, mushy and structureless; abundantly grades to very silty claystone; silty to clayey to mixed silty - clayey texture to various soft matte textures; earthy lustre; rare irregular subtabular habit when brittle. SANDSTONE (800' -930') = Distinctive very soft matrix that is expansive when hydrated; very closely gradational to very sandy claystone; pale yellowish brown to medium light gray with strong brown secondary hues; well sorted in very fine range; <5% larger fine grains; dominantly subangular to subrounded, subdiscoidal to spherical; clay matrix supported; disintegrates if it is washed hard; (very clayey) Iithic quartz arenite; <10% mafic minerals and (meta)lithics. SANDSTONE (960 1030') = Light gray to light brownish gray overall, individual grains transparent to colorless and very pale colored translucent; predominantly quartz; upper very fine to lower very fine; well to very well sorted; angular to subangular; moderately well developed sphericity; clay matrix supported. COAL (970'- 1030') = Grayish black to brownish black; moderately hard to hard; subbrittle to brittle; blocky to conchoidal fracture; tabular to platy cuttings habit; dull lustre, occasionally vitreous; smooth to matte texture; thin bedded; subbituminous to lignite. CLAYSTONE (950'- 1080') = Light brownish gray to medium Tight gray, occasionally very light gray; very soft to soft, rare slightly firm; low to moderate cohesion; moderate adhesion; gelatinous to mushy, rarely pasty; rare firmer cuttings crumble slightly when pressed, and display irregular fracture and subtablular habit; dull to waxy lustre; clayey to smooth texture with occasional spotty siltiness; appears massively bedded with gradations to, and interbeds of, siltstone; flakes of organic material are sparsely disseminated. SILTSTONE (1050' - 1170') = Medium Tight gray to light brownish gray; soft to slightly firm; predominantly structureless clayey lumps, otherwise subcrumbly; irregular to indistinguishable fracture and cuttings habit; dull to earthy lustre; silty texture; thin interbedded with and gradational to claystone. • ta E POCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • SANDSTONE (1170'- 1250') = Light brownish gray to light gray overall; individual quartz grains are colorless to very pale brown to pale gray to very pale grayish orange pink, and 90% translucent and 10% transparent; lithic grains are diverse colors and hues, and generally also appear more opaque than quartz grains; lithics are dominated by a group of gray, brown, black, greenish gray and olive gray grains; very friable and disaggregated; moderately well to well sorted in fine lower to fine upper; roughly 10% ranges into medium lower, 5% into very fine and "coarse" silt; subangular to angular with spotty subrounded; subdiscoidal to discoidal; some longer grains grains are slightly prismoidal; most grains, despite sharp edges have roughly equal axis lengths, and overall display a moderate sphericity; clay matrix supported, some possible grain support; non - calcareous; (clayey) sublithic arenite to lithic quartz arenite; est. 80 -90% quartz, trace -5% feldspar, trace -5% various forms of cryptosilica and 5 -15% lithics and (dominantly black) mafic minerals. SANDSTONE (1250'- 1415') = Light brownish gray to light gray; common pale brown to light grayish brown secondary hues; note very abundant soft clay -silt matrix support; nearly all is closely gradational to a very sandy claystone; very fine lower to medium upper; overall exhibits most of same characteristics as sandstone described immediately above, but often is less well sorted, and has more variance in size, shape, roundedness and composition; note many of the soft cuttings have discernible thin interbeds of silt,clay and sandstone; (silty) lithic quartz arenite to lithic arenite. SHALE (415'- 1430') = Med gray to olive gray; light brownish gray secondary hues; brittle to slightly brittle; silty to clayey texture; earthy lustre; grades to shaley siltst; mostly subplaty. COAL (1440'- 1450') = Appears to be mostly high grade lignite or low subbituminous; black; very dense matte to smooth texture; dull to subresinous lustre; thin blocky to thin platy fracture. SANDSTONE (1415' - 1450') = Essentially a continuation of the sandstone described at 1250'- 1415'; generally has the same characteristics, but most is firmer, brittler and "cleaner ", with less silt in the supporting matrix; overall (silty) lithic arenite. • CLAYSTONE /SILTSTONE (1450 1750') = Rather than a group of individual rock types, the overall appearance of the formation is that of a single lithology, a MUDSTONE, CLAYEY MUDSTONE or SILTY MUDSTONE, with many variations of localized "clayier" and siltier" thin interbeds or zones; sandstone associated with the mudstone is nearly always soft, with a clay -silt supporting matrix and closely gradational to a very sandy mudstone; clay clearly dominates, is easily hydrated by the drilling mud, hydrophilic, soluble entirely or in part, gradational to very clayey soft siltstone, and has good adhesiveness and moderate cohesiveness; siltstone is soft, clayey, very slightly firm or brittle in trace to spotty amounts, and generally also displays more sand grains as silt increases; both claystone and siltstone have a clayey -silty texture and earthy lustre; some firmer clay has a faintly discernible shale structure. CLAYSTONE/SILTSTONE (1450'- 1750') = [Additional observations to those above, of this same interval.] Medium light gray to medium gray with spotty light brownish gray to light olive gray streaks; soft to very soft with occasional slightly firm cuttings; moderately cohesive, moderately to highly adhesive; some cuttings are slightly hydro - fissile; gelatinous to pasty consistency; occasionally punky; firmer cuttings have irregular to subblocky fracture; generally massive structureless cuttings habit; dull to earthy lustre; silty texture, occasionally gritty; claystone is gradational to very silty claystone and siltstone; rare sandy streaks or thin sandstone interbeds. CLAYSTONE/SILTSTONE (1750'-1850') = Medium light brownish gray to medium gray; soft to very soft, rarely slightly firm; moderate to low cohesion; moderate to high adhesion; moderately hydrophilic, gelatinous to pasty; massive and structureless with no discernible habit; earthy lustre; silty to smooth texture, rare locally gritty; claystone gradational to siltstone; locally sparse flakes of carbonaceous material. CLAYSTONE/SILTSTONE (1850'- 1950') = Medium light brown to medium light gray with slight trend toward olive hues in siltier portions; very soft to soft, very rarely slightly firm; low to moderate cohesion; moderate to high adhesion; gelatinous to mushy, curdy in part; massive structureless hydrated returns with little • indication of fracture type or habit; earthy to dull lustre; smooth to silty texture, occasionally gritty; massive claystone gradational to siltier claystone or siltstone; localized traces of carbonaceous material. PI EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • SANDSTONE/SAND (1810'- 2020') = Individual quartz grains are colorless and transparent, to colorless and very pale gray and other pale colors and translucent; upper very fine to lower very fine; occasionally to upper fine; well sorted overall; subrounded to subangular; well developed sphericity; apparent clay matrix supported. CLAYSTONE/SILTSTONE (1950'- 2070') = Light brownish gray to medium Tight gray very soft to soft becoming predominantly slightly firm around 2070'; low to moderate cohesion; moderate adhesion; predominantly massive structureless clay returns with locally varying degrees of siltiness and rare grittiness; firmer cuttings irregular to subblocky fracture; subtabular cuttings habit; dull lustre; silty texture; appears both massive and thinly bedded. SHALE (2040'- 2140') = Light medium gray to medium gray; slightly firm to subbrittle; crumbly; subblocky fracture; tabular to wedgelike cuttings habit; dull luster; smooth texture; subfissile; trace laminae of carbonaceous material. CLAYSTONE/SILTSTONE (2070'- 2160') = Light brownish gray to Tight medium gray; soft to slightly firm, occasionally very soft; moderately cohesive; low to moderate adhesion; mushy to pasty, occasionally gelatinous; irregular to subblocky fracture when more cohesive; subtabular habit; earthy to dull lustre; clayey to occasionally silty texture; claystone and siltstone are gradational and interbedded. CLAYSTONE/SILTSTONE (2160'- 2280') = This is MUDSTONE with variations in clay and silt content, but otherwise has a single set of characteristics; hydrated sample is brownish gray, with strong olive gray and dark yellowish brown secondary hues which locally become the dominant color; when dry the mudstone is medium light gray with faint secondary hues of the same wet colors described above; very soft to soft with minor slightly brittle to firm; mushy to pasty to gelatinous when hydrated, then punky to stiff when drying; soluble in part and hydrophilic; good adhesiveness, moderate cohesiveness; less sticky with increasing silt; 1 411 mostly massive and structureless when wet, but firm pieces display microthin beds and interbeds; silty to clayey to various matte textures; earthy lustre; clay contains trace to locally common sand grains; trace to spotty pieces of very fine silty sandstone and silty shale; when brittle, the siltstone, claystone and shale I commonly has thin carbonaceous laminations. SANDSTONE (2275'- 2300') = Medium light gray to Tight gray; (silty) sublithic arenite - lithic quartz arenite; very fine lower to fine lower; well sorted; dominantly subangular and subdiscoidal; displays abundant silt laminations; note moderately hard local zones of grain supported and calcite cemented sandstone. CLAYSTONE (2340'- 2470') = Light brownish gray to medium Tight gray with some portions trending toward Tight olive gray; soft to slightly firm, occasionally very soft; moderate to high cohesion; moderate to low adhesion; the more cohesive claystone is crumbly to subcrumbly with irregular to subblocky fracture and subtabular habit; the Tess cohesive claystone is structureless and shapeless; silt content is highly variable; earthy lustre; silty to smooth texture; occasionally grittly; abundantly gradational to silty claystone and siltstone. SILTSTONE/SANDSTONE (2425'- 2575') = Medium dark gray to medium gray to Tight olive gray; predominantly quartz with trace of other siliceous lithic fragments; predominantly coarse silt with minor fraction of very fine lower sand grains; sandstone fraction is well sorted, subangular to subrounded, has moderate(subdiscoidal) to well developed sphericity and a trace of near prismoidal grains; is soft and easily friable and predominantly clay matrix supported with spotty grain supported; siltstone fraction is crumbly to subcrumbly with irregular fracture and subtabular habit, has a silty to gritty texture and earthy luster, thinly bedded and abundantly interbedded with the very silty sublithic arenite sandstone. SILTSTONE (2460'- 2670') = Medium gray to brownish gray; soft to slightly firm; softer siltstone is mushy to gelatinous; structureless and lumpy when hydrated; dull to slightly waxy lustre; silty to gritty texture; firmer siltstone is crumbly to subbrittle with irregular to subblocky fracture and wedgelike to subtabular habit; earthy • to dull lustre; silty to gritty texture; both massive and thinly bedded, and grading to silty claystone, silty sandstone or very sandy siltstone. PI E POCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 SANDSTONE (2590'-2700') = Medium gray to olive gray, occasionally light brownish gray; individual grains II I colorless to very Tight gray and translucent to transparent, with minor vari - colored translucent to opaque; predominantly quartz and chert with other undifferentiated siliceous lithic fragments; lower very fine grained to silt sized, occasionally upper very fine, rarely lower fine; generally well sorted; subangular to subrounded in estimated equal fractions; moderately developed sphericity; predominantly easily friable and soft; occasionally moderately hard; mostly clay matrix supported; some harder grain supported with mix of clay and calcite cementation; overall appearance is of a moderately argillaceous and /or silty sandstone. SHALE (2520'- 2800') = Not well developed; most of the shale structure is barely discernible; this is a VERY SILTY SHALE; approximately 90% has a high silt content, and the remaining 10% appears to be almost exclusively clay; olive gray to brownish gray to medium dark gray, with each dominant color having strong secondary hues of the other colors; soft to brittle range, but mostly slight to moderately brittle or firm; initially appears massive and structureless until broken, and then very subtle parallel lines or laminations are revealed in the rock fabric; dominantly irregular lumpy to subplaty habit, with occasional larger thinner platy pieces; the silty shale will not separate in planar fashion; the "clayier" shale is slightly darker gray and also is somewhat massive looking, but does separate in an uneven rough planar orientation; nearly all of the shale grades to shaly silst or shaly silty sandstone; SILTSTONE (2670 2900') = Light brownish gray to medium Tight gray, locally with pale yellowish brown or Tight olive gray secondary hues; closely gradational to silty claystone, silty sandstone and silty shale, and superceding claystone as the dominant fraction of a thinly bedded SILTY MUDSTONE unit; soft and lumpy and structureless when well hydrated; when Tess hydrated and thus firm or brittle, it is massive to slightly shaly, with irregular subblocky to subplaty and occasionally subsplintery cuttings fracture; most of the mudstone is slightly brittle or slightly firm; large brittle pieces range from crumbly to marginally tough, and often have a rounded wedge -like habit; silty to clayey to mixed silty- abrasive to soft matte textures; earthy lustre; often calcareous in part (especially when sandy). SANDSTONE (2890 3000') = Medium light gray with very faint light olive gray secondary hues, and patchy pinpoint splotches of very light gray within the clay matrix; very fine lower to very fine upper with traces in fine lower; well sorted (95 %) in very fine upper; sbangular to angular and dominantly subdiscoidal; despite the very fine grain size, there are abundant reflections of light off of the quartz grains, indicating many flat crystalline faces and suggesting very common secondary silica; 98% matrix support, >2% grain supported; the white matrix has a soft very glassy appearance that is suggestive of devitrified volcanic ash (smectite- illite clay group); the sandstone is often very silty and /or very clayey and abundantly grades to those other lithologies; roughly equal fractions of the sandstone are either very calcareous or non - calcareous; silty or ashy lithic quartz arenite; estimated 10% fraction is various forms of cryptosilica (chert, chalcedony) and marginally diverse lithics. CLAYSTONE (3000'- 3090') = Medium light gray to medium gray to Tight brownish gray as claystone grades to siltier formation; slightly firm to soft; high cohesion; low adhesion; crumbly; irregular to subblocky fracture; tabular to massive cuttings habit; dull lustre; clayey to silty texture; gradational to, and interbedded with, siltstone and sandstone; rare to trace loose pyrite in sample. SILTSTONE (2900 3175') = Light brownish gray to medium light gray, common Tight olive gray and occasional light yellowish brown secondary hues; closely gradational to silty claystone and silty shale; part of an overall thinly interbedded SILTY MUDSTONE that includes claystone, shale and spotty very fine sandstone; when hydrated can be soft and lumpy and structureless; when non or partially hydrated is slightly to moderately brittle or slightly to moderately firm; irregular subplaty to subblocky to slightly wedgelike cuttings habit; fragile and crumbly; silty to clayey to mixed silty - clayey to various matte textures; earthy lustre; commonly calcareous in part. • El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • CLAYSTONE (3175'- 3300') = Light brownish gray to medium gray with some olive gray hues; overall very soft to soft; dominantly structureless clay lumps; with increasing depth claystone becomes more cohesive and has varying amounts of silt and trace sand; moderately to highly adhesiveness; moderate to low cohesion; moderately soluble; massive with thin shale and siltstone interbeds, gradational siltiness; dull to earthy lustre. SHALE (3260'- 3360') = Medium gray to medium dark gray; slightly to moderately firm; crumbly to subbrittle; subblocky to planar fracture; subtabular to wedge -like cuttings habit; dull lustre; smooth to clayey texture; subfissile. CLAYSTONE (3300'- 3360') = Light brownish gray to light olive gray to medium light gray; very soft to soft, occasionally slightly firm; moderate cohesion; moderate adhesion; slightly soluble; gelatinous to mushy, occasionally pasty; irregular to subblocky when not structureless clay lumps; dull to earthy lustre; silty to smooth texture, occasionally gritty; thickly to massively interbedded with, and gradational to, siltstone and rare sandstone. SHALE (3360'- 3460') = Dark gray to medium dark gray with strong olive gray to olive black secondary hues; thinly interbedded with the siltstone and claystone; many cuttings pieces display visible microthin interbedding of the dark gray siltstone with minor light brownish gray siltstone; slightly brittle to slightly firm to soft; clayey texture; earthy lustre; moderate to poor fissility; thin platy habit; very fragile. (Note the relative absence of brown colored soft silty shale with poorly developed fissility that is associated with the hydrated clay /silt). SANDSTONE/SAND (3450'- 3520') = Overall very silty or locally ashy sandstone; light gray to light grayish brown with occasionally strong light olive gray secondary hues; very fine lower to fine lower; well to moderately well sorted (85 -90 %) in very fine upper; subangular to angular, subdiscoidal to subspherical; minor (5 %) fraction with better developed sphericity; clay matrix supported; one variation is supported by a very light gray soft glassy looking clay that appears to be redeposited volcanic ash, and second variation by brown "muddy" silty soft clay; all of the sandstone is abundantly to slightly calcareous, and a variable fraction is very calcareous; clayey (ashy) sublithic arenite to lithic arenite; estimated 65 -85% quartz (and possibly winnowed glass shards, trace -5% feldspar, trace -5% various forms cyrptosilica (chert, chalcedony), trace to 10% micro carbonaceous and /or coal fragments; trace to 10% lithics and mafic minerals; locally common brown transluscent minerals; trace to spotty locally abundant loose pyrite grains and tiny fragments of framboidal pyrite. TUFFACEOUS CLAYSTONENOLCANIC ASH (3470'- 3670') = Consistently present in at least trace amounts; very light gray to yellowish gray; occasionally with very pale orange or grayish orange pink secondary hues; soft to very soft after hydration; rare very slightly brittle pieces; distributed as tiny blebs within the clay and silt, as well as occuring in microthin patchy zones; appears to increase in abundance in sandier zones (sandstone); some sandstone may have "smushy" microscopic lithic clasts of ash; ashy to clayey texture; mixed microsparkly and earthy lustre when wet, and soft glassy appearance when dry. SHALE (3460'- 3760') = Dark gray to medium dark gray with strong olive gray to olive black secondary hues; thinly interbedded with the siltstone and claystone; a second variation is light brownish gray and is the shaly fraction of the "muddier" abundant silty claystone; slight to moderately brittle; clayey to silty to various matte textures; earthy lustre; fissility appears to improve as depth increases. CLAYSTONE/SILTY CLAYSTONE (3760'- 3960') = Medium light gray to brownish gray colors of varying lightness values and various gray and brown secondary hues; soft to very soft to slightly firm; roughly half the claystone is present as lumps of hydrated structureless very soft to soft clay that is abundantly mixed with silt and /or very fine sand; the remaining half of the claystone is more cohesive and has generally "firmer" characteristics, including: punky to pasty consistency; crumbly to subcrumbly tenacity; subblocky to irregular fracture; wedgelike to subtabular cuttings habit; dull to earthy lustre; clayey to silty to mixed clayey - gritty texture, thinly to massively bedded; gradationally silty; interbedded with different thicknesses 41111 of siltstone and thin sandstone. 1E1 EP CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • SHALE (3760'- 3920') = Medium dark gray to medium gray, occasionally dark gray; moderately firm to slightly firm; subbrittle to crumbly; planar to blocky fracture; tabular to subplaty cuttings habit, occasionally wedgelike; dull to earthy lustre; clayey texture, occasionally slightly silty; subfissile; thinly interbedded with claystone and siltstone. SILTSTONE (3820'- 4110') = Brownish gray to Tight brownish gray with strong medium Tight gray to medium gray secondary hues; slightly firm to soft; when mixed with significant fractions of clay is moderately to highly cohesive and poorly adhesive; when firmer and siltier its characteristics are: crumbly to subcrumbly; irregular fracture; wedgelike to subtabular cuttings habit; earthy to dull lustre; silty texture that locally grades to mixed silty - microgritty; gradational to both claystone and sandstone; occasionally displays discrete thin interbedding with claystone. SANDSTONE (3920'- 4110') = Medium gray to olive gray to medium Tight gray; very fine Tower sandstone that is closely gradational to siltstone; well sorted; subangular to angular, occasionally subrounded; high to moderately developed sphericity; easily friable; both matrix and grain supported; weak calcareous cementation in part, otherwise matrix of mixed clay - silt - silica; locally abundant carbonaceous microflakes; predominantly quartz with secondary amounts of chert and undifferentiated lithic fragments. CLAYSTONE (3960'- 4170') = Medium light gray to brownish gray; very soft to soft, rarely slightly firm; predominantly structureless clay lumps; moderately to highly adhesive; low to moderate cohesion; moderately to highly mixed with silt, very fine sand, and various small clastic fragments; mushy to pasty consistency, occasionally gelatinous; irregular fracture where discernible; dull lustre; predominantly silty to gritty texture, occasionally smooth; locally moderately calcareous (often from microscopic calcite particles and fragments). SILTSTONE (4110'- 4230') = Light brownish gray to medium gray; soft to very soft, rarely slightly firm; pasty to mushy; subcrumbly when firmer; irregular fracture, occasionally subblocky; wedgelike to subtabular S cuttings habit; dull to earthy lustre; silty to gritty texture; interbedded with, and gradational to claystone and sandstone. SHALE (3920'- 4600') = Note two major variations of shale (with transitional types); dominant first type is brownish gray to light brownish gray with very strong medium light gray to medium dark gray secondary hues, and locally also with faint to strong yellowish brown or olive gray secondary hues; soft to slightly brittle to slightly firm; becomes very soft clay when pulverized and hydrated; this first variation is mostly a very silty shale with poor and often barely discernible fissility, and is a MAJOR FRACTION OF THE overall very dominant SILTY MUDSTONE; this muddy shale variation shares color, habit, and textural characteristics with associated massive claystone and siltstone and differs only by having some shale structure; mixed clayey -silty to silty texture; earthy lustre; planar separation, if it occurs, is very uneven and rough. SHALE (3920'- 4600') = The second major shale variation of this interval is less abundant overall than the "muddy" silty shale, but locally increases in abundance to become dominant; olive gray to brownish gray to medium dark gray, with each color having strong secondary hues of the other colors; soft to brittle range, but mostly slightly to moderately brittle or firm; though also having moderate to poorly developed fissility, pieces of this shale variation appear as distinctly thinner, flatter and platier, and very often also have a splintery habit that the "muddy" silty shale Tacks; when pressed the shale will tend to separate in a rough planar fashion, and the "best" cleanest looking pieces will separate cleanly; clayey to several dense matte textures; earthy lustre; traces with micro carbonaceous laminations or very thin broken streaks of silt -size pyrite grains; some of the darker gray shale may be slightly carbonaceous in part. • El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 SILTSTONE/CLAYSTONE (4230'- 4700') = This is a SILTY MUDSTONE with many local variations in silt and clay content, but otherwise shares essentially the same characteristics of color, texture, habit and overall appearance; most of the shale is just a shaly variation of the massive mudstone; brownish gray to Tight brownish gray with medium light gray to medium gray, light yellowish brown, and occasionally also light olive gray secondary hues; when dried the mudstone often appears medium light gray with faint secondary hues of wet colors described above; very soft to soft to slightly brittle or firm; trace to spotty siltstone is moderately brittle; note that overall the mudstone cuttings are "firming up" and becoming siltier with depth; claystones are mushy -pasty to gelatinous when hydrated, then punky to stiff when drying; soluble in part, hydrophilic; good adhesiveness, moderate cohesiveness; less sticky with increasing silt; mostly massive and structureless when wet and soft, but firmer pieces display microthin beds and interbeds; silty - clayey to various matte textures; earthy lustre; some silt -clay grades to very fine silty or clayey sandstone; spotty siltstone is composed of "silt only" and has a different texture with a distinctive micrograininess; note that the "coarser siltstone grains are close to the sand cutoff (62microns); non to very calcareous range; mostly slight to moderately calcareous. SANDSTONE (4700'- 4850') = Overall light brownish gray to medium gray, and trending toward olive hues; individual grains predominantly white to very light gray translucent to transparent, occasionally medium dark gray to dark gray; predominantly lower very fine to upper very fine, occasionally upper fine; well to very well sorted; subangular to subrounded, occasionally angular; moderate to well developed sphericity; easily to very easily friable; grain supported with minor matrix support; weak to very weak calcareous cementation; locally abundant tuffaceous matrix; abundant to sparse dark yellowish brown carbonaceous flakes; fair to poor visually estimated porosity; no discernible sample fluorescence; no cut. SILTSTONE/CLAYSTONE (4760'- 4910') = Light brownish gray to medium gray with olive gray secondary hues; soft to slightly firm; crumbly to subbrittle; irregular to subblocky fracture; subtabular to wedgelike cuttings habit; dull to slightly waxy lustre; silty to locally gritty texture; clay -rich cuttings tend to be silty structureless lumps with mushy consistency; the overall sample and all the various lithologies appear to be 411 moderately to slightly calcareous. SANDSTONE (4910 5050') =Light brownish gray to light olive gray to medium gray overall, individual grains predominantly colorless and transparent to white translucent to very Tight gray; trace to spotty grains of various colors ranging from dark gray to moderate green; grains in sand range make up an estimated 20% or less of the total cuttings content, with the balance being silt or clay /ash (matrix) material; lower very fine, occasionally upper very fine; well sorted; subrounded to subangular; predominantly well developed sphericity; easily friable to soft; grain supported in silt dominated cuttings, matrix supported in ashy cuttings; moderate trace to locally abundant carbonaceous flakes (but generally less than described in 4700' -4850' interval); weak calcareous cementation; poor visually estimated porosity; no discernible sample fluorescence; no cut. CLAYSTONE (4960'- 5145') = Light brownish gray to medium Tight gray; very soft to soft, rarely slightly firm; moderate to low cohesion and high to moderate adhesion; locally moderately soluble; mushy to pasty consistency; well hydrated structureless clay lumps; dull lustre; smooth to silty texture; thick bedded grading to and interbedded with siltstone; moderately to slightly effervescent with HCI, possibly a characteristic of the clay or possibly due to calcite particles. SILTSTONE (4900'- 5400') = Note two major variations of siltstone. The most abundant type is the continued silty fraction of the SILTY MUDSTONE that dominates the interval; almost always clayey in part and closely gradational to very silty claystone; light brownish gray with very strong medium light gray to medium gray secondary hues plus faint pale yellowish brown, pale brown, and occasionally light olive gray secondary hues; soft to slightly brittle or firm; mushy when well hydrated; mostly lumpy and structureless, becoming "wedgy" or subblocky /subtabular as the tenacity becomes more resistant; a minor amount is also very slightly shaley; mixed silty - clayey to silty texture; earthy lustre; this silty mudstone variation is massive to thinly bedded; locally the bedding is microthin; note increasing occurance of very thin sandier, grainier, non- • clayey siltstone interbeds; non - moderately calcareous. EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • SILTSTONE (4900'- 5400') = The second major siltstone variation appears to have a closer association with the sandstone present, than with mudstone, and though less abundant overall than silty mudstone, often is locally dominant. Mostly the same colors as muddier siltstone, but consistently in higher lightness values; light brownish gray to medium light gray with strong pale yellowish brown secondary hues; occasional faint grayish orange secondary hue; slightly brittle or firm and "brittle!'" than the muddy silstone; part of this sandier siltstone type is still gradational to the mudstone, but most is distinctly "grainier" and siltier; very often is a "coarse" silt that is just below the very fine sand (62 micron) cutoff, and locally grading to sandstone; commonly displays micro interbedding of darker thin zones, "bands" or laminae and lighter colored silt; silty to microabrasive to mixed silty to "sandy" to several coarse matte textures; earthy to microsparkly lustre; an abundant fraction has common to abundant "floating" very fine to fine sand (quartz) grains; moderately to very calcareous. SANDSTONE/SILTY SANDSTONE (5050'- 5500') = Medium light gray to light gray with strong light brownish gray secondary hue; very fine lower to very fine upper, with spotty fraction in fine range; well to moderately well sorted in very fine, especially very fine lower; silty and closely gradational to the coarser siltstone described above; subangular to subrounded; subdiscoidal to subspherical; trace of rounded and well rounded grains that appear to be reworked glass shards; clay and silt matrix supported; very silty and clayey sublithic arenite to Iithic quartz arenite; 10 -15% mix of darker gray cryptosilica (chert, chalcedony), lithics and mafic minerals. SHALE (5450'- 5630') = Medium dark gray to dark gray with brownish gray hues; moderately firm to slightly firm; brittle to subbrittle; blocky to planar fracture, occasionally subsplintery; platy to tabular cuttings habit; dull to earthy lustre; smooth to silty texture; subfissile to fissile; slightly to moderately calcareous. SILTSTONE (5500'- 5830') = Light brownish gray to medium Tight gray to olive gray; slightly firm to soft; variable clay content; as clay fraction increases the cuttings are softer, more hydrated, structureless and shapeless and more adhesive; as clay fraction decreases the siltstone becomes firmer and its • characteristics are: crumbly to subbrittle; subblocky to irregular fracture; subtabular cuttings habit; earthy to dull lustre; silty texture that becomes increasingly gritty in local transitions to sandstone; displays sparse to locally abundant distribution of carbonaceous material as particles and as laminae; interbedded with and gradational to claystone and sandstone; moderately calcareous. SANDSTONE (5500'- 5830') = Medium light gray to light bluish gray with light brownish gray hues; individual grains are colorless to pale gray to "off" white and translucent to transparent; occasionally pale green; fine upper to fine lower; locally very fine upper to very fine lower and ranging into silt; most is well sorted; subangular to angular, occasionally subrounded; moderately developed sphericity, subdiscoidal to subspherical; friable; roughly 50% of the sample is disaggregated; 80 -90% of the consolidated sandstone is matrix supported by soft tuff /clay and has very poor estimated porosity; 10 -20% of the consolidated is grain supported with weak calcite cementation, displays a higher content of silt and carbonaceous material content and has poor estimated porosity; no sample fluorescence; no cut. CLAYSTONE (5710'- 5910') = Light brownish gray to medium light gray, occasionally very light gray; very soft to soft, rarely slightly firm; moderately cohesive; moderately to highly adhesive; well hydrated structureless lumps; mushy to pasty, occasionally gelatinous; firmer cuttings have irregular fracture; massive cuttings habit; larger cuttings display PDC bit metamorphism; dull to subwaxy lustre; smooth to silty texture; interbedded with and gradational to siltstone; slightly to moderately calcareous. • EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 . SANDSTONE (5940'- 6010') = Light brownish gray to medium gray; locally has laminar zones with very light gray to yellowish gray; lower fine to upper fine, with abundant very fine and silt -size particles throughout increasing with depth; fair to well sorted; sbangular to angular, occasionally subrounded, finer grains tending to be most angular; moderately developed sphericity; individual grains are pale gray, pale brownish gray, pale brown, coloreless to "off" white and translucent to transparent; very abundantly disaggregated; with spotty grain supported and tuffaceous clay matrix supported; volcanic ash derived matrix produces a light "banded" appearance; soft when hydrated to easily friable; rare firm friable to moderately hard calcite cemented sandstone; fair to poor estimated visual porosity; 60 -80% quartz and light gray colored chert, 20- 40% (meta)lithic rock fragments, mafic minerals, dark gray chert and clastic flakes of carbonaceous material; the carbonaceous grains become abundant toward the bottom of the interval; no sample fluorescence. Note that SOLTEX was recently added to the mud system. The SOLTEX microparticles generate a bright to very bright white cut fluorescence that can "mask over" the cut fluorescence that would be produced by natural hydrocarbons. This sandstone was suspected of having hydrocarbons (C1 -05 gases present) and -- generated strong bright white to slightly yellowish white cut fluorescence, but shows could not be determined due to the SOLTEX contamination. SANDSTONE (6075'- 6120') = Medium gray to medium light gray to olive gray; common Tight brownish gray secondary hues; local thin zones of 100% sandstone are often light gray with black and various "off- gray" colored grains that produce a "dirty" salt and pepper appearance; very fine lower to fine upper; moderately well sorted within very fine upper to fine lower range; either there is subtle fining upward, or each sandstone lobe has slightly different sorting range; trace (1%) grains are lithics in medium lower; 90% angular 10% subangular and nearly all discoidal; note near absence of even a trace of rounded grains; both matrix and grain supported types; overall more silt matrix supported but local zones are dominantly grain supported; matrix supported is usually soft and very fragile and easily separated; soft silty sandstone is moderately to very calcareous; grain supported sandstone is only slightly calcareous and appears mostly cemented by silica and "smushy" thin firm intergrain clay that appears to be composed of slightly glassy looking devitrified ash and some micro - micas; sublithic arenite to lithic arenite; 65 -80% quartz, trace to 5% feldspar, 20 -30% diverse lithics, mafic minerals and imbedded gilsonite fragments (or other asphalt type) and /or carbonaceous fragments; lithics include greenstone rock fragments, pale bluish gray schist fragments and various translucent brown and gray rock fragmens and minerals; poor visual porosity; no sample fluorescence; initial pale white cut fluorescence with thin milky brighter streaming increased in intensity to very bright, but cemented GILSONITE grains plus probable SOLTEX contamination created most of the cut; clean sandstone pieces with gilsonite absent still generated cut fluor, but only pale to marginally bright yellowish white to whitish yellow with wispier less bright streaming; dry resididual cut fluorescence was only dull yellow and patchy. SANDSTONE/SAND (6260'- 6370') = Most of the same characteristics as sandstone described at 6075'- 6120'; same general appearance but Iighteness values are more often Tight gray to medium light gray, and there are fewer individual black grains; the black grains include mafic minerals, carbonaceous or gilsonite grains, and lithic (argillite) rock fragments; possible fining upward through the upper zones of each massive section; the size distribution in the middle and lower zones of each section appears to be fairly even; very fine upper to fine upper, traces in medium; moderately well to well sorted in fine lower range; both grain and matrix supported; slightly calcareous; abundant matrix supported appears white, soft and glassy, and looks like devitrified ash with later silica replacement; isolated sandstone pieces have a very pale to dull yellow sample fluorescence; most has pale faintly yellowish white instant cut fluorescence with thin slightly brighter streaming and occasionally blooming; the cut gradually increases in intensity (5 minutes) to moderately bright. SHALE (6120'- 6450') = Two sections with nearly identical characteristics above and below sandstone interval above; medium gray to medium dark gray to olive gray; local darker hues, especially to olive black; common brownish gray to brownish black secondary hues; slightly to moderately brittle and slightly to moderately firm; soft, when pulverized and hydrated; moderately developed shale structure, moderate to poor fissility; subblocky to subplatey to platy and splintery; many fairly long pieces; improved planar separation; clayey to silty to various matte textures; earthy lustre. • El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 SANDSTONE (6435'- 6465') = Most of same characteristics as the higher massive sandstone sections after • 5940', but this interval is very fine lower to very fine upper, well sorted, and visibly tighter than previous intevals; the cuts produced generally have a less intense fluorescence than what was observed in the earlier sandstones. SHALE (6465' -6560) = Most characteristics are the same as previous shale interval, but note an increase in shale with well developed structure, good fissility, many longer splintery pieces, and larger pieces whose grain fabric has tightly packed particles that all lie roughly parallel; common medium dark gray shale with grayish black to black laminations and good planar separation along the laminations; slightly to moderately brittle to firm; fragile to marginally tough; clayey to silty to organic texture; earthy lustre; some pieces display "ridged" laminations. SANDSTONE (6550'- 6570') = Medium light gray with light olive gray secondary hues; also common to light gray; very fine lower to fine upper; moderately well sorted in very fine upper to fine lower range; continued same general characteristics as massive sandstone sections after 5940'; bright whitish yellow sample ✓ fluorescence; tight; slow bright white to slightly bluish white cut fluorescence, very slow streaming. SANDSTONE (6595'- 6610') = Medium light gray to medium gray with olive gray hues in part; with secondary Tight gray to light olive gray; very fine lower to very fine upper, occasionally fine; well sorted in very fine upper; continued same general characteristics and composition as massive sandstone sections after 5940'; moderately bright yellowish white sample fluorescence; slow bright bluish white to white j blooming cut; dull dark yellowish gold residual cut. SHALE / VOLCANIC ASH (6620'- 6745') = Interbedded shale and devitrified ash; shale characteristics: grayish black to brownish black; darker gray microzones often alternately laminated with lighter gray zones; slightly to moderately brittle and slightly to moderately firm; some appears mushy but still flakes apart; abundant fraction appears organic; good fissility; thin platy to near "cut leaf" habit; organic matte texture; earthy lustre; some displays abundant thin carbonaceous laminations, often separated by equally thin gray clay layers; Volcanic ash: light bluish gray to light gray, occasionally medium Tight gray with strong pale yellowish gray secondary hues; brittle to firm; shaly; thin platy to splintery to thin blocky; devitrified volcanic ash; smooth to dense matte texture; subwaxy to waxy lustre. SHALE/CLAYSTONE (6745' - 6825') = Significant increase in non - fissile pieces, and softer more easily hydrated claystone; becomes increasingly lighter in color; dominantly pale yellowish brown; dark yellowish brown shale fraction continues with significant change in cuttings habit; now 1 to 5 mm diameter with common flaky appearance and trace amounts of fine to medium grain sands dispersed throughout. Note trace amount of pale yellowish brown carbonate (siderite ?) in sample at 6740'. SAND /SANDSTONE (6820 6830') = Another "Brookian" sand after 5940' with generally the same characteristics as the more massive sections above: medium light gray; very fine lower -fine upper; well sorted in very fine upper to fine lower; dominantly subangular and subdiscoidal to discoidal; this sample has abundant disaggregated sand grains; consolidated pieces are dominantly matrix supprted; faint gold • sample fluorescence; faint yellowish white to whitish yellow cut fluorescence with slow slightly brighter yellow streaming and blooming that increased intensity to moderately bright whitish yellow to yellowish white; very spotty marginally bright yellowish white residual dry cut ring fluorescence. SHALE / "PEBBLE" SAND (6830'- 6885') = Medium gray to grayish black to brownish black; brittle to firm; platy to subplaty; moderately well developed fissility; clayey to silty to dense matte textures; earthy lustre; very common loose sandstone grains, some are rounded coarse upper transparent quartz grains; many grains have a slight reddish brown stain; common disaggregated grains; also many grains that appeared to be "loose" or "floating" in the shale; very common pyritized shale; and tiny agglomerations of micro pyrite crystals and particles; rare shale with medium to dark green glauconite grains. El EPOCH I L CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • SANDSTONE / SAND (6885'- 6915') = Kuparuk Sand: pale to dusky yellowish brown; fine lower, well sorted; minor fraction of grains ranges to coarse; pieces of consolidated sandstone are grain supported with silica cementation; trace matrix supported pieces have a siliceous matrix; dominantly subangular to subrounded, subspherical; most cemented pieces are marginally hard rather than friable; pervasive brown stain that looks like oil staining, but there is no sample fluorescence; fast to slow bright white to slightly bluish white cut fluorescence with slow blooming and streaming. SHALE (6915 7020') = Distinctive very dusky red color dominates; often looks orangish brown under the microscope; minor to locally abundant fraction is light to dark gray; brittle to firm, and moderately to very tough; thick platy to blocky to splintery habit; note very dusky red shale has a distinctive micrograiny to "rough "clayey texture, and locally, if very calcareous to very limy often has a microsucrosic texture; dense earthy to rough vitreous lustre; gray shales have a "clayier" texture and dominantly smoother texture; gray shale is often present as long thin cuttings pieces; some shale is very silty in part; note that abundant soft clay, since pieces of massive claytone are absent in the samples, is apparently the result of pulverized, hydrated and "mudded" shale. Note that the shale has a moderately bright light yellow cut fluorescence. SAND (7025 - 7120') = Probably cavings from uphole. Persists throughout the section. Amounts range from strong trace to 10 %. Light gray to white overall; clasts range from very fine lower to fine upper; subangular to rounded; moderately well sorted; composed of 80% quartz, 20% (meta)lithics and mafic minerals; note distinctive traces of microcrystalline pyrite, dark green glauconite and inoceramus fragments. SANDSTONE/SAND (7125' - 7220') = Mix of pale to dark yellowish brown, pale grayish brown, Tight gray, pale brown; approximately equal fractions of colorless transparent grains, and grains with brown color that appear hydrocarbon stained; well sorted in very fine range; more very fine upper than very fine lower overall, but several local zones are dominated by very fine lower; trace fine lower grains; dominantly subrounded to rounded, subspherical; matrix support greater than grain support overall but precedence varies; variable non to moderately calcareous; matrix ranges from very dense crystalline (white to dark gray • to brown) clay minerals to siliceous to calcareous; common microcrystalline black to dark brown streaks and patches from bioturbation; visible micro- zoning of both light and dark colored sandstone; glauconitic quartz arenite to lithic quartz arenite; scattered dark to medium green very fine glauconite; appears tight and low visible porosity; rare faint petroleum odor; no sample fluorescence (rare very faint yellow sample fluorescence at 7220'); fast to instant diffuse pale to moderately bright white to slightly bluish white cut fluorescence with slow slightly brighter streaming and blooming; intensity increases in time to bright; initial wispy streaming widens and stops; very dull to moderately bright Tight yellow residual cut fluorescence; no cuts or ring visible in plain light. PELLET RICH SILTSTONE AND SANDSTONE (7223'- 7240') = Medium dark gray to dark gray to olive gray to olive black, lighter gray secondary hues; brittle to moderately hard, tough; thinly interbedded; very distinctive glauconite oolites, chamosite replaced oolites and locally very abundant larger peloids; replaced by medium gray, medium to dark greenish gray, brownish gray, dense opaque black, vitreous black minerals; some rocks have micro vugs in or near some black minerals; some black minerals app to be a solid ✓ hydrocarbon with visible pale straw cut, very strong; brittle; white cut fluorescence; note that an associated faintly grayer black mineral does not cut at all; there are abundant peloids with rims. VERY SILTY SHALE (7285' - 7313') = Siltstone that tends to flake apart; subfissile; dusky yellowish brown to grayish brown to medium dark gray, graysh black to brownsh black; brittle; platy and elongated habit; planar to splintery fracture; tough; variably silty, microsucrosic, and micrograiny textures; dull to subvitreous lustre; dominantly subfissile; upper part has abundant glauconite; the glauconite is altered in part to minerals whose colors are medium to dark greenish gray, light medium gray to black, and whose textures are dense clayey to microcrystalline to cryptocrystalline; much of the alteration is to chamosite minerals. • FPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 SILTSTONE (7380'- 7450') = Note that the siltstone in this interval appears very homogeneous in color, texture, overall appearance; pervasive brownish gray, trace light brownish gray in part; slightly brittle to brittle to firm; mostly fragile to occasionally marginally tough; silty to very finely abrasive or grainy texture; only occasionally appears to be slightly sandy in part; most is slightly shaley; locally massive; most randomly separates when pressed, but commonly will separate in a near planar fashion; earthy lustre; some softer pieces have various matte textures; only rare laminations or micro interbedding. SILTSTONE (7450'- 7585') = Note that this siltstone is very homogeneous in color and cuttings size; medium brownish gray, occasionally with patchy Tight brownish gray, rarely with slight olive hues; firm to moderately hard, dominantly moderately brittle and crumbly; occasionally moderately tough; brittle; weak to occasionally moderately tough; tabular, blocky, subplaty cuttings; earthy lustre with scattered microsparkles; silty to gritty to microabrasive texture; scattered to com very fine sand grains; locally grades to silty claystone as silt percent decreases; non to slightly calcareous; scattered black pinpoint specks; trace amounts of microcrystalline pyrite; commonly displays subtle very fine laminations or bands; incipient fissility; increasing development of shale structure with depth and abundantly grading to VERY SILTY SHALE; no sample fluorescence; near instant faint diffuse pale yellow cut fluorescence; no other oil indicators. SANDSTONE (7600' - 7680') = Pale yellowish brown to pale brown, light brownish gray; clasts range from very fine lower to very fine upper, with scattered fine lower grains; subangular to rounded; moderately well sorted in the very fine range; composed of dominantly quartz with minor lithics; scattered dark grayish green to greenish gray glauconite; traces of a dark gray mineral, possibly an alteration product of glauconite; dominantly silt and clay matrix supported grains; no discernible sample fluorescence; instant light yellow moderately bright cut fluorescence followed by slow light yellow to white cut fluorescence; cut and cut ring not visible in white light. SANDSTONE (7680' - 7765') = Pale yellowish brown to pale brown, occasionally Tight brownish gray; grains • range from very fine lower to very fine upper, scat to rare fine lower grains; subangular to rounded; moderately well sorted in the very fine range; quartz rich with scattered lithics; scattered to occasionally common grayish green glauconite, trace amounts of dark gray mineral, possibly an alteration product of glauconite; dominantly silt and clay matrix supported; increase in silt content with increasing depth; estimated poor porosity; no sample fluorescence; instant pale yellow diffuse cut fluorescence with very slight increase in intensity over 5 minutes; no cut or cut ring residue visible in white light. SILTSTONE (7760'- 7900') = Medium to occasionally light brownish gray; rare pale yellowish brown and olive hues; firm to moderately hard; crumbly to brittle; weak to moderately tough; tabular, blocky and platy cuttings habit; very closely GRADATIONAL to a VERY SILTY SHALE; abundant pieces with fairly clean easily parted planar separation; occasionally with light gray to white banded appearance; silty, microabrasive, microgritty, and various matte textures; earthy lustre with scattered microsparkles; trace to spotty harder siliceous and /or calcite replaced siltstone has microsucrosic texture, subvitreous lustre; local siltstone variations grade to very fine sandstone or claystone; massive siltstone displays sparsely to densely distributed "floating" very fine sand grains; scattered black pinpoint specks and /or microcrystalline pyrite are common; dry rock fabric has dense (nearly continuous) reflective micro surfaces; no sample fluorescence; instant faint diffuse pale - marginally bright yellow cut fluorescence (only oil indicator). • FP OCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 0 SURVEY INFORMATION Depth Inclination Azimuth Vertical Northings Eastings Vertical Dogleg Feet Degrees Degrees Depth Feet Feet Section /100ft 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE -IN 468.63 0.26 105.02 468.63 0.27 S 1.02 E -0.27 0.06 562.90 0.27 264.37 562.90 0.35 S 1.01 E -0.35 0.55 651.76 0.31 260.59 651.76 0.41 S 0.56 E -0.41 0.05 739.98 0.22 251.82 739.98 0.50 S 0.17 E -0.50 0.11 830.60 0.25 279.55 830.60 0.52 S 0.18 W -0.52 0.13 920.04 0.24 235.04 920.03 0.60 S 0.53 W -0.60 0.21 1011.14 0.22 200.55 1011.13 0.87 S 0.75 W -0.87 0.15 1103.01 0.12 224.61 1103.00 1.10 S 0.87 W -1.10 0.13 1195.58 0.09 182.75 1195.57 1.24 S 0.94 W -1.24 0.09 1289.53 0.03 179.91 1289.52 1.34 S 0.95 W -1.34 0.06 1353.42 0.04 348.44 1353.41 1.33 S 0.95 W -1.33 0.11 1475.03 0.30 25.75 1475.02 1.00 S 0.82 W -1.00 0.22 1566.92 0.17 72.52 1566.91 0.74 S 0.59 W -0.74 0.24 1660.32 0.11 42.75 1660.31 0.63 S 0.40 W -0.63 0.10 1752.83 0.13 14.20 1752.82 0.46 S 0.31 W -0.46 0.07 1847.30 0.22 14.64 1847.29 0.18 S 0.24 W -0.18 0.10 1941.92 0.07 4.48 1941.91 0.05 N 0.19 W 0.05 0.17 2039.59 0.11 41.55 2039.58 0.18 N 0.12 W 0.18 0.07 • 2133.74 0.11 16.47 2133.73 0.33 N 0.03 W 0.33 0.05 2226.46 0.11 30.99 2226.45 0.50 N 0.04 E 0.50 0.03 2317.83 0.15 27.01 2317.82 0.68 N 0.14 E 0.68 0.05 2415.91 0.16 3.27 2415.90 0.94 N 0.21 E 0.94 0.07 2505.61 0.03 105.27 2505.60 1.06 N 0.24 E 1.06 0.19 2599.34 0.05 274.87 2599.33 1.06 N 0.22 E 1.06 0.08 2694.68 0.12 25.35 2694.67 1.15 N 0.23 E 1.15 0.15 2788.45 0.02 127.46 2788.44 1.23 N 0.28 E 1.23 0.14 2883.08 0.02 319.16 2883.07 1.23 N 0.29 E 1.23 0.05 2976.59 0.12 299.55 2976.58 1.30 N 0.19 E 1.30 0.11 3071.56 0.06 271.98 3071.55 1.35 N 0.05 E 1.35 0.08 3264.43 0.31 251.12 3264.42 1.18 N 0.54 W 1.18 0.13 3358.43 0.35 208.55 3358.42 0.85 N 0.92 W 0.85 0.26 3453.73 0.35 221.10 3453.71 0.37 N 1.25 W 0.37 0.08 3550.85 0.35 196.97 3550.83 0.13 S 1.53 W -0.13 0.15 3642.42 0.38 224.72 3642.40 0.61 S 1.83 W -0.61 0.19 3734.26 0.55 238.17 3734.24 1.06 S 2.42 W -1.06 0.22 3825.45 0.59 231.35 3825.42 1.58 S 3.16 W -1.58 0.08 3921.46 0.68 231.46 3921.43 2.25 S 3.99 W -2.25 0.10 4018.14 0.71 227.73 4018.10 3.01 S 4.88 W -3.01 0.05 4110.61 0.72 229.96 4110.56 3.77 S 5.75 W -3.77 0.03 4202.96 0.96 217.37 4202.90 4.76 S 6.66 W -4.76 0.32 ID 4295.99 0.96 230.22 4295.92 5.87 S 7.73 W -5.87 0.23 4392.79 1.06 230.44 4392.71 6.96 S 9.05 W -6.96 0.11 El EPOCH CONOCO PHILLIPS ALASKA INC. PUVIAQ #1 • Depth Inclination Azimuth Vertical Northings Eastings Vertical Dogleg Feet Degrees Degrees Depth Feet Feet Section /100ft 4485.02 1.10 238.81 4484.92 7.96 S 10.46 W -7.96 0.18 4572.90 0.29 153.72 4572.79 8.60 S 11.09 W -8.60 1.27 4677.85 0.35 81.87 4677.74 8.79 S 10.66 W -8.79 0.36 4768.55 0.37 112.56 4768.44 8.87 S 10.11 W -8.87 0.21 4861.93 0.25 147.11 4861.82 9.15 S 9.72 W -9.15 0.23 4956.45 0.15 98.76 4956.34 9.35 S 9.48 W -9.35 0.20 5050.03 0.01 13.27 5049.92 9.36 S 9.36 W -9.36 0.16 5143.23 0.01 29.67 5143.12 9.35 S 9.36 W -9.35 0.00 5238.33 0.22 134.79 5238.22 9.47 S 9.22 W -9.47 0.23 5329.63 0.10 351.46 5329.52 9.51 S 9.11 W -9.51 0.34 5423.64 0.10 10.68 5423.53 9.35 S 9.11 W -9.35 0.04 5517.15 0.14 71.15 5517.04 9.23 S 8.98 W -9.23 0.14 5610.40 0.28 96.91 5610.29 9.22 S 8.65 W -9.22 0.17 5704.57 0.29 131.79 5704.46 9.40 S 8.25 W -9.40 0.18 5799.13 0.15 120.73 5799.02 9.62 S 7.97 W -9.62 0.15 5892.08 0.22 125.19 5891.96 9.78 S 7.72 W -9.78 0.08 5986.30 0.13 53.91 5986.18 9.83 S 7.49 W -9.83 0.23 6080.00 0.55 188.49 6079.8810.21 S 7.47 W -10.21 0.70 6171.73 0.27 138.47 6171.61 10.81 S 7.39 W -10.81 0.47 6268.88 0.34 127.67 6268.7611.16 S 7.01 W -11.16 0.09 6364.51 0.39 161.44 6364.3911.64 S 6.68 W -11.64 0.23 • 6454.94 0.45 144.75 6454.82 12.23 S 6.38 W -12.23 0.15 6542.75 0.35 114.95 6542.6212.62 S 5.94 W -12.62 0.26 6644.94 0.28 109.14 6644.81 12.84 S 5.42 W -12.84 0.07 6737.45 0.50 155.23 6737.3213.28 S 5.03 W -13.28 0.40 6831.65 0.48 170.67 6831.5214.04 S 4.80 W -14.04 0.14 6925.21 0.48 185.48 6925.0714.82 S 4.77 W -14.82 0.13 7019.19 0.35 209.51 7019.05 15.46 S 4.95 W -15.46 0.23 7114.49 0.53 219.79 7114.35 16.05 S 5.37 W -16.05 0.21 7213.30 0.46 215.44 7213.15 16.73 S 5.90 W -16.73 0.08 7304.32 0.44 200.13 7304.17 17.36 S 6.23 W -17.36 0.13 7397.20 0.29 209.35 7397.05 17.90 S 6.47 W -17.90 0.17 7491.79 0.29 200.39 7491.64 18.34 S 6.67 W -18.34 0.05 7586.36 0.14 230.41 7586.21 18.64 S 6.85 W -18.64 0.19 7680.84 0.17 214.49 7680.6918.82 S 7.01 W -18.82 0.05 7773.71 0.15 241.27 7773.56 18.99 S 7.20 W -18.99 0.08 7807.86 0.14 320.53 7807.71 18.98 S 7.26 W -18.98 0.54 7900.00 0.14 320.53 7899.85 18.81 S 7.41 W -18.81 0.00 110 I El E 1 1 0 • CONOCO PHILLIPS ALAKSA INC. PUVIAQ #1 DAILY MUD PROPERTIES Date Depth Den. Vis PV YP Gels Fil Cake Solids Sand MBT PH CI Ca 3/08/03 204 10.1 52 16 32 10/12/12 5.4 1 6.5 0.50 3.0 8.7 15000 100 3/09/03 370 10.1 50 14 26 8/11/12 5.3 1 6.6 0.40 3.0 9.4 15000 100 3/09/03 716 10.0 52 13 30 8/10/12 5.0 1 6.8 0.70 5.0 9.3 13500 120 3/10/03 1043 10.1 53 14 25 7/12/15 6.7 1 7.3 2.00 5.0 9.4 14000 130 3/10/03 1358 10.0 49 11 22 6/12/16 5.8 1 7.9 0.75 5.0 9.2 13000 120 3/11/03 1430 10.1 48 11 22 6/12/16 6.0 1 6.0 0.75 7.5 8.8 14000 120 3/11/03 1430 10.2 48 12 21 7/14/18 6.8 1 6.8 0.75 7.5 8.6 15000 80 3/12/03 1430 10.0 48 10 18 6/11/13 7.0 1 6.8 0.75 7.5 8.7 15000 80 3/12/03 1430 10.0 44 10 16 5/9/11 7.0 1 5.7 0.50 5.0 10.4 15000 80 3/13/03 1430 9.8 44 10 16 5/9/11 7.0 1 6.8 0.50 5.0 9.8 15000 80 3/13/03 1430 9.6 46 11 17 6/14/19 6.0 1 4.8 0.25 5.0 11.4 27000 480 3/14/03 1430 9.65 40 11 17 7/12/17 7.5 1 5.6 0.12 5.0 10.9 30000 480 3/14/03 1430 9.6 48 12 21 9/16/21 6.0 1 5.7 0.00 5.0 9.9 29000 320 3/15/03 1430 9.6 50 12 25 9/19/24 6.0 1 5.6 0.10 5.0 9.8 30000 320 3/15/03 1430 9.6 49 13 23 9/17/22 6.0 1 5.6 0.10 5.0 9.9 30000 240 3/16/03 1430 9.6 50 13 23 9/17/22 6.0 1 5.6 0.10 5.0 9.9 30000 240 3/17/03 1430 9.6 50 13 23 9/17/22 6.0 1 5.6 0.10 5.0 9.9 30000 240 3/17/03 1430 9.6 50 14 22 8/16/21 5.6 1 5.6 0.10 5.0 9.7 30000 200 3/18/03 1430 9.6 50 14 22 8/16/22 5.6 1 5.6 0.10 5.0 9.7 30000 200 3/18/03 1450 9.6 50 13 23 7/17/22 6.4 1 5.6 0.10 5.0 9.9 30000 240 3/19/03 1850 9.6 49 13 20 7/14/20 6.0 1 5.8 0.75 6.0 9.6 28000 920 3/19/03 2232 9.7 48 14 18 6/13/20 6.5 1 6.2 1.00 5.0 9.4 29000 440 3/20/03 2605 9.65 50 14 22 9/25/29 5.8 1 5.6 0.30 5.0 8.9 30000 400 3/20/03 2996 9.7 48 14 19 6/25/31 5.2 1 5.8 0.30 5.0 9.1 34000 320 3/21/03 2996 9.7 48 14 19 6/25/31 5.2 1 5.8 0.30 5.0 9.1 34000 320 3/21/03 3175 9.75 51 16 15 5/25/31 5.7 1 6.3 0.30 7.0 9.1 35000 240 3/22/03 3175 9.75 51 16 15 5/25/31 5.7 1 6.3 0.30 7.0 9.1 35000 240 3/22/03 3175 9.75 51 17 19 5/14/25 6.0 1 6.3 0.30 7.0 9.1 35000 240 3/23/03 3175 9.85 50 16 50 5/22/29 6.0 1 7.3 0.30 8.0 9.1 35000 240 3/23/03 3175 9.65 47 16 16 5/29/39 7.0 1 6.1 0.30 7.0 11.9 30000 400 3/24/03 3175 9.5 47 15 15 6/9/16 6.0 1 5.1 0.10 7.0 11.1 30000 400 3/24/03 3175 9.5 47 16 15 4/8/15 6.0 1 5.1 0.10 7.0 11.2 30000 400 3/25/03 3195 9.6 48 16 17 4/14/23 6.0 1 5.5 0.10 7.0 9.6 31000 960 El EPOCH 29 I 4110 • CONOCO PHILLIPS ALAKSA INC. PUVIAQ #1 Date Depth Den. Vis PV YP Gels Fil Cake Solids Sand MBT PH CI Ca 3/25/03 3547 9.55 46 12 13 3/17/23 5.9 2 5.3 0.20 7.5 10.9 27500 580 3/26/03 4110 9.55 49 13 14 3/21/28 5.7 2 5.4 0.15 8.6 10.3 33000 620 3/26.03 4414 9.6 46 11 13 3/18/25 5.7 2 5.9 0.20 7.5 10.1 33500 620 3/27/03 4957 9.6 47 13 13 3/17/22 4.7 2 5.0 0.25 7.5 9.5 31500 520 3/27/03 5193 9.6 52 21 20 6/22/27 3.9 2 4.4 0.25 6.3 9.4 33000 400 3/28/03 5702 9.55 50 15 17 4/21/29 4.1 2 4.7 0.40 7.5 9.2 29000 368 3/28/03 6088 9.6 56 13 16 3/23/28 4.2 2 4.9 0.50 7.5 9.6 32500 320 3/29/03 6267 9.65 55 12 14 3/20/27 4.2 2 4.9 0.40 7.5 9.3 33000 280 3/29/03 6267 9.65 54 13 19 4/20/26 3.7 2 5.3 0.25 7.5 9.0 34000 160 3/30/03 6267 9.6 52 27 22 6/22/24 3.6 2 4.8 0.15 6.3 8.8 34000 168 3/30/03 6267 9.6 53 26 22 5/21/23 3.6 2 5.3 0.15 6.3 9.1 34000 148 3/31/03 6267 9.75 50 13 13 3/16/18 3.2 2 6.2 0.15 6.3 9.1 36000 320 3/31/03 6360 9.55 45 10 10 3/15/17 3.6 2 5.3 0.12 6.3 8.8 34000 260 4/01/03 6710 9.55 44 11 13 5/19/23 4.3 2 5.4 0.12 7.5 9.4 33500 140 4/01/03 6894 9.6 46 13 16 7/22/25 4.5 2 5.6 0.12 7.5 9.8 33000 100 4/02/03 7120 9.65 45 13 13 5/22/23 4.9 2 6.2 0.20 7.5 9.6 29000 100 4/02/03 7120 9.5 42 10 8 3/12/15 5.4 2 6.0 0.12 6.3 9.6 25000 60 4/03/03 7120 9.55 58 29 21 4/19/24 2.6 2 5.0 0.12 6.3 10.0 38500 60 4/03/03 7126 9.65 58 16 14 4/20/22 3.2 2 5.9 0.12 6.3 9.6 33000 60 4/04/03 7156 9.65 49 16 15 3/18/20 3.3 2 5.9 0.12 6.3 9.6 33500 60 4/04/03 7156 9.65 50 14 18 3/18/20 3.2 2 5.9 0.12 6.3 9.6 33500 60 4/05/03 7205 9.65 52 15 14 3/18/20 3.3 2 6.5 0.12 6.3 10.3 32500 48 4/05/03 7223 9.65 53 15 15 3/19/22 3.2 2 6.4 0.12 6.3 9.8 33000 48 4/06/03 7223 9.6 55 15 13 3/13/16 3.5 2 5.9 0.12 6.3 9.9 33500 44 4/06/03 7313 9.7 45 13 11 2/13/16 3.8 2 6.3 0.20 6.3 10.2 34500 48 4/07/03 7313 9.7 54 12 12 2/12/15 3.9 2 6.4 0.20 6.3 9.8 34000 44 4/07/03 7313 9.7 53 14 11 2/11/13 3.6 2 6.8 0.20 6.3 9.8 34500 52 4/08/03 7690 9.55 62 14 22 6/22/27 3.2 2 5.5 0.12 5.0 9.6 38000 60 4/08/03 7900 9.65 53 18 15 3/10/18 3.4 2 5.9 0.12 5.0 9.9 39000 80 El EPOCH 30 CONOCO PHILLIPS ALAKSA INC. PUVIAQ #1 BIT RECORD Bit Grading I C D LB G 0 R N U U CE A T E N T L CA U H A E E L AR G E S R R T I E R 0 C I N N R R H C G C O C A N S H P W V R A U S S R L L E D Bit Size Make Type S/N Jets Depth In Depth Out Drilled Hour Ave Ave Ave Ave No. $ Ft/Hr WOB RPM PSI 1 16.0 STC XT1 MM4 3x20, 113 1430 1317 24.64 70.3 9.0 80 1224 1 2 WT A E 1 NO TD 542 1x14 2 12.25 HTC MXC 5019 3x16, 1430 3175 1745 30.98 76.7 13.1 93 1655 1 1 NO A E 1 NO TD 1 341 1x12 3 8.5 Hyca DS70 2003 6x13 3175 6267 3092 54.06 69.8 4.9 115 1960 2 2 LT N D 1 NO RR log 47R B 4 8.5 Hyca DS70 2009 6x13 6267 7120 853 29.12 41.9 6.4 120 2016 2 2 LT C X 1 NO PR log 74R B 5 8.5 STC MXO 6004 3x18 7120 7156 36 2.04 19.3 17.8 122 1940 1 1 NO A E 1 NO CP 9DX 562 6 8.5 HC ARC 4508 TFA 7156 7313 157 10.49 41.5 18.0 86 623 NG (Cor 425C 510 =0.7 e) S 78 4RR 8.5 Hyca DS70 2009 6x13 7313 7900 587 9.18 72.4 7.1 118 2232 2 2 LT C X 1 NO PR log 74R El B EPOCH 31 • Conoc81 PUVIAQ 1 • CORE PHOTOGRAPHS RESTRICTED CONFIDENTIAL conocoPholips makA, Inc; • t .. . ! ti T"" V" N.• • ti CO r CO r„ T""" N. ,Fi, 00 .. .. . 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