Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-036
e e r~ '" &:' '.. -, , '\;;:.' \" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marker. doc FW: Disclosure of 6 CPAI wells approved t' Subject: FW: Disclosure of 6 CPAI wells approved Date: Thu, 26 Jun 2003 10:16:06 -0800 From: "Jim Cowan" <jc~dnr.state.ak.us> Reply-To: <Jim_Cowan~dnr. state.ak.us> To' <sarah_palin~admin.state.ak.us> CC: <Steve_Davies~admin.state.ak.us>, <Howard_Okland@admin.state.ak.us>, "Mark D. Myers" <mdm~dnr.state.ak.us>, "Bonnie Robson" <br~dnr. state.ak.us> Sarah, Steve and Howard, As follow-up to the message below, CPAI's land manager confirmed today that the only wells subject to appeal are the two Trailblazer wells. The Nigliq 1 & IA, Spark IA, Moose's Tooth C, Rendezvous A & 2 may be disclosed immediately. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 ..... Original Message ..... From: Jim Cowan [~.~.!~..!.J..~.~..~..~.~.~.~.~..~..~..~..~.~] Sent: Wednesday, June 25, 2003 4:05 PM To: sarah~alin@admin.state.ak.us Cc: Steve Davies@admin.state.ak.us; Howard Okland@admin.state.ak.us Subject: Disclosure of CPAI Trailblazer A-1 & H-1 wells appealed Sarah, Steve and Howard, The DNR received the anticipated appeal from ConocoPhillips regarding the Division of Oil & Gas' denial of extended confidentiality for data from the Trailblazer A1 & Hi wells (NPR-A). That denial was issued on June 5, but release was delayed until tomorrow, June 26, so CPAI could utilize the 20-day notice-of-appeal period to formulate its position. The AOGCC is copied on the appeal letter and may have already have reached you. Consequently, we ask that you do not disclose confidential information and data from these two wells until we notify you that the appeal process is complete. Appeals of the similar denials for the other six wells are also due today, but have not yet been received. If we hear nothing more from CPAI I'll notify you in the morning that you may proceed with their release effective tomorrow, June 26. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS FRANK H. MURKOWSKI GO VERNOtt 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE:(907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL #7002 0860 0003 3538 7846 RETURN RECE2T REQUESTED June 5, 2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR RECEIVED Re: Request for extended confidentiality Nigliq 1 and lA Wells JUN 0 9 2003 Alaska Dil & Gas Cons. Commission Anchorage Dear Mr. Mott: I am responding to your April 10, 2003, letter to Commissioner Irwin in which you requested, on behalf of ConocoPhillips Alaska, Inc. (CPAI) and the working interest owners, extended confidentiality under 11 A_AC 83.153 for the Nigliq 1 and Nigliq lA well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission (AOGCC). Originally scheduled for release on April 21 and April 30, 2003, respectively, the Division of Oil and Gas (Division) temporarily extended the confidentiality of this well infom~ation until June 6, 2003, to allow CPAI to make a showing that the information is significant for the valuation of unleased land more than three miles from the wells. CPAI presented the information to the Division on May 29, 2003. CPAI requested that the well data be granted extended confidentiality through at least December 31, 2003, on the premise that the information is significant for evaluation of state lease ADL 390348 (currently leased and due to expire September 30, 2003) and unleased federal submerged blocks approximately six miles to the north (tentatively scheduled to be offered for leasing in September 2003). All currently unleased lands are more than three miles from the Nigliq 1 and Nigliq 1A wells. As you know, 11 AAC 83.153(a) provides that the commissioner may extend confidentiality for well information if the well is located more than three miles from unleased lands. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or "Develop, Conserve, attd Enhance Natural Resources for Present attd Future Alaskans." information required under AS 31.05.035fi'om a well located more than three miles fi'om any unleased land if the owner of the well fi'om which these reports or information are derived makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three-mile radius." Having considered the information provided by CPAI, the request for extended confidentiality is denied. Reasons for doing so include, but are not limited to: · The information derived from the Nigliq 1 and Nigliq lA wells does not contain significant information relating to the valuation of ADL 390348 (currently leased).or the unleased federal submerged lands five and more miles from the Nigliq 1A location. Information derived from the nearby Fiord, Temptation, and Nechelik wells is already in the public domain and discloses subsurface information relating to the valuation of the nearby unleased lands. By copy of this letter I am advising the AOGCC to release reports and information from the Nigliq 1 and Nigliq lA wells on Friday, June 6, 2003, upon expiration of the previously granted temporary 45- day extension. 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(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, 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_app.eals(~,dnr.state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31St day after issuance. 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, Mark D. Myers Director Cc: Sarah Palin, Commission Chair, AOGCC Jeff Landry, Department of Law Mike Kotowski Jim Cowan FRANK H. MURKOWSKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS CERTIFIED MAIL #7002 0860 0003 3538 7778 RETURN RECEIPT REQUESTED 550 WEST 7TM A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE:(907) 269-8800 FAX: (907) 269-8938 April 21, 2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR Re' Requests for Extension of Confidentiality under 11 AAC 83.153 Nigliq 1 Nigliq lA Trailblazer A-1 Trailblazer H- 1 Spark lA Moose's Tooth C Rendezvous A Rendezvous 2 50103203700000 50103203700100 501032036400 501032036900 501032031301 501032031500 501032031600 501032036300 I am responding to your letters of April 9 and 10, 2003, requesting extended confidentiality under 11 AAC 83.153 for well data, reports and information generated from the eight referenced wells and filed with the Alaska Oil and Gas Conservation Division (AOGCC) under AS 31.05.035. For wells more than three miles from unleased land, as is the case here, 11 AAC 83.153(a) grants the commissioner discretionary authority. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05.035 from a well located more than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three-mile radius." Inasmuch as all wells are more than three miles from unleased lands, confidentiality for the eight referenced wells is extended for only 45 days from this date (through June 5, 2003) during which time the Division of Oil and Gas will require a showing to establish the significance of well data from the referenced wells to unleased OCS and NPR-A lands and to state lease ADL 390348 which is due to "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." expire September 30, 2003. The showing should be scheduled prior to May 30, 2003, to allow the Division to make a decision by June 5, 2003, regarding further extension of the confidentiality period. Extended confidentiality for the remaining four wells for which you requested extended confidentiality (Hunter A, 501032040500; Lookout 1, 501032035900; Lookout 2, 501032041000; and Mitre 1, 501032040900) will be reviewed prior to their 2004 disclosure dates. Please submit that request on or about March 26, 2004, so that the significance of the well information can be evaluated in the context of activities up to that time. By copy of this letter I am notifying the AOGCC of the 30-day extension of confidentiality for the eight referenced wells. 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(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, 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~dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31st day after issuance. 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. Mark D. Myers Director Cc.' Sarah H Palin, Commission Chair, AOGCC Jeff Landry, Department of Law J. R. Cowan, Division of Oil and Gas Permit to Drill 2010360 DATA SUBMITTAL COMPLIANCE REPORT 3126/2003 Well Name/No. NIGLIQ 1 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-Z0370-00-00 MD 8040 TVD 7875 Completion Dat 3/21/2001 Completion Statu P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log N__~o Sample No Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type M~dia Fmt (data taken from Logs Podion of Master Well Data Maint) C C C C R R Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number 10047 ~also 10048) FINAL 954 ~-80'4'0 oh ~---5/10/2001 10048~so 10047) FINAL 10049 ~ FINAL Core Analysis FINAL ~ 5 FINAL ~ Vision RES 2/5 FINAL f..p..,~X~-C o m p e n s at e d 2/5 FINAL NEU/DEN namtar Formation 5 FINAL ics Tes ~J~T~n RES 2/5 FINAL '-B~le Sonic Imager 2/5 FINAL ~ Array 2 FINAL ~D~r~ctional Survey FINAL ~tional Data FINAL core Report""~ FINAL /,~C..~ R L't ~-~w"-- /,¢.~-~"2 FINAL Comments 954-8040 Digital Data 954 8040 oh 5/10/2001 120 8040 oh 5/10/2001 oh 8/8/2001 1195 8010 Open 5/9/2001 120 8040 Open 5/9/2001 954 8040 Open 5/9/2001 994 8040 Open 5/9/2001 6039 7550 Open 5/9/2001 2038 8040 ch 5/10/2001 117 8003 ch 5/10/2001 2038 8040 ch 5/10/2001 6122 7317 ch 5/10/2001 117 8003 ch 5/10/2001 2038 8040 ch 5/10/2001 2038 8040 ch 5/10/2001 ch 5/10/2001 ch 5/10/2001 ch 5/10/2001 7145 7550 ch 5/10/2001 950 8040 ch 5/10/2001 954-8040 Digital Data ~ 10049 ,.~-8040 ~ ~j,/p ~? i(..~ Core Analysis Report 10050&.4'~5-8010 ~ ~ .~'~ ~1~-8040 l w c~'~,~'MI/ ~- 1OO49 10047c'~-54-80 0. ' ---/, . 10048 "'~4-8040 10051 6c'~039_7550 Co m~':~' ~ J' 2038-8040 BL, Sepia 117-8003 BL, Sepia 2038-8040 BL, Sepia 6122-7317 BL, Sepia 117-8003 BL, Sepia 2038-8040 BL, Sepia 2038-8040 BL, Sepia Directional Survey Paper Copy Directional Data Digital Data Core Report 7145-7550 Color Print 950-8040 Color Print DATA SUBMITTAL COMPLIANCE REPORT 312612003 Permitto Drill 2010360 Well Name/No. NIGLIQ 1 Operator CONOCOPHILLIPS ALASKA INC MD 8040 'I-VD 7875 Completion Dat 3/21/2001 Well Cores/Samples Information: Name Completion Statu P&A ~ 16A~6 Interval Start Stop Sent Received Current Status P&A Dataset Number Comments Cuttings 120 8O40 APl No. 50-103-20370-00-00 UIC N ADDITIONAL INFORMATION Well Cored? ~' / N Chips Received? ~ N Analysis Y / N RP.c.~.ived ? Daily History Received? (~/N Formation Tops (~/N Comments: Compliance Reviewed By: Date: ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O.Taylor, Chair DATE: August 12, 2001 THRU: Tom Maunder, P .1. Su pervisor SUBJECT: Location Clearance Inspection Niqliq#1 f i ~ Phillips Alaska Inc. PTD~ ~Ö\'-Q~~ ~a \-a (0 \ Sunday. AUÇlust 12, 2001; I made a Location Inspection on Phillip's Plug and Abandoned well "Niqliq #1". FROM: Lou Grimaldi, Petroleum Inspector This exploratory location was clean with no evidence of drilling activity other than a rather tall mound of gravel and dirt over the cellar area. I spoke with Rick Overstreet about this and explained that the intent is to bring the area back to a natural state and this mound was too high (5-6 feet). It is possible that some snow and ice may have been pushed in with the gravel. This should subside over the next couple years but if not may indicate something other than the original gravel being placed there. A return visit in the future is warranted. SUMMARY: I made a Location Inspection on Phillip's Plug and Abandoned Exploratory well "Niqliq #1". Attachments: Niqliq mound 8-12-01 LG.jpg Niqliq mound 2 8-12-01 LG.jpg Niqliq Airshot 8-12-01 LG.jpg cc: Overstreet/Morrison (Phillip's Alaska Inc.) NON-CONFIDENTIAL SCANNED NO\1 {} 12005 010812-Location Clearence Inspection Niqliq 1-LG.doc 5!Æii7.i~.¥~e~" ..M...f-.... ) ) ) ) A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, ATO1486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Nigliq 1 & lA DATE: 08/07/2001 Lisa Weepie State of Alaska - AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Nigliq 1 501032037000 & Nigliq lA (501032037001) Report o~Ot-o~ ~ o~ Or-- ~t U/Core Labs Core Analysis - Nigliq 1; CL file 57111-01077; 06/11/01 '~Core Labs Core Analysis - Nigliq lA; CL file 57111-01111; 07/16/01 w/3.5" disk (digital data) Log Data CD ROM "'Schlumberger -Open hole edits DSI and CMR Nigliq lA; LDWG format; logged 3/26/01; .1OB 21170 Log Data sepias and 1 blue#ne print each 5chlumberger - CMR-TLC; log date 3/26/01 hlumberger Dipole Sonic Imager, log date 3/26/01 ~Schlumberger MDT (Modular Formation Dynamics Tester), log date 3/26/01 P/ease check off each item as received, sign and return one copy of the transmittal to address be/ow, The other copy is for your records. All data to be held confidential until State of Alaska designated release date (AOGCC) Approx 4/2003 CC: Rick Lev~nsgj% PAI Geologist Receipt:~_j~,,~~r~_ Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, Al( 99501 Date: Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases RECEIVED AUG 0 8 2001 Ala~a Oil & Gas Cons. CommissiOn ,~c~a~e - C-~i~G = LO~%mrON Sta~a cf Alaska ...... -:er-2 i::e.~-vala - =--Ds: Review ~he well file, a.nd' c~mmen: on pluqcjing, well head' s:a:u~an~ !oca,~:n c!ea~ca - prcv~e loc'. clear, co~e. ,¢ · · PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 June 4,2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Nigliq #1 and Nigliq #IA (201-036 / 301-062 and 201-061) Completion Report Dear Ms. Commissioner: Phillips Alaska, Inc., as operator of the Nigliq #1 and Nigliq #IA exploration wells, submits the attached "Well Completion Report" (AOGCC form 10-407). Other attachments to the completion report include the directional survey, report of daily well operations, an as-built, and a memo of geological tops. We will send under separate cover the logs, the mud logs, the core description and other well data and reports. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader PAI Drilling GCA/skad STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o! well Oil Classification of Service Well Gas D Suspended [] Abandoned [~] Service O 7. Permit Number 201-036 / 301-062 8. APl Number 50-103-20370-00 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 210' FSL, 1170' FWL, Sec. 2, T12N, R4E, UM (ASP: 369592, 6003006) At Top Producing Interval 1009' FSL, 328' FWL, Sec. 2, T12N, R4E, UM (ASP: 368762, 6003820) At Total Depth 1011' FSL, 337' FWL, Sec. 2, T12N, R4E, UM (ASP: 368771, 6003822) 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 43 DF' RKB / Pad 15' I ADL 380092 / 388525 9. Unit or Lease Name N/A 10. Well Number Nigliq #1 1. Field and Pool Exploration 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore March 5, 2001 I March 14, 2001 I March 21, 2001 (P&A'd) I N/A feet MSL 17. Total Depth (MD + TVD) 118. Plug Back Depth (MD + TVD) 119. Directional Survey 120. Depth where SSSV set 8040' MD / 7875' TVD I 2050' MD / 2036' TVD lYES I~! No E]I N/A feet MD 22. Type Electric or Other Logs Run MWD/LWD with(ARCS-GR/Res), PEX(MCFL/CNLFFLD/GR/AITH), CSI, DSI, MDT 16. No. of Completions 0 21. Thickness of Permafrost 23. CASING SIZE WT. PER FT. GRADE 16" 62.5# H-40 9.625" 36# J-55 24. Perforations open to Production (MD + TVD of Tc interval, size and number) None CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 117' Surface 2036' HOLE SIZE CEMENTING RECORD 24" 285 sx AS I 12-1/4" 318 sx AS III & 233 sx Class G Plu~ #1: 8040'-6940' Plug #2: 4600'-3770' Plug #3: 2587'-2050' and Bottom and 25. TUBING RECORD AMOUNT PULLED SIZE DEPTH SET (MD) N/A N/A 26. PACKER SET (MD) N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug 1: 8040'-6940' 400 sx 15.8 ppg Class G cement Plug 2: 4600'-3770' 345 sx 15.8 ppg Class G cement Plug 3: 2587'-2050' 275 sx 17 ppg Class G cement 27. Date First Production N/A Date of Test N/A Flow Tubing Press. 28. Hours Tested Casing Pressure PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) Plugged & Abandoned Production for OIL-BBL GAS-MCF Test Period > Calculated OIL-BBL GAS-MCF 24-Hour Rate > WATER-BBL WATER-BBL ICHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - APl (corr) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. To be sent under separate cover letter RECEIVED (.,,o 2001 A~chcrsce Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate 29. ~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted under separate cover See Attachment 31. LIST OF ATTACHMENTS Summary of Operations, Directional Survey, As-Built, Geological Markers 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed..,~X'~ ..,~ . __ ~_- Title Alpine Drlllln,q Team Leader Date G. C. Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ' Item 28: If no cores taken, indicate "none". ~ I! C 'EI'V E L'~ ~.:, ,~ L_ ~ ~ ~ Fo~ 10-407 ORIGINAL. Formation Tops 9 5/8 casing point C-40 C-30 C-20 K-3 Marker K-2 Marker HRZ Base HRZ K-1 Marker Kuparuk D shale Kuparuk C Lower Cretaceous Unconform Nechelik J-3 Marker Drillers TD Nigliq #1 Measured Depth 2O46 2277 2505 2876 3872 4283 6530 7037 7078 7138 7171 7176 7252 7890 8040 OR G, IN/ L. RESERVOIR OPTIMIZATION CORE LABORATORIES CORE ANALYSIS REPORT PHILLIPS PETROLEUM CO. NIGLIQ #1 WELL COLVILLE DELTA UMIAT MERIDIAN, ALASKA CL FILE 57111-01077 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (SOS) a~2-8~oo Report Presented ll-June-O1 INTRODUCTION Phillips Petroleum Company selected Core Laboratories to provide field handling and analytical services for cores recovered from the subject well. Core Laboratories personnel handled the core in the field and prepared it for shipment to our laboratory in Anchorage. Services provided at the Anchorage facility included core gamma surface log, core sampling, slabbing, and photography. Drilled sample plugs were forwarded to Core Laboratories' Bakersfield location for analysis. Standard porosity, permeability and fluid saturation determinations were performed on all horizontally oriented samples. Vertically oriented samples were tested for permeability only. Presented herein are the results of the analysis performed in Bakersfield with a brief description Of the requested procedures and tests. In conjunction with the report, the core analysis results are supplied in Excel format on floppy diskette. We appreciate this opportunity to be of service and hope these data prove beneficial in the development of this reservoir. DESCRIPTION OF SERVICES Sample Preparation Samples were received wrapped with Saran and foil and sealed in plastic sample jars. Upon receipt, each sample was weighed and its weight compared to that recorded in Anchorage prior to shipping. The samples were then unwrapped, labeled, and reweighed. If the samples appeared fragile they were mounted in thin-walled metal jackets with 120-mesh stainless steel end-screens installed on each to prevent sample loss. The sleeves and jackets were seated under hydrostatic loading at 1000 psig Fluid Extraction Water and the oil were removed from the samples by Dean Stark methods using toluene as the solvent. Dean Stark extraction was performed for a minimum of sixteen hours, and was terminated when the volume of water collected in each sample's receiving tube had stabilized. Complete hydrocarbon extraction was accomplished using soxhlet extractors with a 70:30 methylene chloride/methanol mixture as solvent. Fully cleaned samples were taken from the soxhlets and placed in a convection oven at 230°F to drive off residual solvent. After a minimum of twelve hours the extracted samples were removed from the convection oven and cooled to laboratory temperature in a desiccator. Grain Density Determinations Grain volumes were determined by Boyle's Law double-cell methods using an extended range helium porosimeter. Where applicable, metal jacket and end-screen weight and volume corrections were applied. Grain density values were calculated using Equation 1. (~ma Mg = (1) Vg Where: (~ma = Matrix (grain) density (g/cc) Grain mass (g) Grain volume (cc) Porosity Determination (Jacketed Samples) Direct pore volume measurements also by Boyle's Law double-cell methods were performed upon samples confined at 400 psig in Hassler-type core holders. Porosity values were calculated using Equation 2. = rL J I/F~P'~ i1.100+V~ (2) Where: Vp Vg = Porosity (%) = Pore volume (cc) = Grain volume (cc) Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 3 and 4. So = .lOO (3) Sw = [-~7] ' 1 oo (4) Where: So Sw Mf Md = Oil saturation (%) Mw =. Water saturation (%) Vw = Fresh sample mass (g) (50 = Clean, dry sample mass (g) Vp = Water mass (g) = Water volume (cc) = Density of oil = Pore volume (cc) Permeability to Air Permeability determinations were made on the jacketed samples following pore volume determinations. Permeability values for the un-jacketed samples were estimated. Permeability values of sleeved samples were calculated utilizing Darcy's Equation for compressible fluids, Equation 5. ~;~ J L ~ (s) Where: Ka = Pa = vg = Ap = ? = Qa = L = Vb = Permeability to air (md) Atmospheric pressure Gas viscosity (cp) Differential pressure Mean pressure Flow rate (cc/sec) Length (cra) Bulk volume (cc) Sample Disposition Sample plugs to be returned to Phillips Petroleum in Anchorage under separate cOver as per Phillips' instructions. Phillips Petroleum Co. "Nigliq" 1 Colville Delta* CORE ANALYSIS RESULTS File No. : 57111-01077 Loc.: Sec. 2.T12NIR4E APl No.: 50.103-20370 7244.0 - 7425.0 Core # 1 Cut 180' Recovered 1 7244.2 1,191 0.191 15.2 28.7 49.6 78,3 0.58 2.68 2 7245.2 0.308 0,263 12,9 28,5 56,7 85,2 0.50 2.67 3 7246,2 0.499 0.241 13,4 30.9 56.2 87.1 0,55 2.67 4 7247.2 4.239 0.094 17.0 44,4 40,9 85,3 1.09 3102 5 7248.2 6,419 6.328 17.3 42.7 34.5 77,2 1.24 2.67 6 7249.2 0.836 0.699 13.4 29.3 52,2 81.5 0.56 2.67 7 7250.2 5,160 2.889 9,5 52,9 28,8 81,7 1.84 3,03 8 7251.2 12.264 0.347 15.7 40.0 33,0 73,0 1,21 2.68 9 7252,3 8.938 1.392 15.7 30,6 44.8 75.4 0.68 2.67 10 7253,2 28,030 9,261 18.0 40.8 33.8 74.6 1.21 2.65 11 7254.2 8.232 2.815 15,9 38.6 32.8 71.4 1.18 2.68 12 7255,2 24,518 3.292 17,8 47.9 23,2 71.1 2.08 2.66 13 7256.2 9.743 0.578 16.4 38,7 33.5 72,2 1,16 2.66 14 7257.2 34.476 1.602 18,1 39.6 30.1 69.7 1,32 2.66 15 7258,2 0,718 0,443 13,6 31.8 45.0 76.8 0.71 2.67 t6 7259,2 39.670 1,198 18.3 42.2 31.0 73,2 1.36 2.68 17 7260.2 86.508 16.881 19.9 46,0 23.0 69,0 2.00 2.68 18 7261.2 1.409 0.216 16.1 51.4 28.5 79,9 1.80 2.73 19 7262.2 3,888 0.510 15.1 50.3 27.0 77,3 1,86 2.67 20 7263.2 39.935 1.702 18,1 40.2 31,5 71.7 1.28 2.66 21 7264,3 6.778 1.141 15,6 43.0 32.1 75,1 1.34 2.72 22 7265.2 81.838 18.938 19.1 45.0 29.1 74.1 1.55 2.67 23 7266.2 2.356 1,141 14.1 42,0 35.6 77.6 1.18 2.66 24 7267,2 15.040 5.462 16.5 36.9 26.0 62,9 1.42 2.66 25 7268.2 41.442 23.757 t7,9 44.4 29.5 73.9 1.51 2.66 26 7Z69,2 31.217 2.840 17.5 37.9 34.2 72.1 1.11 2.68 27 7270.2 60,432 11.085 19,4 50.8 20.3 71.1 2.50 2.69 181' Sst bm vfgr ~y soak= m stn gld flu Sst bm vfgr sity soak= m sin gld flu Sst bm vfgr airy s~alo dk stn gtd flu Sst bm vfgr vslty pyr dk sin gld flu Sst dk bm vfgr sslty scak= dk sin dgld flu Sst bm vfgr slty scalc dk sin dgld flu Sst bm vfgr slty pyr dk sin dgtd flu ,Sst brn vfgr sslty dk sin rigid flu Sst bm vfgr slty scale dk sin dgld flu Sst bm vfgr sstty dk sin dgld flu Sst bm vfgr slty dk sin dgld flu Sst brn vfgr sslty dk sin dgld flu Sst bm vfgr slty dk stn dgld flu SSt bm vfgr sslty dk sin dgld flu Sst bm vfgr slty soak= dk sin dgld flu Sst brn vfgr sslty scal¢= dk sin dgld flu Sst bm vfgr slty carb lam dk sin dgtd flu Sst bm vfgr ~ vcalc m sin dg~d flu Sst bm vfgr sity scale dk sin dgid flu SSt bm vfgr sslty dk stn dgld flu SSt bm vfgr slty oak= dk sln dgld flu Sst bm vfgr sslty sc, ak= dk sin dgld flu SSt bm vfgr vslty dk ~n dgld flu Sst bm vfgr sstty dk sin dgld flu Sst bm vfgr sslty dk sin dgld flu Sst bm vfgr sslty soak= dk sin rigid flu Sst brn vfgr salty scale dk stn dgld flu f frao Phillips Petroleum Co, "Nigliq" 1 Colville Delta- File No. : 57111.01077 Loc,: Sec, 2-TI2NIR4E APl No,: $0-103-20370 CORE ANALYSIS RESULTS 28 7271.2 3.214 3.060 14.2 38.1 40.2 78.3 0.95 2.71 29 7272.1 22.461 1.950 17.2 41.2 27,9 69.1 1.48 2.70 30 7273.1 0.487 0.010 11.4 32.1 45.4 77.5 0.71 2.72 31 7274,9 0.343 0.112 10.8 31,7 44.7 76.4 0.71 2.71 32 7275.1 1.756 0.657 14.0 36.9 40.7 77.6 0.91 2:70 33 7276.1 1.266 0,509 22,4 48,4 33,8 82.2 1.43 2.78 34 7277.1 2.887 0.102 15,6 38,4 37,9 74,3 0.96 2,71 35 7278.1 0,940 0.544 13,4 34,9 45,7 80,6 0,76 2.69 36 7279,1 1.238 0.414 12,8 33,1 50.7 83,8 0.65 2.69 37 7280.1 1.245 .0.559 13.3 36,0 46.2 82.2 0.78 2.71 38 7281,1 1.352 0,448 13.8 34,8 42.8 77.6 0,81 2.71 39 7282,1 1.285 0,371 12.4 29.1 54.9 84.0 0.53 2.67 40 7283,1 16.174 1,306 17.1 39.6 28.5 68.t 1.39 2,67 41 7284.1 13.449 0.353 16,1 39.6 33,4 73.0 1.19 2.68 42 7285,1 1.354 0.278 13.7 37.0 44.7 81.7 0.83 2.68 43 7286,1 1,944 0,485 14,6 35.4 43,3 78.7 0.82 2,68 44 7287,1 1.720 0,159 14,4 39,4 39.6 79.0 0.99 2,67 45 7288.3 1.579 0.521 14.1 38.8 41,6 80.4 0.93 2,67 46 7289,1 2,219 0,355 14.4 35,4 42,2 77,6 0.84 2.67 47 7290,1 1.39~ 0.260 13,2 35,8 44,9 80,7 0.80 2,67 48 7291.1 1.250 0.649 14,2 38,4 42,7 81.1 0.90 2.66 49 7292,1 0.509 0.147 12,8 32,9 49,5 82,4 0,66 2.68 50 7293,1 0.825 0.097 14.3 29.3 44.6 73,9 0.66 2,67 51 7294.1 0,852 0.138 14.1 35.8 46.0 81.8 0.78 2.68 52 7295,1 1,113 0.156 14,1 37,8 45,4 83.2 0.83 2.67 53 7296.2 1,575 0,338 14.6 42.2 41.7 83.9 1.01 2.67 54 7297.2 0.331 0.256 14.3 37.9 48.2 86.1 0.79 2.68 55 7298.2 0.400 0.181 13.4 35.1 50,8 85.9 0,69 2.67 56 7299,2 1,320 0:221 14.7 37.2 43,8 80.8 0.85 2.66 SSt bm vfgr slty c, al(= dk stn dgld flu Sst bm vfgr sstty calc dk stn rigid flu Sst brn vfgr vsity calc dk sin dgld flu SSt bm vfgr vslty calc m stn dgld flu Sst bm vfgr stty cai(= dk stn dgld flu Sst bm vfgr vslty vcal(= dk stn dgld flu Sst bm vfgr slty (=al(= dk stn dgld flu 8st bm vfgr slty scale dk stn dgld flu Sst bm vfgr airy scale dk stn dgld flu SSt bm vfgr slty cal= dk stn dgld flu Sst bm vfgr sity cal~ dk stn dgld flu Sst bm vfgr vslty s4~alc dk stn dgld flu SSt bm vfgr sslty scale dk stn dgld flu SSt bm vfgr sslty scalc dk stn dgld flu Sst bm vfgr slty scalc dk stn dgld flu Sst bm vfgr slty scal(= dk stn dgld flu Sst bm vfgr slty scale dk stn dgld flu Sst brn vfgr slty scalc dk stn dgld flu Sst bm vfgr slty scalc dk stn dgld flu Sst bm vfgr slty scalc dk sln dgld flu Sst bm vfgr slty dk stn dgld flu Sst bm vfgr slty scalc dk stn dgld flu Sst bm vfgr slty $cal(= dk stn dgld flu Sst bm vfgr slty s(=alc dk stn dgld flu Sst bm vfgr airy seal= dk stn dgld flu Sst bm vfgr slty scale dk stn dgld flu Sst bm vfgr 81ty 8Gale dk stn dgld flu Sst bm vfgr slty ~calc dk stn dgld flu SSt bm vfgr slty dk stn dgld flu Phillips Petroleum Co. "Nigliq" 1 Colville Delta- File No. : 57111-01077 Loc.: Sec. 2-T12NIR4E APl No.: 50-103-20370 CORE ANALYSIS RESULTS 57 7300.2 0.466 0,126 13,5 34,3 51.8 86.1 0.66 2,68 58 7301,3 0,799 0.182 14.7 35.1 46.0 81,1 0.76 2,66 59 7302.2 0,458 0.206 13,1 38,4 48.1 86,5 0.80 2,66 60 7303.1 0.201 0,163 13.5 29.1 51.1 80,2 0.57 2,68 61 7304.7 1.066 0~18 14,9 34.3 43.8 78.1 0.78 2:67 62 7305.1 1,540 0,119 14,4 34.7 45,1 79.8 0.77 2.68 63 7306.6 0.588 0,138 13.6 27,7 51,8 79.5 0.53 2.67 64 7307.2 0~77 0.121 13,0 44.4 41,6 88,0 1.07 2.69 65 7308,1 0.721 0,204 14,5 33.4 44.0 77,4 0,76 2.68 66 7309,1 0,351 0.127 13.6 28.2 51.9 80,1 0,54 2.68 67 7310,1 0.563 0.197 14.2 42,0 38.8 80.8 1.08 2.68 68 7311.1 1.708 0,163 15,6 32,6 44.5 77.1 0.73 2.88 69 7312.2 0,539 0.158 14.4 30,5 49,4 79,9 0.62 2,67 70 7313,2 0.253 0.121 13.2 32.0 49,9 81.9 0,64 2.69 71 7314.2 0.269 0.087 13.1 48.6 36.0 84.6 1,35 2.68 72 7315.9 0,645 0.088 14,4 34.0 44.3 78,3 0.77 2.68 73 7316.2 0.183 0,081 12.9 33,8 53,2 87.0 0,64 2.69 74 7317.2 0.179 0,087 12,7 32~ 52.7 84,9 0.61 2.68 75 7318.2 0.405 0.116 14.0 40.6 38.7 79.3 1,05 2.66 76 7319,2 0.506 0.154 t3,9 44.3 42.5 86.8 1.04 2.67 77 7320,3 0.361 0.151 13.8 33.6 53,0 86.6 0.63 2.67 78 7321.7 0.224 0.119 12.4 30.5 59.1 89,6 0.52 2.67 79 7322.3 0.198 0,113 11.6 23.0 67.7 90,7 0.34 2.66 80 7323.2 0,171 0,103 12.0 28,7 60.0 88,7 0.48 2,67 81 7324,7 0.175 0.093 12.2 25,3 61.0 86,3 0.41 2,68 82 7325,2 0.264 0.108 11,9 25.8 63.2 89.0 0.41 2,68 83 7326,7 0,311 0,116 12.5 47,0 47,3 94,3 0,99 2,68 84 7327.7 0,415 0,159 13.8 31.7 49.4 81,1 0.64 2.67 85 7328.3 0.234 0,171 13.5 38,9 -45.8 84,7 0.85 2.68 SSt bm vfgr slty scale dk stn dgld flu Sst bm vfgr sity dk stn dgld flu Sst bm vfgr slty dk stn dgld flu SSt bm vfgr vslty scalo m stn rigid flu Sst bm vfgr slty scale dk sin dgld flu Sst bm vfgr slty scale dk stn dgld flu Sst bm vfgr slty scab3 dk stn dgld flu Sst bm vfgr sity scale dk stn dgld flu SSt brn vfgr sity scale dk stn dgld flu Sst bm vfgr vslty scale dk stn dgld flu Sst bm vfgr slty scalo dk stn dgld flu Sst bm vfgr slty scalo dk sln dgld flu SSt bm vfgr slty scal~ dk stn dgld flu Sst bm vfgr slty scale dk stn dgld flu Sst bm vfgr slty scale dk stn dgld flu Sst bm vfgr aity scal~ dk stn dgld flu Sst bm vfgr vslty scale m stn dgld flu Sst bm vfgr vslty scale m stn rigid flu Sst bm vfgr slty dk stn dgtd flu SSt bm vfgr city ;calo dk stn dgld flu SSt bm vfgr slty scalo dk stn dgld flu Sst bm vfgr vsity soalc m stn rigid flu Sst It bm vfgr vslty m stn rigid flu Sst brn vfgr vslty scale m stn dgld flu Sst brn vfgr vslty scale m stn rigid flu Sst bm vfgr vslty scale m stn dgld flu Sat It bm vfgr vslty sh scale m stn dgtd flu Sat bm vfgr slty scale dk stn dgld flu Sat bm vfgr vs~ scale dk stn rigid flu Phillips Petroleum Co. 'Nigliq" 1 Colville Delta File No. : 57111-01077 Loc.: Sec. 2-T12NIR4E APl No.: $0-103-20370 CORE ANALYSIS RESULTS 86 7329.1 0.209 0,101 13.6 32.6 52.8 85.4 0,62 2.68 87 7330,1 0.333 0.128 14.2 39.3 45.1 84.4 0.87 2.67 88 7334,4 0.140 0.106 12.2 19.4 66,1 85.5 0.29 2.67 89 7335.3 0,167 0.090 11.5 28.8 60.9 89.7 0.47 2.67 90 7336.3 0.241 0,104 12.5 31.6 54.8 86.4 0.58 2.67 91 7337.2 0.142 0.101 13.0 30.4 52.9 83.3 0.57 2.67 92 7338.2 0.171 0.082 12.6 30.2 53,0 83.2 0,57 2.66 93 7339.2 0.158 0,143 12.0 28.1 59.7 87.8 0,47 2,67 94 7340.2 0.174 0,081 t 1.2 20.2 70.2 90.4 0.29 2,68 95 7341.2 0.241 0.139 11.1 22.6 72,0 94.6 0.31 2.67 95 7342.2 0,134 0.075 10.5 19.0 75.7 94.7 0,25 2.67 97 7343.2 0.196 0.069 12.1 26.0 59.0 85.0 0.44 2.67 98 7344,2 0,104 0.071 10.7 32.1 59.7 91.8 0.54 2,66 99 7345,3 0.195 0,110 13.5 30.3 50.0 80.3 0,61 2,66 100 7346.2 0.161 0.123 12.2 30.3 54.8 85.1 0.55 2,66 101 7347.3 0.206 0.093 9.9 36.1 62,3 98.4 0,58 2.66 102 7348,3 0.144 0,055 10.9 18.7 70.6 89.3 0,26 2.66 103 7349,3 0.117 0,095 11.9 37.9 50.8 88.7 0.75 2.67 104 7350,2 0.141 0.074 9.9 34.8 63.7 98,5 0.55 2.67 105 7351.2 0.196 0.047 10.1 31.3 65.0 96.3 0.48 2.67 106 7352.2 0.143 0.044 10.5 30.8 59.3 90. t 0.52 2.67 107 7353,2 0.113 0.039 10.3 17.9 74.0 91.9 0,24 2,67 108 7354.3 0,120 0.074 10.8 24.9 67.6 92.5 0.37 2,66 109 7355.4 0.115 0.064 11.7 25.5 63.4 88.9 0.40 2.66 110 7356,2 0. t71 0.065 10.0 20.4 79.2 99.6 0,26 2.66 111 7357,2 0,094 0.038 11.5 27.1 62.4 89.5 0.43 2.66 112 7;356,2 0.100 0.057 10,1 18.3 76.4 94.7 0,24 2.66 113 7359,2 0.200 0.050 9.4 17.0 82.1 99.1 0.21 2,67 114 7360.3 0.217 0.064 9.3 22.0 77.1 99.1 0.29 2.70 SSt bm vfgr vslty scalc dk sin dgld flu SSt bm vfgr vslty soalc dk sin dgld flu Sst bm vfgr vslty scalc m stn dgld flu Sst bm vfgr vslty $calc m sin rigid flu SSt bm vfgr vslty scalc m stn rigid flu Sst bm vfgr vslty scalc dk-m sin dgld flu Sst bm vfgr vslty dk-m stn dgld flu SSt brn vfgr vslty scalc dk-m sin dgld flu SSt bm vfgr vslty scalc m sin dgld flu Sst bm vfgr vslty scalc m sin dgld flu SSt It bm vfgr vslty s~alc m stn dgld flu Sst bm vfgr vslty scalc m sin rigid flu Sst bm vfgr vslty m sin dgtd flu Sst bm vfgr vslty m sin dgld flu Sst It brn vfgr vslty m stn gld flu SSt It brn vfgr velty m etn dgld flu SSt It bm vfgr vsity m sin girl flu Sst it bm vfgr vslty scalc m stn girl flu SSt It bm vfgr vslty scalo m sln gld flu Sst It bm vfgr vslty scalc m sin gld flu Sst It bm vfgr vslty scale m stn gld flu Sst It bm vfgr vslty scalo m sin gld flu Sst it bm vfgr vstty m stn gld flu Sst It bm vfgr vslty m stn gld flu Sst It brn vfgr vslty m stn gld flu SSt It bm vfgr vslty m stn gld flu Sst it bm vfgr vslty m sin gld flu Sst It bm vfgr vslty scalo m sin gld flu Sst It bm vfgr vslty calo m sln gld flu Phillips Petroleum Co. "Nigliq" 1 Colville Delta- File No. : 57111-01077 Loc.: Sec. 2-T12NIR4E APl No.: 50-103-20370 CORE ANALYSIS RESULTS 115 7361.2 0.126 0.032 11.1 29.2 62.0 912 0.47 2.67 116 7362.2 0.169 0.087 10.8 33.6 66.1 99.7 0.51 2,67 117 7363,2 0,092 0.076 11,7 28.8 60.0 86.8 0.48 2,67 118 7364,2 0,585 0.064 10,2 20.3 73.1 93,4 0.28 2.67 119 7365.2 0.110 0.036 10.3 19.8 68.9 88.7 0.29 2:67 120 7366,9 0,119 0.038 11.7 28.4 59,2 85.6 0,45 2,68 121 7367,3 0.075 0.057 10,7 19.6 69,8 89.4 0.28 2,69 122 7368.2 0.t39 0.078 12,2 25,6 59.4 85.0 0.43 2.68 123 7369,3 0,165 0,068 10,3 15.7 78,0 93,7 0.20 2.67 124 7370,3 0,328 0.050 11,0 21.9 68.3 90.2 0.32 2,68 125 7371.3 0,202 0.057 9.7 19.6 78.2 97,8 0,25 2,67 126 7372.6 0.150 0.071 10.0 14,6 79,7 94,3 0.18 2.68 127 7373,3 0.085 0.047 10,3 25.3 66.3 91.6 0,38 2.67 128 7374,9 0.177 0,094 10,8 23,5 66,9 90.4 0.35 2 129 7375,7 0.087 0.072 11.5 30,8 58.5 89.3 0.53 2,66 130 7378.2 0.122 0.080 11.1 24.4 64.8 89.2 0.38 2.67 131 7377.2 0.125 0.004 11.2 23.1 67,4 90.5 0.34 2,67 132 7378,9 0.071 0,057 10.9 14.6 79,4 94,0 0,18 2.69 133 7379,2 0.117 0.043 10.9 18,7 80,7 97.4 0.21 2.68 134 7380,2 0.081 0,029 lO,g 41,5 53.0 94.5 0,78 2.80 135 7381,9 0.092 0.030 9,3 20,0 74,1 94.1 0,27 2,67 136 7382.2 0,176 0.033 9.8 18.7 80,7 99,4 0.23 2.66 137 7383,2 0.092 0.031 10,0 25,2 72.3 97.5 0.35 2,66 138 7384.9 0.104 0.034 10.9 24.0 66.3 90.3 0,36 2,68 139 7385.3 0.062 0.044 10.7 26.0 63.6 89.6 0.41 2.67 140 7386.2 0.187 0.034 9,6 22.3 77,1 99,4 0.29 2.66 141 7387.8 0.124 0.054 9,8 17.0 81.9 98.9 0.21 2.67 142 7388,2 0.112 0,021 9,7 16.6 82.4 99.0 0.20 2,67 143 7389.2 O. 121 0.020 9,6 8.6 89.8 98.4 O, 10 2.70 SSt It bm vfgr vsity scalo m stn gld flu Sst it bm vfgr vsity sc=lc m 8tn gld flu Sst It bm vfgr vslty seal; m stn gld flu Sst It bm vfgr vslty sc=lc m etn gld flu Sst It bm vfgr vslty seal= m 8tn girl flu Sst It bm vfgr vslty sc=lc m sin gld flu SSt It bm vfgr vsity scalo m stn gld flu Sst It brn vfgr vsity sc=lo m stn gld flu Sst It bm vfgr vslty sc=lo m stn gld flu Sst It bm vfgr vslty sc=lc m stn gld flu Sst It bm vfgr vslty sc=lo m 8tn gld flu SSt It bm vfgr vsity sc=l= m stn gld flu Sst It bm vfgr vslty scal= m stn gld flu Sst It bm vfgr vslty m stn gld flu SSt It bm vfgr wity m stn gld flu Sst It bm vfgr vsity sc, al= m s~ gld flu Sst it bm vfgr vsity sc, al= m stn gld flu SSt It bm vfgr vslty scala m stn gld flu SSt It bm vfgr vslty sc=l= m stn gld flu Sst It bm vfgr vslty pyr m stn gld flu Sst It bm vfgr vslty sc=lo m stn gld flu Sst It bm vfgr vslty sh lams m ~n gld flu Sst It bm vfgr vslty m stn gld flu SSt It bm vfgr vsity m stn gld flu Sst It bm vfgr vstty sc, al= m stn girl flu Sst It bm vfgr vsity m stn gld flu Sst It bm vfgr vslty sc=lo m stn girl flu SSt It bm vfgr vslty sc=lc m stn girl flu Sst It bm vfgr vslty cai= m stn gld flu Phillips Petroleum Co. "Nigliq" 1 Colville I~lta File No. : 57111-01077 Loc,: Sec, 2-T12NIR4E APl No.: 50-103-20370 CORE ANALYSIS RESULTS 144 7390.2 0.156 0.023 9.4 10.7 88,2 98,9 0.12 2.66 145 7391.3 0,098 0.0t9 9.2 7,1 91,5 98.6 0.08 2.66 146 7392.2 0.041 0.022 10.6 0.0 83.4 83.4 0.00 2.69 147 7393.2 0,506 0.023 9,8 0.0 94.2 94.2 0.00 2.68 148 7394.9 0.254 0,017 9,7 0.0 93,2 93.2 0,00 2:68 149 7395,2 0.048 0.022 10.0 0,0 87,9 87,9 0.00 2.68 150 7396.9 0.179 0,015 9.7 0.0 92,6 92.6 0.00 2,87 151 7397.2 O. 107 0,032 9.6 0.0 99.1 99, I 0.00 2,66 152 7398.3 0.142 0.065 10.1 0.0 97.4 97.4 0.00 2.67 153 7399,9 0,086 0.016 10.0 0.0 99,2 99.2 0,00 2,68 154 7400.2 0.561 0.027 10,3 0,0 93,2 93.2 0.00 2,67 155 7401.2 0.080 0.013 10,8 0.0 93,3 93.3 0.00 2,67 156 7402,3 0,038 0.032 9.8 0,0 96.3 96.3 0.00 2.67 157 7403,2 0,132 0,0t8 9.5 0,0 98,1 98,1 0,00 2,68 158 7404.2 0.086 0,029 9.6 0.0 96,1 96.1 0.00 2,67 159 7405.7 0,163 0,018 9,1 0,0 94.6 94.6 0.00 2.66 160 7406.2 0.048 0.018 9.4 0,0 99,1 99,1 0,00 2.68 161 7407,3 0.063 0.027 92. 0,0 98.3 98,3 0,00 2,66 162 7408,8 0,052 0,025 9,7 0.0 95.8 95.8 0.00 2.66 163 7409.2 0.064 0.030 9.9 0.0 94.1 94,1 0.00 2,66 164 7410.3 0.057 0.025 9,3 0.0 97,7 97.7 0.00 2.66 165 7411,8 0.039 0.012 10.2 0.0 90.1 90.1 0.00 2.67 166 7412.3 0.051 0.044 10,4 0.0 93.8 93.8 0.00 2.67 167 7413,3 0.038 0.018 10.1 0.0 93,4 93.4 0.00 2.67 168 7414.2 0.052 0.011 9,7 0.0 95.0 95.0 0.00 2.67 169 7415,2 0.059 0.030 9.9 0,0 96,4 96.4 0.00 2.67 170 7416.2 0,059 0.009 9.4 0.0 96,5 96,5 0.00 2,67 171 7417.4 0,049 0.023 10,3 0.0 88,3 88.$ 0.00 2.67 172 7418.2 0.098 0.011 9.8 0.0 92,4 92.4 0.00 2.66 Sst gry-tan vfgr vslty m ~p gm gtd flu Sst gry-tan vfgr vNty m sp sm gld flu Sst gry vfgr vslty scalc no stn no flu Sst {;FY vfgr vslty scale no stn no flu Sst gry vfgr vslty scale no stn no flu Sst gry vfgr vslty scale no sin no flu Sst gry vfgr vslty scale; no sin no flu Sst gry vfgr vslty no stn no flu Sst gry vfgr vslty scale no sm no flu SSt gry vfgr vdty scalc no sin no flu Sst gry vfgr vslty scale no sin no flu Sst gry vfgr vslty scalc no sin no flu Sst gry vfgr vslty scalc no sin no flu Sst gry vfgr vslty scalc no sin no flu Sst gry vfgr vslty scalc no stn no flu Sst gry vfgr vslty no stn no flu Sst gry vfgr vsity no sin no flu Sst gry vfgr vslty sh no sin no flu SSt gry vfgr vslty sh no sin no flu Sst gry vfgr vslty sh no sin no flu Sst gry vfgr vsity sh no sin no flu Sst gry vfgr vslty sh sonic no sin no flu Sst gry vfgr vslty sh soalo no sin no flu Sst gry vfgr vslty sh scal~ no stn no flu Sst gry vfgr vslty sh soalo no sin no flu Sst gry vfgr vslty sh scalc no stn no flu Sst gry vfgr vslty sh scalc no sin no flu Sst g~/vfgr vstty sh scale no sin no flu Sst gry vfgr vslty sh no sin no flu Phillips Petroleum Co. "Nigliq" 1 Colville Delta. File No. : 57111-01077 Loc.: Sec, 2.T12NIR4E APl No.: 50.103.20370 CORE ANALYSIS RESULTS 173 7419.3 0.076 0.016 9.5 0.0 98,0 98,0 0.00 2.67 Sst .gry vfgr vstty sh scal(~ no sin no flu 174 7420,2 0.083 0.009 9.7 0.0 97.8 97.8 0,00 2.67 SlIM gry vfgr sd sh scal~ no stn no flu 175 7421.2 0.069 0.028 I0.3 0.0 92.0 92.0 0.00 2.66 Sltst gry vfgr sd sh no stn no flu 176 7422.8 0.048 0.020 10.2 0.0 94.7 94,7 0,00 2.67 SILst gry vfgr sd sh scale no stn no flu 177 7423.3 0.067 0.020 10,5 0.0 95.6 95.6 0.00 2;66 $1tst gry vfgr sd sh no stn no flu Phillips Petroleum Co. "Nigliq" 1 Colviile -Delta File No.: 57111-01077 Loc.: Sec2-Tt2NIR4E APl No.: 50-103-20370 HYDRAULIC UNITS 7244.2 0,48849 0,088 9 7245,2 0,32580 0,048 8 7246,2 0,39141 0,061 9 7247,2 0,76824 0,157 10 7248.2 0,91297 0,191 10 7249,2 - 0,50594 0,078 9 7250.2 2,20511 0,23t 12 7251,2 1,49807 0,278 11 7252,3 1,27719 0,237 11 7253..2 1,79114 0,392 12 7254,2 1,19905 0.226 11 7255.2 i ,69392 0,368 12 7256,2 1,22960 0,242 11 7257,2 1,96014 0,433 12 7258.2 0,46045 0,072 9 7259.2 2,06226 0,462 12 7260.2 2,62718 0,654 12 7261.2 0,48651 0.093 9 7262,2 0,89651 0,159 10 7263,2 2,10949 0.466 12 7264,3 1,12281 0,207 11 7265.2 2,40297 0.566 12 7266.2 0,77824 0.128 10 7267,2 1,51218 0.299 11 7268.2 2,18405 0,477 12 7269.2 1.98586 0.420 12 7270,2 2,30271 0,554 12 7271.2 0,90772 0,150 10 7378.9 0,20677 ' 0,025 7 7385.3 0,19807 0,024 7 7392.2 0,16574 0,020 7 7395,2 . 0,19587 0.022 7 7402.3 0,17753 0,019 7 7411,8 0.17284 0,020 7 7412,3 0,19020 0,022 7 7413,3 0,17053 0,019 7 7417,4 0,18749 0,022 7 7422.8 0,19058 0.022 7 7424.1 0,16143 0,018 7 7245.2 0,32580 0.048 8 7276.1 0,25848 0.075 8 7297.2 0,28594 0,048 8 7303.1 0,24684 0.038 8 7307,2 0.30665 0.046 8 7309,1 0,31947 0,050 8 7313.2 0,28572 0.043 8 7314,2 0.29889 0.045 8 7316.2 0,25163 0.037 8 7317.2 0.25456 0.037 8 7318.2 0,32758 0.053 8 7320.3 0,31809 0.051 8 7321.7 0.29654 0.042 8 7322,3 0,31360 0.041 8 7323.2 0,27357 0,037 8 7324.7 026962 0,038 8 7326.7 0,34601 0.050 8 Phillips Petroleum Co, "Nigliq" 1 Colville Delta File No.: 57111-01077 Loc.: Sec2,T12NIR4E APl No.: 50-103-20370 HYDRAULIC UNITS 7272,1 1.72457 0,359 12 7273.1 0.50570 0,065 9 7274.9 0.46133 0.056 9 7275.1 0.67997 0.111 10 7276.1 0.25848 0.075 8 7277,1 0.73217 0,135 10 7278,1 0.53736 0.083 9 7279,1 0,66478 0.098 10 7280,1 0.62486 0.096 10 7281,1 0.61081 0,098 10 7282.1 0.71394 0,101 10 7283,1 1,47975 0.305 11 7284,1 1,50240 0,287 11 . 7285.1 0.62454 0.099 10 7286.1 0.67354 0.115 10 7287.1 0,64317 0.108 10 7288.3 0.63876 0.105 10 7289.1 0.73056 0.123 10 7290.1 0,67458 0.102 10 7291.1 0.55988 0.093 9 7292.1 0.42566 0.063 9 7293,1 0.45374 0.076 9 7294.1 0.46806 0.077 9 7295.1 0.53868 0.088 9 7296.2 0.60331 0.103 10 7297.2 0.28594 0,048 8 7298.2 0.34903 0.054 9 7299.2 0.54441 0.094 9 7327.7 0.33820 ' 0.054 8 7328,3 0,26380 0.041 8 7329.1 0.24689 0.039 8 7330.1 .0.29055 0.048 8 7334.4 0.24256 0,034 8 7335,3 0,29068 0,038 8 7336.3 0.30385 0,044 8 7337.2 0,21915 0.033 8 7338.2 0.25504 0.037 8 7339.2 0,26402 0.036 8 7340,2 0,31111 0.039 8 7342.2 0.30158 0.035 8 7343.2 0.29243 0.040 8 7344.2 0.25887 0.031 8 7345.3 0.24132 0.038 8 7346.2 0.26115 0.038 8 7348.3 0,29716 0.036 8 7349.3 0.23207 0.031 8 7350.2 0.33945 0.037 8 7352.2 0.31043 0.037 8 7353.2 0.28792 0.033 8 7354.3 0.27247 0.033 8 7355.4 0,23367 0.031 8 7357.2 0.21735 0.028 8 7358.2 0.27967 0,031 8 7361.2 0.26769 0.033 8 7362.2 0,32293 0.039 8 7363.2 0,20947 0.028 8 Phillips Petroleum Co, "Nigliq" 1 Colville Delta File No.: 57111-01077 Loc,: Sec2-T12NIR4E APl No,: $0-103-20370 HYDRAULIC UNITS 7300.2 0.37269 0.058 9 7301,3 0,42700 0,073 9 7302.2 0,39098 0,059 9 7303.1 0.24684 0.038 8 7304.7 0.47898 0.084 9 7305.1 0.61032 0.103 10 7306.6 0.41587 0.065 9 7307.2 0,30685 0.046 8 7308.1 0.41430 0.070 9 7309.1 0.31947 0.050 8 7310.1 0,37869 0.063 9 7311,1 0.56205 0,104 9 7312.2 0.36131 0.061 9 7313.2 0.28572 0.043 8 7314.2 0.29889 0.045 8 7315,9 0,39332 0,066 9 7316.2 0.25163 0,037 8 7317.2 0.25456 0.037 8 7318,2 0.32758 0,053 8 7319.2 0.37042 0.060 9 7320.3 0.31809 0.051 8 7321.7 0.29654 0.042 8 7322.3 0.31360 0.041 8 7323.2 0.27357 0,037 8 7324.7 0.26962 0,038 8 7325.2 0.34692 0.047 9 7326.7 0.34601 0.050 8 7327.7 0.33820 0.054 8 7365.2 0,28227 ' 0.032 8 7386.9 0,23826 0.032 8 7367.3 0,21974 0.026 8 7368.2 0,24020 0.033 8 7372.6 0,3,4437 0.038 8 7373.3 0,24728 0.029 8 7374.9 0,33103 0.040 8 7375.7 0.21107 0.027 8 7376.2 0.26400 0.033 8 7377.2 0.26350 0.033 8 7379.2 0,26617 0.033 8 7380.2 0,21964 0.027 8 7381.9 0.30518 0.031 8 7383.2 0.27093 0.030 8 7384.9 0.25213 0.031 8 7387.8 0.32549 0.035 8 7388.2 0.31363 0.034 8 7389.2 0,33238 0.035 8 7391.3 0.32230 0.032 8 7397.2 0,31492 0,033 8 7398.3 0.33111 0.037 8 7399.9 0,26221 0,029 8 7401.2 0,22465 0.027 8 7404.2 0,27753 0,030 8 7406.2 0.21726 0,023 8 7407.3 0.25655 0.026 8 7408.8 0,21:344 0,023 8 7409.2 0.22973 0.025 8 Phillips Petroleum Co. "Nigliq" 1 Colville Delta File No.: 57111-01077 Loc,: Sec2-T12NIR4E APl No.: 50-103-20370 HYDRAULIC UNITS 7328.3 0,26380 0,041 6 7329,1 0.24689 0.039 6 7330,1 0.29055 0.048 6 7334,4 0.24206 0,034 8 7335.3 0,29068 0.038 8 7336.3 0,30385 0.044 8 7337.2 0.21915 0.033 6 7338.2 0,25504 0.037 8 7339.2 0.26402 0.036 8 7340,2 0.31111 0.039 8 7341.2 0.37235 0.046 9 7342,2 0,30158 0.035 8 7343,2 0.29243 0.040 7344.2 0,25887 ' 0.031 8 7345.3 0.24132 0,038 8 7346,2 0.26115 0,036 8 7347.3 0,40979 0.045 9 7348.3 0.29716 0.036 8 7349.3 0.23207 0.031 8 7350.2 0.33945 0.037 8 7351,2 0,39148 0.044 9 7352.2 0,31043 0.037 8 7353.2 0.28792 0.033 6 7354.3 0.27247 0.033 8 7355.4 0.23367 0,031 8 7356.2 0.36693 0,041 9 7357.2 0,21735 0.028 8 7358.2 0.27967 0.031 8 7410.3 0,24062 ' 0.025 8 7414.2 0.21239 0.023 8 7415.2 0,22130 0.024 8 7416.2 0.23841 0.025 8 7418.2 0,28963 0.031 8 7419.3 0.26857 0.028 8 7420.2 0.27153 0.029 8 7421.2 0.22342 0.026 8 7423.3 0.21464 0.025 8 7244.2 0.48849 0.088 9 7246.2 0.39141 0.061 9 7249,2 0.50594 0.078 9 7258.2 0,46045 0,072 9 7261,2 0.48651 0.093 9 7273,1 0.50570 0,065 9 7274.9 0.46133 0.056 9 7278.1 0,53736 0.083 9 7291.1 0.55988 0.093 9 7292.1 0,42566 0.063 9 7293.1 0.45374 0.078 9 7294.1 0,46806 0.077 9 7295.1 0.53866 0.088 9 7298.2 0,34903 0.054 9 7299.2 0.54441 0.094 9 7300.2 0,37259 0.058 9 7301.3 0.42700 0,073 9 7302.2 0,39098 0.059 9 7304.7 0.47898 0.084 9 Phillips Petroleum Co. "Nigliq" 1 Colvllle -Delta File No.: 67111-01077 Loc.: Sec2-T12NIR4E APl No.: 50.103-20370 HYDRAULIC UNITS 7359.2 0.43744 0.046 9 7350.3 0.46526 0.048 9 7361.2 0.26769 0.033 8 7362,2 0.32293 0,039 8 7363,2 0.20947 0,028 8 7364,2 0.66170 0,075 10 7365,2 0.28227 0,032 8 7366.9 0.23826 0,032 8 7367.3 0.21974 0..026 8 7368.2 0.24020 0.033 8 7369,3 0.34712 0,040 9 7370,3 0.44170 0,054 9 7371.3 0,42336 0,045 9 7372.6 0.34437 0,038 8 7373,3 0,24728 0,029 8 7374,9 0,33103 0,040 8 7375.7 0.21107 0,027 8 7376.2 0,26400 0,033 8 7377.2 0.26350 0,033 8 7378.9 0.20677 0,025 7 7379.2 0.26617 0,033 8 7380,2 0.21964 0,027 8 7381.9 0.30518 0,031 8 7382.2 0.38773 0,042 9 7383,2 0.27093 0,030 8 7384.9 0.25213 0,031 8 7385.3 0.19807 0.024 7 7386.2 0,38768 0,041 9 7306.6 0,41587 ' 0.065 9 7308.1 0.41430 0,070 9 7310.1 0.37869 0,063 9 7311,1 .0.56205 0.104 9 7312.2 0,36131 0,061 9 7315,9 0.39332 0.066 9 7319.2 0,37042 0.060 9 7325.2 0.34692 0.047 9 7341,2 0.37235 0.046 9 7347,3 0,40979 0,045 9 7351.2 0,39148 0,044 9 7356,2 0.36693 0.041 9 7359.2 0,43744 0.046 9 7360.3 0.46526 0.048 9 7369,3 0,34712 0,040 9 7370.3 0.44170 0.054 9 7371.3 0.42336 0.045 9 7382.2 0,38773 0,042 9 7386.2 0,38768 0.041 9 7390.2 0,38890 0,040 9 7394.9 0.47301 0.051 9 7396.9 0,39513 0.043 9 7403.2 0.35371 0.037 9 7405.7 0.41652 0.042 9 7247,2 0,76824 0.157 10 7248.2 0.91297 0.191 10 7262,2 0.89651 0.159 10 7286.2 0.77824 0.128 10 Phillips Petroleum Co. "Nigliq" 1 Colville Delta File No.: 57111-01077 Loc.: Sec2-T12NIR4E APl No.: 50.103-20370 HYDRAULIC UNITS 7387,8 0,32549 0,035 8 7368.2 0,31363 ~),034 6 7389,2 0,33238 0,035 8 7390,2 0,38890 0,000 9 7391,3 0,32230 0,032 8 7392.2 0,16574 0,020 7 7393,2 0,65568 0,071 10 7394,9 0,47301 0,051 9 7395,2 O, 19587 0,022 7 7396.9 0,39513 0,003 9 7397.2 0,31492 0,033 8 7398,3 0,33111 0,037 8 7399,9 0,26221 0,029 8 7400,2 0,64237 ' 0,073 10 7401,2 0,22465 0,027 8 7402.3 0,17753 0.019 7 7403.2 0.35371 0.037 9 7404,2 0.27753 0.030 8 7405.7 0.41652 0.042 9 7406,2 0,21726 0,023 8 7407,3 0,25655 0,026 8 7408,8 0,21344 O, 023 8 7409.2 0,22973 0.025 8 7410.3 0.24062 0.025 8 7411,8 O, 17264 0.020 7 7412.3 0.19020 0.022 7 7413.3 0.17053, 0.019 7 7414.2 0.21239 0,023 8 7271,2 0,g0772 ' 0,150 10 7275,1 0,67997 0,111 10 7277,1 0,73217 0,135 10 7279,1 .0,66478 0,098 10 7280,1 0,62486 0,096 10 7281,1 0,61081 0,098 10 7282.1 0,71394 0,101 10 7285,1 0.62454 0.099 t0 7286.1 0.67354 0,115 10 7287,1 0,64317 0,108 10 7288,3 0,63876 0,105 10 7289,1 0,73056 0,123 10 7290,1 0,67456 0,102 10 7296,2 0,60331 0.103 10 7305,1 0,61032 0,103 10 7384,2 0,66170 0.075 10 7393,2 0,65566 0,071 10 7400.2 0,64237 0,073 10 7251,2 1,49807 0,278 11 7252.3 1,27719 0,237 11 7254,2 1,19905 0.226 11 7256.2 1,22960 0.242 11 7264,3 1,12281 0,207 11 7287,2 1.51218 0,299 11 7283,1 1.47975 0,305 11 7284,1 1,50240 0.287 11 7250,2 2,20511 0.231 12 7253.2 1.79114 0.392 12 Phillips Petroleum Co. "Nigliq" 1 Colville Delta File No.: 57111-01077 Loc.: Sec2-T12NIR4E APl No.: 50-103-20370 HYDRAULIC UNITS Depth': , . iF ow ,,,rvoir 'Hydrau,O 'i::':"i'hdi~at~!:!!' ...?'i.: index ?i:'.::i':. 74t 5,2 0.22130 0.024 8 7416.2 0,23841 0,025 8 7417,4 0.18749 0.022 7 7418.2 0.28963 0.031 8 7419.3 0,26857 0.028 8 7420.2 0,27153 0.029 8 7421.2 0,22342 0,026 8 7422.8 0.19058 0.022 7 7423,3 0.21464 0,025 8 7424; 1 O, 16143 0.018 7 ., I_ · ' , i ii '1. i "Depth.. ': ... Flow. ': ReServoir ':HydmUli(=, ! i:.':~"indicat~?'!":. .'?~! ,,.~i IndeX':.'.::?: ':'-:!i:i:'i:.';:"::,: :. ~i:" :;.i:': 7255.2 1.69392 ' 0.368 12 7257.2 1,96014 0,433 12 7259.2 2,06226 0,462 12 7260.2 . 2,62718 0.654 12 7263.2 2.10949 0.466 12 7265.2 2.40297 0,566 12 7288.2 2.18405 0.477 12 7269.2 1.98586 0,420 12 7270,2 2.30271 0,554 12 7272,1 1.72457 0.359 12 Phillips Petroleum Co. "Nigliq" 1 Colville Delta C-1 7244.0 - 7425.0 1 7244.0 - 7246.0 7246.0 - 7249.0 2 7249.0 - 7252.0 7252.0 - 7255.0 3 7255.0 - 7258.0 7258.0 - 7261.0 4 7261.0 - 7264.0 7264.0 - 7267.0 - 5 7267.0 - 7270.0 7270.0 - 7273.0 6 7273.0 - 7276.0 7276.0 - 7279.0 7 7279.0 - 7282.0 7282.0 - 7285.0 8 7285.0 - 7288.0 7288.0 - 7291.0 9 7291.0 - 7294.0 7294.0 - 7297.0 10 7297.0 - 7300.0 7300.0 - 7303.0 11 7303.0 - 7308.0 7308.0 - 7309.0 12 7309.0 - 7312.0 7312.0 - 7315.0 13 7315.0 - 7318.0 7318.0 - 7321.0 14 7321.0 - 7324.0 7324.0 - 7327.0 15 7327.0 - 7330.0 7330.0 - 7333.0 CORE INVENTORY C-1 Continued 16 7333.0 - 7336.0 17 18 lg 2O 21 22 23 24 25 26 27 28 29 30 7336.0 - 7339.0 7339.0 - 7342.0 7342.0 - 7345.0 7345.0 - 7348.0 7348.0 - 7351.0 7351.0 - 7354.0 7354.0 - 7357.0 7357.0 - 7360.0 7360.0 - 7363.0 7363.0 - 7366.0 7366.0 - 7369.0 7369.0 - 7372.0 7372.0 - 7375.0 7375.0 - 7378.0 7378.0 - 7381.0 7381.0 - 7384.0 7364.0 - 7387.0 7387.0 - 7390.0 ' 7390.0 - 7393.0 7393.0 - 7396.0 7396.0 - 7399.0 7399.0 - 7402.0 7402.0 - 7405.0 7405.0 - 7408.0 7408.0 - 7411.0 7411.0 - 7414.0 7414.0 - 7417.0 7417.0 - 7420.0 7420,0 - 7423.0 File No.: 67111-01077 Loc.: Sec2-T12NIR4E APl No,: 50-103-20370 C-1 Continued 3t 7423.0 - 7425.0 Operations Summary Nigliq I and lA Rpt Date March 2, 2001 March 3, 2001 March 4, 2001 March 5, 2001 March 6, 2001 March 7, 2001 Comments Rig down and prep to move rig Continue moving rig f/CD1-14 to Nigliq #1 - Move rig camp- position sub base - lay herculite and set mats - move rig floor into position - hook up air, water, steam and mud lines Take on spud mud, spot cutting tank & build containment burm, rigging up Epcoh mudloggers Service top drive Prep to pick up drill pipe - P/U and 39 jts. 5" DP, 29 jts. HWDP, 3 NM DC & Std back in derrick Function test diverter - calibrate gas alarms - perform accum closure test - Test witnessed and approved by John Crisp AOGCC Cut off conductor and install landing ring Accept rig 00:00 hrs. Cut and slip 60' drill line N/U dirverter system - riser, flow line, diverter line, hoses Pump sweep and circ btms up - check samples for csg point Spud in & drill 12 1/4" hole f/117' tro 2046' - 2032' TVD Make up BHA # 1 Fill hole & check for leaks - Pressure test mud lines to 2500 psi Finish rigging up Epoch mud loggers Monitor well - wiper trip f/2046' to Held pre spud meeting w/crew L/D cmt head & landing jt. Rig up to run 9 5/8" csg R IH f/1100' to 2046' Prep & put together BOP stack PJSM - Cement 9 5/8" csg as follows: Pumped 40 bbls. viscosified water w/nut plug as marker 5 bbls water test lines to 2500 psi drop btm plug pumped 50 bbls Arco spacer @ 10.5 ppg mix & pump 249 bbls lead slurry @ 10.7 ppg observed nut plug marker at sha L/D BHA # 1 Pull out w/5" DP & HWDP to run 9 5/8" casing Housekeeping rig floor Held PJSM - Ran 49 jts. 9 5/8" 36# J-55 BTC csg - equipped w/Davis Lynch FC, FS, & TAM PC - Landed on FMC mandrel hanger w/FS @ 2036' FC @ 1949' TAM PC @ 1010' Flush 20" hydril w/fresh water - N/D diverter system Install FMC Unihead & test seals Circ and condition mud & hole for cement job Break circ - pump hi vis sweep & circ hole clean - monitor well - blow down top drive Test BOPE - Hydril to 250 psi Iow & 3750 psi high - test kill & choke line vlaves - pipe rams - blind rams - choke manifold valves - floor safety valve - dart valve - top drive IBOP to 250 psi Iow & 5000 psi high - 3 choke manifold valves failed to test Set test plug - fill stack w/water Rig up to pick up 5" drill pipe f/shed Rig down test equip. - pull test plug - set wear bushing Pick up 5" DP f/pipe shed and std back in derrick (57 jts) Install new blind rams Hammer up Unihead adopter flange - set BOP stack onto adopter - Install bell nipple - flow line - turnbuckles Operations Summary Nigliq 1 and lA March 8, 2001 March 9, 2001 March 10, 2001 March 11,2001 March 12, 2001 Continue putting BOP stack together- blind rams/mud cross/btm pipe rams Body test choke and BOP - repair misc. leaks RIH f/2035' to 2378' (15 mins.) Drill 8 1/2" hole f/2378' to 3001' - 2942 TVD Pressure test 9 5/8" casing to 2500 psi for 30 mins. Pick up and rack back 12 more jts. 5" DP Pick up 27 jts. 5" DP f/pipe shed & RIH w/BHA to 1900' - Wash to 1929' Perform F.I.T. to 13.3 ppg EMW w/9.8 ppg mud Make up BHA # 2 - pulse test MWD Circ & cond. mud for casing test Drill wirper plugs - FC - Cmt - FS - C/O rat hole to 2046' - Drill 20' new hole to 2066' Drill 8 1/2" hole f/2066' to 2378' Continue picking up 5" DP from pipe shed and standing back in derrick Circ hole clean for F.I.T. Electrical problem w/shale shakers - circ - pull back to 9 5/8" casing shoe Monitor well - blow down TD - wirper truip f/3546' to 2557' 10 stds. improper fill on last 5 stds. - Mionitor well (static) -RIH to 3546 Pump sweep & circ hole clean Prep to POOH - pump dry job - blow down TD - fill trip tank Drill 8 1/2" hole f/3757' to 4458' - 4331' TVD - ADT- 3.48 POOH for bit - hole in good condition - bit balled up Continue RIH - monitor well @ 2034' - fill pipe - RIH to 3757' Circ btms up - no gas shows (15 mins.) Drill 8 1/2" hole f/3546' to 3757' - ROP slowed Drill 8 1/2" hole f/3001' to 3546' - ADT 4.03 AST- 0 Change bits - RIH to 264' - pulse test MWD Attempt to improve p rate - pump nut plug sweep - unsuccessful - bit appears balled up Wiper trip f/5544' to 3444' - r well - RIH to 5544' Pump hi vis sweep - circ hole clean - blow down TD - monitor well Drill 8 1/2" hole f/5544' to 6305' - 6140' TVD - ADT 5.48 AST 2.0 Drill 8 1/2" hole f/4458' to 5544' -5382'TVD ADT-7.7 AST 1,25 Prep to trip for BHA - fill trip tank - obtain SPR - blow down top drive POOH w/BHA ~ L/D motor & bit POOH to 5700' - monitor well - pump dry job - continue POOH to BHA Drill 8 1/2" hole f/7163' to 7168' - 7003' TVD - circ btms up for sample for Geologist RIH to 1050' - Pulse test MWD - RIH to 2000' Cut & slip drill line Clean rig floor - M/U bit #4 W/BHA# 3 - Down load MWD Circ btms up for sample for Geologist Drill 8 1/2" hole f/6305' to 7163' - 6998' TVD - ADT- 10.96 Service top drive RIH w/coring assmebly - fill pipe every 2000' RIH to 7143' - fill pipe @ 4370' & 7100' Pump hi vis sweep & circ hole clean - monitor well - pump dry job POOH for core bbl M/U coring assembly Drop ball - cut core # 1 f/7244' to 7267' C.._ o r ~ Drill 8 1/2" hole f/7168' to 7244' - drill break Circ btms up sample for Geologist · ' . { Operations Summary i' Nigliq I and lA March 13, 2001 Circ btms up Break circ.- MAD pass w/MWD f/7143' to 7168' L/D BHA - MWD - stab - bit Pull wear bushing - set test plug - rig up test equip. POOH w/HWDP to core bbls. 6 mins/std Test BOPE- pipe rams - blind rams - choke and kill line valves - choke manifold valves - floor safety - dart valve - IBOP to 250 psi Iow & 5000 psi high - Annular to 250 psi & 3500 psi high - witnessing of test waived by Chuck Scheve AOGCC March 14, 2001 RIH w/HWDP to 1069' - pulse test MWD - Continue RIH Monitor well - pump dry job - POOH w/core # 1 - 2 mins/std. Blow down choke and kill lines - pull test plug - set wear bushing Continue cutting core # 1 f/7267' to 7424' -7259' TVD Break out and lay down outter core bbls M/U BHA # 5 Circ btms up Break out and laydown inner core bbls w/core #1 -100% recovery Begin wiper trip. Est. circ, MAD pass w/MWD from 7244' to 7424'. Pumped high vis sweep and circ hole clean, slight show of shale splinters at shakers. Monitor well, static, blow down TD. R IH to 7244'. Drill from 7424' to 8040', TD. ART=16.03 March 15, 2001 March 16, 2001 #2 mud pump down from 0200 - 2100 hrs. changed out traction motor Wipe hole to 6880', RIH, no problems. POH to 6600', pump dry job and continue to POH. Monitor well at shoe, static. Pump high vis sweep and circ hole clean, monitor well, static. Blow down TD. PJSM. RU Schlumberger and RIH with Platform Express/CMR. Log from 8046' (WLM) to surface, lay down tools. Lay down BHA, clear tools and clean rig floor. MU DSI tools and RIH with WL. Log up with DSI from 8020'. Ran DIS log, POH w/WL and LD tools. RIH with O/S assy, stripping over wireline, 3632' @ midnight. Pull test wireline O/S assy to 6500 lbs, strip through fishing tools, change sinker bars and safety catch for 5" DP. PJSM. RU to strip over wireline, cut line and dress cable for stripping operations. Hang top sheeve, change to long bails and RU link tilt cylinders. LD 3 Jts of hwdp. March 17, 2001 MU 8-1/8" O/S assy. w/3-3/8" grapple, PU LBS and oil jars. Attempted to pull VSP log off station at 7155', stuck, Top of tools @ 7081'. Work wireline attempting to free tools, WO fishing tools. MU VSP tool string and RIH w/WL. Log with VSP from 8020' to 7155'. Worked tools down to 7976' and engaged fish, pressure spike during engagement sheared disc in circ sub. RIH to 7768', wash down to 7800', slight packing off problems. CBU and changed out long bails. Continue to wash down with slight packing off problems from 7800' to 7966', ETOF. POH, worked through several tight spots from 7100' to 4300', no problems above 4300'. Lay down fish recovered (100%), BO and LD fishing tools. POH, pipe pulling tight 30-60k over, circ and work pipe up to 7100'. Operations Summary Nigliq I and lA March 18, 2001 Continue to RIH with O/S assy. stripping over wireline to 7085'. Circ to clean grapple, work tools over fish to 7089'. RU and shear rope socket from fish, POH with wireline. RU to circ and shear disc in circulating sub, observed original circulating press Troubleshoot disc brake on Draworks. Stand back BHA. Slip and cut drilling line. Service Top Drive - changed dies on Grabber. Service TD and Drawworks. RIH to shoe - break circ 3 bpm @ 100 psi. Staged pump up to 8 bpm and circ hole clean with full returns. Monitor well, static, blow down TD. RIH to 2000'. Pumped high vis sweep, began losing returns after sweep around bit, reduced pump rate to 4 bpm and circulated sweep out of hole. (Lost 45 bbls). POH - pulled 30-50k over in several spots from 7288' to 7100' - no other problems. March 19, 2001 March 20, 2001 PJSM. RU Iogers, MU MDT tool string and surface test tools. MU BHA # 6. RIH to 8035', reamed several tight spots from 6713' to 6900'. RIH with MDT on drill pipe to 5953', RU SE sub and pump down wetlatch. Engage docking head and function test tools. PU 30 Jts of 3-1/2" drill pipe and RIH below 5" drill pipe. POH to SE sub, LD SE sub and POH with wireline. Log with MDT per Geologist. POH and LD logging tools. RU and test cementlines to 2000 psi, plug back open hole in two stages from 4600' to 3770' with 345 sxs of 15.8 ppg G cement. CIP @ 13:45 hours Test choke manifold and surface safety valves to 250/5000 psi. Spot 40 bbls high vis pill and pull up to 2586'. RU to test cement line, had washout in line. Swap over cementers to "Injection line". RU to cementers, test lines to 2500 psi. Plugged back 8-1/2" openhole in tw° stages from 8040' to 6940' with 400 sxs of 15.8 ppg G cement. ClP @ 0900 hrs. March 21, 2001 RIH to 3825' - CBU. Wash down @ 2 bpm to 3865', no tag. WOC. RIH to 8040', no problems. POH to 6678' and circ to clear drill pipe. RIH - tag plug @ 3892' with 30K. Pull to 2870'. POH to 4600', circ and cond mud. POH to 3390' - CBU - pull to shoe. Lined up to cementers, had problems with valves on cement unit, troubleshoot. Continued to circ hole with rig pumps. Held Safety and Operations meeting with new crew. Circulate and condition mud for cementing. PJSM. Slip and cut drilling line, service TD. ~l~z~z~l ... ' ..... .. ~ _~ ' .... NOTES.: HAI~ISON BAY ~ ~ORO § (C)II ~,"-~ 2. C~DINA~S ~0~ ARE ALASKA STA~ PLANE Z~E 4, NAD 27.' 3. GEOGRAPHIC COORDtNA~S ARE NAD 27. 4. ELEVATIONS SHO~ ARE BRITISH PE~OLEUM MEA~ SCALE 5~ .-'~ ,.-~ :~~ 1~ ~[/-~'~,/ ~~~7 '~ ~ ~" - ~' ~ - ~-~ x ~ ~' : i~" ~ ~ ~ ~/~ ~,, ~ ~.~ ~ ' - .. ,,,,., ~ ..... ~ ~ ~_..~ ~"~ ....... ~ ~ ~. V[CINITY MAP SCALE 1" = 2 MILES ~" ~ .B ~ e~' ~ oo~ ......................... ,~.. ~ ~-~ 3 '~ ~~ LOCATED ~THIN PROTRACTED 3 2 ~ ~ ' X = 369,591.69 GR~ND ELEVATION ,= 5.~ ~;,. ~ ---:.,:~ ~ ~ ~ ~ I HEREBY CER~FY ~AT I AW PR~ERL Y ~ ~ REGIS~RED AND LImNeD TO PRAC~CE ~,.. LS~ .; '~ A SURLY D~ BY ~g ~ U~R ~Y ~' ... ~ /_ ~ ~ ...' ~ ~ ........... ~ ~~~.~ DIRECT ~PER~$I~ A~ ~AT ALL ~ ~'~' ~~ DIVEN~S AND O~R ~TAIL$ ARE · %~'?ss~ ~~., LOUNSBURY ....... ¢~: *=~ , ,, AREA: M. OD:ULE: UNi T: ' PHILLI~ AI=~, I~. N~cL[Q~ j A S,~=i~i=,~ o~ ~H]~L~PS P~TROL.~U~ COUPA~, EXPLORATORY WELL CONDUCTOR AS BUILT LOCATION .............. ! "'I ,,, LK6'~15~,~ ,, 3/e2/e~ ~ "'* NO: CEA-M1XX-6¢l D383 SHEET: . i i iii PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Nigliq 1 DATE: 05/09/2001 Lisa Weepie AC)GCC 555 W. 7th Avenue, Suite 100 Anchorage, Alaska 99510 Transmitted herewith is the following: Nigliq 1 501032037000 ~O)<~S~ CD ROM O/g/ta/ data v/Schlumberger Processed Dipole Sonic DT's logged 3-15-2001; cd date 03-24-01 .lob 21151 y/Schlumberger Processed CMR Results; logged 03-15-2001; cd date 03-27-01 ]ob 21152 chlumberger CDR ARC6 LWD in 4 bit LDW6 format 120-8040'md 3ob 21171 runs (PDC curve) chlumberger OH ED1TS; PEX AlT CMR & DSI data 954-8040'md; CD 1 of 2; 3ob 21153 chlumberger OH EDITS; PEX AlT CMR & DST data 954-8040'md; CD 2 of 2; 3ob 21153 ! Log Prints (/blueiines each) + I sepia each v//Schlumberger Vision RES* ND & TVD V/ Schlumberger Combinable Magnetic Resonance Log v/ Schlumberger Dipole Sonic Imager v/ Schlumberger Platform Express Comp Neutron/Lithodensity Log v/ Schlumberger Platform Express Array Znduction-RXO v/ Schlumberger Nodular Formation Dynamic Tester Co/or Logs (~ each) V/Schlumberger CMR DMRP-Bin processing v'~chlumberger Best DT-Dipole Sonic Q.C. Plot Report and///ustrat/ons v/ Core Labs Color core photos, Nigliq 1 .V/,/Anadrill directional survey printouts w/3.5" disk Niglig 1(5010320370-00) and iA (5010320370-01) **Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 5/2003 CC: Dave. Bannan, P/~I Geologist Return receipt to: Phillips Alaska, ThC. ATTN: S. Lemke, AT0-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska TI' Technical Databases CORE LABORATORIES PHILLIPS PETROLEUM NIGLIQ NO. 1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 TRANSMITTAL TO: AOGCC Anchorage, AK 99501 OPERATOR: PAI DATE: 21-MARCH-01 AIRBILL: N/A ABV#: PBV 01-03-21-02 CHARGE CODE#: ASD005 WELL: NIGLIQ #1 SAMPLE TYPE: DRIES SAMPLES SENT: NUMBER OF BOXES: 1 Bundle (4 boxes) NIGLIQ #1 120-8040 SENT BY: Mike McCracken UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: Phillips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski DATE: ¢YELL: 'S pETROLeUM V~bLL: NI~LIL~ ~ '1 PHILLIPS PETROLEUM WELL: NIGL ;pETROLEUM WELL: PHiLLiPS PETROLEUM WELL: NIGLI* WELL: Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 PHILL'PS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY March 19, 2001 Daniel J. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7~ , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approvals Phillips Alaska, Inc.- Nigliq # 1 Surface Location: 210' FSL, 1170' FWL, SEC 2, TI2N, R4E Target Location: 1019' FSL, 320' FWL, SEC 2, TI2N, R4E Bottom Hole Location: 4260' FNL, 4975' FEL, SEC 2, TI2N, R4E CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for an Application for Sundry Approvals to plugging the pilot hole of Nigliq #1 in preparation for a sidetrack to a new bottom hole location. A Form 401, Application t'or Permit to Drill will be submitted in accordance with 20 ACC 25.015. Upon completion of the proposed sidetrack and evaluation operations, the well will be permanently abandoned. Verbal permission to proceed with plugging back and sidetracking Nigliq #1 was forwarded to Phillips Alaska, Inc. from Tom Maunder via e-mail on March 16, 2001. Please find attached the information required by 20 ACC 25.105 (e) for your review. Pertinent information attached to this application includes the following: , Form 10-403 APPLICATION FOR SUNDRY APPOVALS per 20 ACC 25.105 (e). A statement of proposed work which encompasses the following requirements: 2.1. Information on abnormally geo-pressured strata; 2.2. The manner of placement, kind, size, and location, by measured depth, of proposed plugs. 2.3. A wellbore diagram showing the placement of the cement plugs. ORI¢,INAL RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchom,,e If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120 Scott Reynolds Drilling Engineer, Alpine Attachments CC: Nigliq #1 Well File / Sharon Allsup-Drake Chip Alvord ATO 1530 ATO 868 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend_ Alter casing _ Repair well _ Change approved program _ Operation Shutdown _ Re-enter suspended well_ Plugging X Time extension _ Stimulate_ Pull tubing_ Variance_ Pedorate _ Other 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory X Stratigraphic _ Service 4. Location of well at surface 210' FSL, 1170' FWL, SEC 2, T12N, R4F~, UM (Updated per As-Staked) At top of productive interval 1019' FSL, 320' FWL, SEC 2, T12N, R4E, UM (Per Permit to Drill #201-036) At effective depth At total depth 4260' FNL, 4975' FEL, SEC 2, T12N, R4E, UM (Per Permit to Drill #201-036) 6. Datum elevation (DF or KB) RKB' 43 DF 7. Unit or Property name N/A 8. Well number Nigliq #1 9. Permit number #201-036 10. APl number N/A 11. Field/Pool leer 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 2036' Intermediate N/A Production N/A Liner 8040 feet Plugs (measured) None 7875 feet feet Junk (measured) feet Size Cemented Measured depth 16" +/- 200cf 117' 9.625" 318 sks lead/233 sks tail 2036' True vertical depth 117' 2022' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A O¢l lilAL RECEIVED Alaska Oil & Gas Cons. Commission 13. Attachments Description summary of proposal _~X Contact Chip Alvord at 265-6120 with any questions_. Detailed operation program __ Anchoraqe BOP sketcl'i _ 14. Estimated date for commencing operation 3-20-2001 16. I~ proposai was verb~ly approved ~~ Name of approver Tom Maunder Date approved 3-16-2001 15. Status of well classification as: Oil X Gas _ Service Suspended _ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned ~4, ~ Title Alpine Team Leader · / - FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance_ Mechanical Integrity Test_ Subsequent form require 10- ~kC)"~ Approved by the order of the Commission .... 'RI(..,tNA~.. SIGNED BY' r-',, "taylor S .ama '- ' ~ommi~ner Date Form 10-403 Rev 06/15/88 IApproval No /~UBMIT IN 1. Information on Abno(~ .ally Geo-Pressured Strata ( .... 1.1. No abnormally geo-pressured strata were encountered while drilling the Nigliq #1 pilot hole. 2. Plug Back Procedure 2.1. Objectives: 2.1.1. No accidents and no spills. 2.1.2. Abandon Nigliq #1 per AOGCC 20 ACC 25.105 AB~NDONMENT OF WELLS, ACC 25.112 WELL PLUGGING REQUIREMENTS, ACC 25.120 WELL ABANDONMENT MARKER and ACC 25.170 ONSHORE LOCATION CLEARANCE. 2.1.3. Set kick-off plug in preparation for sidetrack. 2.2. Setting Abandonment Plugs and Kick-Off Plug. 2.2.1. Notify AOGCC slope inspectors 48 hours prior to tagging cement plug//3 so they may witness the operation. 2.2.2. PU & RIH w/mule shoe & 1000~1500' of 3-1/2" DP. RIH to TD with 5" DP. 2.2.3. Circulate and condition mud for setting 1~ cement plug. 2.2.4. Pump 1~ balanced cement plug per cementing program on the Wellbore Diagram in Section 2. POOH to 7540' MD and circulate out cement 2.2.5. Pump 2~d balanced cement plug per cementing program on the Wellbore Diagram in Section 2. POOH to 6940' MD and circulate out cement. 2.2.6. POOH to 4600' MD. Pump 3'~ balanced cement plug per cementing program on the Wellbore Diagram in Section 2. 2.2.7. POOH to 3900' MD and circulate out cement. POOH another 5 stands and WOC approximately 4 hours. Per AOGCC regulations, RIH and tag cement plug to verify depth and integrity. 2.2.8. POOH to 2600' MD. Pump 4~ balanced cement plug (kick-off plug) per cementing program on the Wellbore Diagram in Section 2. 2.2.9. POOH and PU directional drilling BHA. 2.2.10. RIH and tag cement plug. Dress off to 2200' MD. Time drill to kick-off sidetrack. RECE 'VED Nigliq #1 Colville River Field Plug Back & Sidetrack Plan Updated 03/16/01 RKB - GL = 37' Sidetrack KOP at 2200' MD 'Fop seq 99 SS at 4000' MD Bottom 98 SS at 4500' MD Top Necheliq SS at 7250' MD Well TD at 8040' MD / 7875' TVD IIII I li"lII IIIli'l i II lill ii!ii :!:,~,!! 16" Conductor to 114' I.,: !i I;iI 9-5/8" 36 ppf J-55 BTC ~ ~ Surface Casing .[{ ill II' lllllll[:' '',', il .[ I il . j., :;.]I .l r~.?..,~ :.. :;19. ~ ['?" ':b'"'2: ;' ;I I i ' .~1:1 ' i: ~lif i I '; 'l.i i:1 1II ~ .Ill;Ii l;l,;l::I ~; I' ' ~;[ '['; 'l~ I~ ~ ;:. i~ ill .i,.. i:. 'l. :.., .'.,~ l.. l"l'..., 10.4 PPG Kill Weight Mud i 10.4 PPG Weight Mud @ 2036' MD / 1989' TVD cemented to surface 5O0 ft 700 ft Top of Cement Plug #4 at +/- 2100' Plug #4: Volumes Based on Caliper Log Cement with Class G + additives @ 17 ppg. Slurry: 500' X 0,5452 ft3/ft = 272,6 ft3 => 273 Sx @ 1,00 ft3/sk Bottom of Cement Plug #4 at +/- 2600' Top of Cement Plug #3 at +/- 3900' Plug #3: Volumes Based on Caliper Log Cement with Class G + additives @ 15,8 ppg, Slurry: 300' X 0,4475 ft3/ft = 134,25 ft3 400' X 0,5452 ft3/ft = 218,08 ft3 135 ft3 + 218 ft3 = 353ft3 => 304 Sx @ 1,16 ft3/sk Bottom of Cement Plug #3 at +/- 4600' Top of Cement Plug #2 at +/- 6940' Plug #2: Volumes Based on Caliper Log Cement with Class G + additives @ 15,8 ppg, Slurry: 600' X 0,5452 ft3/ft = 328 ft3 => 282 Sx @ 1,16 ft3/sk Top of Cement Plug #1 at +/- 7540' Plug #1: Volumes Based on Caliper Log Cement with Class G + additives @ 15o8 ppg, Slurry: 500' X 0,3941 ft3/ft = 197,05 ft3 => 170 Sx @ 1,16 ft3/sk Re: Nigliq #I Subject: Re: Nigliq #1 Date: Fri, 16 Mar 2001 17:07:31 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Scoff D Reynolds <sreynol2@ppco.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak. us> Scott, We have discussed your proposal for abandoning the Nigliq #1 for sidetrack and per our discussion you have increased the length of the bottom plug by an additional 100' of -10" hole. Your proposal is acceptable and you may proceed. As discussed, we would like the intermediate plug (-4500') tagged with the Inspector present. Please have Dave or his alternate stay in contact with John Crisp to coordinate. Please plan to submit the sundry notice on Monday. The 401 for the sidetrack should also be submitted on Monday to insure it is processed as quickly as possible. Good luck with the operation and thanks for getting this to us with time to review. Please call if you have any questions. Tom Maunder, PE Petroleum Engineer AOGCC Scott D Reynolds wrote: > Tom- > Here is the document with the revisions. The file name has var 2 in it so you can keep both for your records. (See attached file: Nigliq #1 Plug Back & Sidetrack Plan Var 2.doc) -Scott Name: Nigliq #1 Plug Back & Sidetrack Plan Var 2. doc Nigliq #1 Plug Beck & Sidetrack Plan Var 2. doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 3/20/01 5:13 AM Nigliq #1 Colville River Field Plug Back & Sidetrack Plan Updated 03/16/01 RKB - GL = 37' Sidetrack KOP at 2200' MD , Wellhead 16" Conductor to 114' Li:..!i 9-5/8" 36 ppf j-55 BTC Surface Casing @ 2036' MD / 1989' TVD cemented to surface I 500 ft Top of Cement Plug #4 at +/- 2t0(7 Plug #4: Volumes Based on Caliper Log Cement with Class G + additives {~ 17 ppg. Slurry: 50(7 X 0.5452 lt3/ft = 272,6 fl3 => 273 Sx (~ 1.00 ft3/sk Bottom of Cement Plug #4 at +/- 2600' Top seq 99 SS at 4000' MD Bottom 98 SS at 4500' MD Top Necheliq SS at 7250' MD Well TD at 8040' MD i 7875' TVD 10.4 PPG Kill Weight Mud '.I.';, :';~ :...;:"' --~--- ;-,;....';'..~,.,, . ...:,: · :,. 1~,,~"' 700 ft . - ,.' :.~.; ' ~ · ;. , ;: · o..~ ,', " .,, :,.,.,~...,~ .... :'.'., 10.4 PPG Kill Weight Mud ; ,.,.., ', ,,,.;:,,,:,. :-",-: ,, ;':' :' ~,,, :.".. ~ ,'.' ,.,;.' ,..- , ,.,.. ,' r',~..~.' -.~ ,,, .~..,,...%., .... · ~.~.~ ;'.,..,' .,,,', ,~:..,, ~. ',,. '~ .... .:, ,,~ ,, · !:,. 500 ,",,;,;: ,,,..:'~,',,, '~ ..... ,,~'.,,.~,. · ...~...,.i, Top of Cement Plug ~3 at +/- 3900' Plug #3: Volumes Based on Caliper Log Cement with Class G + additives {~ 15,8 ppg, Slurry: 300' X 0.4475 ff3/ft = 134,25 ft3 400' X 0,5452 ft3/ff = 218.08 fi3 135 fi3 + 218 fi3 = 353ft3 => 304 Sx {~ 1.16 ft3/sk Bottom of Cement Plug #3 at +/- 4500' Top of Cement Plug #2 at +/- 6940' Plug ¢Y2: Volumes Based on Caliper Log Cement with Class G + additives ~ 15.8 ppg. Slurry: 600' X 0.5452 ft3/ft = 328 ft3 => 282 Sx {~ 1.16 ft3/sk Top of Cement Plug #1 at +/- 7540' Plug #1: Volumes Based on Caliper Log Cement with Class G + additives {~ 15.8 ppg. Slurry: 500' X 0.3941 ff3/It = 197.05 fi3 => 170 Sx {~ 1.16 ft3/sk ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : NIGLIQ #1 API number ............... : 50-103-20370-00 Engineer ................. : Dammeyer COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference .................... Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 6.40 ft KB above permanent ....... : 43.00 ft DF above permanent ....... : 43.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ,~Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 313.53 degrees 1 OO4181232 14-Mar-2001 22:25:14 Page 1 of 4 Spud date ................ : 05-Mar-01 Last survey date ......... : 14-Mar-01 Total accepted surveys...: 85 MD of first survey ....... : 0.00 ft MD of last survey ........ : 8040.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 05-Mar-2001 Magnetic field strength..: 1147.22 HCNT Magnetic dec (+E/W-) ..... : 25.45 degrees Magnetic dip ............. : 80.58 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.22 HCNT Reference Dip ............ : 80.58 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.45 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.45 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 14-Mar-2001 22:25:14 Page 2 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 117.00 0.00 0.00 3 199.00 0.20 246.41 4 292.00 0.28 215.21 5 383.00 0.23 199.14 6 562.00 0.12 327.34 7 652.00 0.09 266.96 8 742.00 0.24 140.41 9 832.00 0.58 103.98 10 922.00 0.81 118.53 11 1013.00 1.08 144.66 12 1108.00 1.06 144.28 13 1203.00 1.29 138.04 14 1299.00 0.24 160.08 15 1394.00 2.57 313.83 16 1489.00 5.15 315.02 17 1581.00 7.43 312.70 18 1677.00 10.20 311.97 19 1772.00 12.95 314.22 20 1866.00 15.29 316.60 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 117.00 117.00 0.00 0.00 0.00 82.00 199.00 0.06 -0.06 -0.13 93.00 292.00 0.09 -0.31 -0.41 91.00 383.00 -0.02 -0.66 -0.60 179.00 562.00 0.01 -0.84 -0.82 90.00 652.00 0.15 -0.77 -0.94 90.00 742.00 0.01 -0.92 -0.89 90.00 831.99 -0.57 -1.17 -0.33 90.00 921.99 -1.58 -1.59 0.67 91.00 95.00 95.00 96.00 95.00 1012.98 -3.04 -2.59 1.73 1107.96 -4.79 -4.04 2.77 1202.94 -6.71 -5.55 3.99 1298.93 -7.97 -6.54 4.78 1393.90 -6.02 -5.25 3.32 95.00 1488.68 0.37 -0.76 -1.24 92.00 1580.12 10.45 6.20 -8.53 96.00 1674.97 25.16 16.09 -19.41 95.00 1768.03 44.21 29.14 -33.30 94.00 1859.19 67.12 45.50 -49.36 21 1957.00 16.41 316.91 91.00 1946.73 22 2055.00 16.29 317.02 98.00 2040.76 23 2152.00 17.38 314.40 97.00 2133.61 24 2247.00 17.46 311.26 95.00 2224.25 25 2340.89 17.44 311.40 93.89 2313.82 26 2436.00 17.71 311.84 95.11 2404.49 27 2531.00 18.08 313.68 95.00 2494.90 28 2624.00 18.09 313.42 93.00 2583.30 29 2719.00 17.96 313.00 95.00 2673.64 30 2816.00 17.85 312.13 97.00 2765.94 91.94 63.60 -66.39 119.48 83.77 -85.22 147.54 103.86 -104.84 175.97 123.18 -125.70 204.11 141.77 -146.84 232.81 160.85 -168.31 261.99 180.67 -189.73 290.86 200.56 -210.66 320.26 220.69 -232.08 350.07 240.86 -254.05 Total displ (ft) At Azim (deg) .00 .00 .14 .51 .89 0.00 0.00 246.41 233.16 222.14 .18 .21 .28 .22 .72 224.11 230.73 224.14 195.62 157.00 3.12 4.89 6.83 8.10 6.21 1.45 10.54 25.21 44.25 67.13 91 119 147 175 204 .94 .49 .57 .99 .11 146.22 145.59 144.24 143.80 147.73 238.47 306.01 309.66 311.20 312.67 313 77 314.51 314.73 314.42 313.99 232 261 290 320 350 .81 .99 .86 .26 .07 313.70 313.60 313.59 313.56 313.47 DLS (deg 100f Srvy Tool tool qual type type 0.00 TIP - 0.00 MWD - 0.24 MWD 6-axis 0.16 MWD 6-axis 0.10 MWD 6-axis 0.18 0.12 0.34 0.46 0.32 0.55 0.02 0.28 1.12 2.93 2.72 2.49 2.89 2.93 2.56 1.23 0.13 1.37 0.99 0.05 0.32 0.71 0.09 0.19 0.30 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis FfWD 6-axis' MWD 6-axis [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 14'Mar-2001 22:25:14 Page 3 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) 31 2911.00 17.70 312.11 95.00 2856.41 32 3007.00 17.62 313.33 96.00 2947.88 33 3102.00 17.83 312.93 95.00 3038.37 34 3198.00 18.13 313.72 96.00 3129.68 35 3293.00 18.05 313.16 95.00 3219.99 36 3388.00 17.84 312.83 95.00 3310.37 37 3480.00 17.68 313.79 92.00 3397.98 38 3577.00 17.64 312.01 97.00 3490.41 39 3675.00 17.41 314.49 98.00 3583.86 40 3769.00 17.52 314.01 94.00 3673.53 41 3864.00 17.30 314.17 42 3960.00 17.24 313.17 43 4055.00 17.09 313.44 44 4150.00 17.14 314.01 45 4244.00 16.94 313.16 46 4338.00 16.99 311.98 47 4434.00 17.04 311.90 48 4529.00 16.81 311.61 49 4624.00 16.70 311.47 50 4719.00 16.64 310.70 51 4815.00 16.53 310.57 52 4910.00 16.19 309.66 53 5005.00 15.55 314.17 54 5100.00 15.25 315.00 55 5195.00 14.15 314.92 95.00 96.00 95.00 95.00 94.00 94.00 96.00 95.00 95.00 95.00 Displ +E/W- (ft) ---- 379.07 260.31 -275 408.19 280.07 -296 437.11 299.84 -318 466.74 320.17 -339 496.24 340.46 -361 56 5290.00 12.58 314.91 57 5385.00 11.08 314.85 58 5477.00 9.18 313.71 59 5575.00 8.98 312.63 60 5671.01 7.31 310.76 525.51 360.42 -382 553.57 379.66 -402 582.99 399.69 -424 612.49 419.91 -445 640.70 439.59 -466 3764.18 669.13 459.37 -486 3855.85 697.62 479.05 -507 3946.62 725.66 498.28 -527 4037.41 753.62 517.60 -547 4127.29 781.16 536.59 -567 808.59 555.15 836.67 573.92 864.31 592.34 891.68 610.50 918.91 628.41 4217.19 4308.99 4399.88 4490.84 4581.85 96.00 4673.86 946.27 646.25 95.00 4765.01 972.98 663.49 95.00 4856.39 998.93 680.82 95.00 4947.98 1024.15 698.53 95.00 5039.87 1048.25 715.56 95.00 5132.30 1070.21 731.07 95.00 5225.28 1089.68 744.81 92.00 5315.84 1105.85 756.12 98.00 5412.61 1121.32 766.70 96.01 5507.65 1134.91 775.76 .56 .95 .06 .62 .04 .44 .86 .42 .91 .12 .53 .15 .55 .75 .70 -587.90 -608..80 -629.43 -649.93 -670.47 -691 -711 -731 -749 -766 .26 .73 .06 .03 .08 -781 -795 -807 -818 -828 .63 .43 .01 .29 .43 Total displ (ft) At Azim ( deg ) 379.07 408.19 437.11 466.74 496.24 313.37 313.32 313.31 313.31 313.32 525.51 553.57 583.00 612.50 640.71 313.30 313.30 313.28 313.28 313.32 669.13 697.63 725.66 753.62 781.17 313.36 3'13.37 313.37 313.38 313.39 808.59 836.67 864.32 891.69 918.93 313.36 313.31 313.26 313.21 313.15 946.30 973.03 998.98 1024.20 1048.29 313.07 312.99 312.96 313.00 313.05 1070.24 1089.70 1105.88 1121.35 1134.94 313.09 313.12 313.14 313.14 313.12 DLS (deg 100f 0 .t6 0.39 0.26 0.40 0.20 0.25 0.36 0.56 0.80 0.19 0.24 0.32 0.18 0.18 0.34 0.37 0.06 0.26 0.12 0.24 0.12 0.45 1.46 0.39 1.16 1.65 1.58 2.08 0.27 1.76 Srvy Tool / tool qual ) type type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5765.00 5.91 310.29 62 5861.00 4.25 312.55 63 5956.00 2.33 318.76 64 6051.00 0.89 4.02 65 6146.00 0.89 11.08 66 6242.00 0.94 9.08 67 6337.00 1.06 12.00 68 6432.00 0.86 5.10 69 6527.00 0.58 343.93 70 6621.00 0.20 355.84 71 6717.00 0.37 125.23 72 6812.98 0.57 122.79 73 6907.00 0.51 143.38 74 7001.98 0.49 122.92 75 7097.23 0.47 135.86 76 7197.00 0.56 116.66 77 7286.90 0.53 117.18 78 7383.00 0.50 107.11 79 7478.00 0.51 98.11 80 7574.00 0.67 88.26 81 82 83 84 Last 14-Mar-2001 22:25:14 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) Page Total At displ Azim (ft) (deg) 93.99 5601.01 1145.72 782.79 -836.65 1145.75 313.10 96.00 5696.63 1154.21 788.40 -843.04 1154.24 313.08 95.00 5791.47 1159.65 792.23 -846.90 1159.69 313.09 95.00 5886.43 1162.04 794.42 -848.13 1162.07 313.13 95.00 5981.42 1162.91 795.88 -847.93 1162.93 313.19 6077.41 6172.39 6267.38 6362.37 6456.37 96.00 95.O0 95.00 95.00 94.00 1163.76 797.39 -847.66 1163.77 313.25 1164.66 799.02 -847.36 1164.66 313.32 1165.56 800.58 -847.11 1165.56 313.38 1166.42 801.76 -847.18 1166.42 313.42 1166.95 802.38 -847.33 1166.95 313.44 1166.77 1165.99 1165.12 1164.30 1163.51 802.37 -847.08 1166.77 313.45 801.93 -846.43 1165.99 313.45 801.34 -845.79 1165.12 313.45 800.78 -845.19 1164.30 313.45 800.28 -844.58 1163.51 313.46 96.00 95.98 94.02 94.98 95.25 6552.37 6648.35 6742.36 6837.34 6932.59 99.77 7032.35 1162.64 799.77 -843.86 89.90 7122.25 1161.82 799.38 -843.10 96.10 7218.34 1161.01 799.05 -842.30 95.00 7313.34 1160.30 798.87 -841.49 96.00 7409.33 1159.56 798.83 -840.50 7668.00 0.65 77.98 94.00 7764.00 0.74 73.68 96.00 7860.00 0.77 65.69 96.00 7954.00 0.91 59.81 94.00 survey extrapolated to TD: 86.00 85 8040.00 0.91 59.81 1162.64 313.46 1161.82 313.48 1161.01 313.49 1160.30 313.51 1159.56 313.54 7503.33 1158.87 798.95 -839.43 1158.87 313.58 7599.32 1158.25 799.24 -838.30 1158.25 313.63 7695.31 1157.69 799.68 -837.12 1157.70 313.69 7789.30 1157.25 800.32 -835.90 1157.25 313.75 7875.29 1156.86 801.00 -834.72 1156.88 313.82 4 of 4 DLS Srvy Tool (deg/ tool qual i00f) type type 1.49 1.74 2.05 1.91 0.12 0.06 0.14 0.24 0.40 0.41 0.54 0.21 0.21 0.19 0.12 0.19 0.03 0.10 0.08 0.20 0.13 0.11 0.11 0.17 0.00 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [(c)2001 Anadrill IDEAL ID6_iC_08] SVY# 51 52 53 54 55 56 57 58 59 6O 61 62 63 64 65 66 67 68 69 7O 71 72 73 74 75 76 77 78 79 8O 81 82 83 84 85 86 87 88 89 9O 91 92 93 94 95 96 97 98 99 100 NIGLIQ #1 INTEQ Measured Angle Azimuth Depth deg deg 4910.00 16.19 309.66 5005.00 15.55 314.17 5100.00 15.25 315.00 5195.00 14.15 314.92 5290.00 12.58 314.91 5385.00 11.08 314.85 5477.00 9.18 313.71 5575.00 8.98 312.63 5671.00 7.31 310.76 5765.00 5.91 310.29 5861.00 4.25 312.55 5956,00 2.33 318,76 6051.00 0.89 4.02 6146.00 0,89 11.08 6242.00 0.94 9.08 6337.00 1.06 12.00 6432.00 0.86 5.10 6527.00 0.58 343,93 6621.00 0.20 355.84 6717.00 0.37 125,23 6812.98 0.57 122,79 6907.00 0.51 143.38 7001.98 0.49 122.92 7079,23 0.47 135.86 7197.00 0.56 116.66 7286.90 0,53 117.18 7383.00 0.50 107.11 7478.00 0.51 98.11 7574.00 0.67 88.26 7668,00 0.65 77.98 7764.00 0.74 73,68 7860.00 0.77 65.69 7954.00 0.91 59.87 8040,00 0.91 59.87 TVD-RKB 4765.01 4856.40 4947.98 5O39.87 5132.30 5225.28 5315.84 5412.61 5507.64 5601.01 5696.63 5791,47 5886.43 5981.42 6077.41 6172.40 6267.38 6362.38 6456.37 6552.37 6648.35 6742.36 6837.34 6914.59 7032,35 7122.25 7218.35 7313.34 7409.34 7503.33 7599.32 7695.32 7789.31 7875.29 >>PROJECTED TO TD>> TVD Subsea 4722.01 4813.40 4904.98 4996.87 5089.30 5182.28 5272.84 5369.61 5464.64 5558.01 5653.63 5748.47 5843.43 5938.42 6034.41 6129.40 6224.38 6319.38 6413.37 6509.37 6605.35 6699.36 6794.34 6871.59 6989.35 7079.25 7175.35 7270.34 7366.34 7460.33 7556.32 7652.32 7746.31 7832.29 Alaska State Plane Coo~inates X Y ff 368892.08 6003682.16 368873.06 6003699.82 368855.40 6003717.84 368838.65 6003735.17 368823.38 6003750.95 368809.82 6003764.93 368798.45 6003776.44 368787.36 6003787.22 368777.39 6003796.46 368769.29 6003803.63 368763.00 6003809.35 368759.20 6003813.25 368758.02 6003815.46 368758.24 6003816.91 368758.53 6003818.42 368758.87 6003820.04 368759.14 6003821.60 368759.09 6003822.78 368758.96 6003823.40 368759.20 6003823.38 368759.85 6003822.94 368760.48 6003822.34 368761.06 6003821.76 368761.55 6003821.35 368762.39 6003820.73 368763.15 6003820.33 368763.94 6003819.99 368764.75 6003819.79 368765.73 6003819.73 368766.80 6003819.84 368767.94 6003820.11 368769.13 6003820.53 368770.36 6003821.14 368771.55 6003821.81 N/-S ff 663.50 680.83 698.53 715.57 731.07 744.82 756.12 766.70 775.77 782.80 788.40 792.24 794.42 795.88 797.39 799.02 800.59 801.76 802.38 802.37 801.94 801.35 800.79 800.38 799.78 799.39 799.06 798.88 798.84 798.96 799.25 799.69 800.33 801.01 E/-W ff -711.72 -731.05 -749.O2 -766.08 -781.63 -795.43 -807.00 -818.28 -828.42 -836.64 -843.03 -846.90 -848.12 -847.93 -847.66 -847.35 -847.11 -847.18 -847.32 -847.08 -846.42 -845.78 -845.19 -844.69 -843.84 -843.08 -842.28 -841.47 -840.48 -839.41 -838.28 -837.10 -835.88 -834.70 313.53 DLS deg/100 ff 0.45 1.46 0.39 1.16 1.65 1.58 2.08 0.27 1.76 1.49 1.74 2.05 1.91 0.12 0.06 0.14 0.24 0.40 0.41 0.54 0.21 0.21 0.19 0.14 0.16 0.03 0.10 0.08 0.20 0.13 0.11 0.11 0.17 0.00 Ve~. Sec ff 972.98 998.93 1024.16 1048.25 1070.21 1089.68 1105.85 1121.32 1134.91 1145.72 1154.21 1159.65 1162.05 1162.91 1163.76 1164.66 1165.56 1166.42 1166.95 1166.77 1165.99 1165.12 1164.30 1163.66 1162.63 1161.81 1161.01 1160.29 1159.55 1158.86 1158.24 1157.68 1157.24 1156.85 >> Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Nigliq # 1 Phillips Alaska, Inc. Permit No: 201-036 Sur. Loc. 156'FSL, 1031'FWL, Sec. 2, T12N, R4E, UM Btmhole Loc. 4260'FNL, 4975'FEL, Sec. 2, T12N, R4E, UM . Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice maybe given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE CO~MISSION DATED this 3~--- day of March, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Subject: Nigliq #1 Date: Tue, 27 Feb 2001 09:55:41 -t000 From: "Scott D Reynolds" <sreynol2@ppco.com> To: tom_maunder@admin.state.ak, us Tom, Just a heads up. I received the as-staked for Nigliq #1 and the surface location changed 51' North and 140' east of the planned surface location used for the APD. After some discussions with our geologists, I am planning to push the surface casing setting depth down to 2100' MD (2085 'I'VD). This will put me in the middle of a shale section which will give me a better shoe. It is also a better location after looking at isolating the shallower water bearing zones. If you need any further details, give me a call. Regards, Scott Reynolds Drilling Engineer, Alpine. 1 of 1 2128101 12:04 PlY Nkjliq #1 Subject: Nigliq #1 Date: Tue, 27 Feb 2001 09:55:41 -1000 From: "Scott D Reynolds" <sreynoi2@ppco.com> To: tom_maunder@admin.state.ak.us Tom, Just a heads up. I received the as-staked for Nigliq #1 and the surface location changed 51' North and 140' east of the planned surface location used for the APD. After some discussions with our geologists, ! am planning to push the surface casing setting depth down to 2100' MD (2085 TVD). This will put me in the middle of a shale section which will give me a better shoe. It is also a better location after looking at isolating the shallower water bearing zones. If you need any further details, give me a call. Regards, Scott Reynolds Drilling Engineer, Alpine. 1 of 1 2/27101 10:11 AI~ To; Subject: Date: ~ ?i~,{lL i>qSAlas(a, h'~c Dave Barman I.aurie St Aubin Wayne Campaign Shallow salinities in the Nigliq area Feb. 26. 2001 Fhis document will discuss the evaluation of shallo,x aquifers in selected North Slope well logs. The purpose is to demonstrate that the casing progran~s intended ibc this year's x~ells will protect potential aquifizrs. Further objective is to identif~ and map these potential aquifers fur fL~ture refere~ces, or to document the absence of such aqui~brs if that is deemed to be tile case Several wells have been selected t'~>r this study These wells have been picked base on the presence of sufficient shalloYx' logs. and for geographic coYerage over the area of Exploration interest to Phillips. The logs have been evaluated ~br water salinities using coIllll]Oll techniques to the industo and specified ill the EPA docl~:Bellt. ARCO Colville River St. #1 One fhcet of this exaluation is m~ique to the arctic. 2he Pennai?ost Pick first step is to select the base of Permafrost tt seems the sands f?eeze while tile shales do not This makes the shales conductive and the sands resistive. Ii1 the past, inally have picked Permat?ost based on a simple resistivity cutoff; usually 100 fire's. When possible, 1 have employed sorbic information as well. Ice consolidates these uncompacted sands and the sonic displays ihster travel times. Below the frost level, the sands show travel times similar to the shales This example fi'om the ARCO Colviile River State #l illustrates this. Note lhat a simple resistivity cutoff would place Base Pem~afi'ost m~[ch higher Keep in mind. this only represents a ;'Ice-dox~a~-to" pick. There must be sand present in the section for the permafrost to be detected by any means short of a stabilized temperature sm",ey. In fact, temperature data collected fi'om Alpine suggests permafrost to be significantly deeper than these techniques have implied. Frozen sallds will present high resistivities fc>r reasons other than low salinity. Calculations will be meaningless. ,1: PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Also, the sands would not flow anything and could not be considered aquifers. Similar meaningless results would occur with the presence of hydrates, though they can exist at temperatures above freezing and just below actual permafrost. These situations need to be identified and excluded from this work. Two methods are used in this evaluation. The "Rw Apparent" or Rwa technique re-writes the Archie equation Ro = a*Rw/~TM to solve for Rw. The assumptions are; the sand is 100% water bearing (that is the implication of the term Ro to represent the sand resistivity), and no excess conductivity (shale) in the system. Porosity (~) is derived fi.om Neutron-Density crossplot when available, but more often from the sonic, as it is more common in the shallow sections. For sonic porosity, I use an adaptation of the "Hunt-Raymer" algorithm ~' · = 0.6* (AT-56)/AT Other assumptions include values for a and m (cementation exponent). The EPA document uses the Humble formulation (a = 0.62 and m = 2.15), and I have used that here. I use a temperature gradient of 2.1° F per 100 feet. I have also converted all water resistivities to 75° F for easier comparison, and calculated salinities to kppm Total Dissolved Solids. Rwa has also been calculated in the shales. Porosities will be overestimated and mineral conductivity will be a factor, but these are opposing effects and the result will still be at least a qualitative measure of the fluid properties. The second technique uses the Spontaneous Potential (SP) curve. This curve measures the electric potential created by salinity contrasts between invading mud filtrate and connate water. Bounding shales serve as semi-permeable membranes, which enhance the reaction. Other effects on the SP are shale content of the sand, sand permeability and thickness, invasion, and hydrocarbon content. Empirical charts are available that attempt to correct SP for these and other effects, but I have used the SP directly. Understand, that overlooking shaliness will suppress SP and result in a salinity too low, thus providing a lower limit. One further issue with the SP is that it often will wander, especially in these shallow sections. To straighten, or "baseline" the SP curve is a standard procedure, though may be somewhat subjective in extreme cases. Continuous water resistivity curves have been calculated for those wells with sufficient data, to a depth of 4000'. Sands with maximum SP excursions have been calculated with the SP technique as a check. Other wells have been calculated with the data available and conclusions drawn. Following are results for the wells around the Nigliq location. The presentations are X-Y plots of Rwa corrected to 75°F, versus measured depth. Where possible, SP estimates have been included as spot checks. The colors represent the Volume shale as determined from standard log analysis. Also included is a small discussion on each well. From this and other work, we conclude there are no fresh water aquifers below planned casing point. Phillips Alaska, Inc. is a Subsidiary of Phillips Petroleum Company Mr. Wayne Campaign February 28, 2001 Page 3 Reference Raymer, lJ.., Hunt ER., & Gardner JS.~ "An Improved Sonic Transit Time-to-PorosiU Transform". ']'~'ansuctions qf the .%'PI,~ZA 21 ~ Armua/ Logging Svmpo,s'ium (1980). RWA / DEPTH Crossplot W~lh NECHEL~K~I RwA Nechelik #1 This well has a number of sands just under the pe~t~afrost. Raw resistivities drop to 2 ~m by 1300', indicative ofsal~' waters, which shows also in the Rwa calculation above 1700'. I have also run SP calct~lations in the first log run section (200'-2700'). These values are systematically higher than the Rwa. and i suspect improper measurement of the surfi~ce nmd samples. In this section of the well the mudcake measurement is reported as more conductive than the filtrate, an unusual situation if m~e. On the second togging run, the SP appears ~o be a reverse resistivity curve and no~ a valid measurement of salinity. Unibi~unately, this problem is not unusual in the arctic or ofl~hore, where proper grounding may be difficult to achieve. Still, the Rwa calculated tbr the shales indicate saline waters and no sands. In the sands from Permaffos~ to 1700', Rwa ~ 75~'F averages 0.25 ~m for a salinity of 24 Kppm TDS. Below 1700' there are t~x* sands and average Rwa (~ 75°F is 0.35 ~m ibr a satinily of 17 Kppm TDS. Phillips Alaska, thC is a Subsidiary of Philtips Petroleum Company Mr. Wayne Campaign February 28, 2001 Page 4 RWA / DEPTH Crossplot Temptatiol~ #1 Unfortunately, there are fkw sands in the shallow section of this welt and this LWD data does not have an SP. However, we can h)ok at the Values of Rwa calculated in the shales as indication of the expected saiinides .r~r this section. Average Rwa of 0.3 Clm at 75°F results in a salinity of 20 Kppm TDS. 'Ibis data starts at the casing shoe depth of 1820' MD. ']'his analysis indicates high salinities and no sands to serve as aquifers. Wayne Campaign Sr. Staff' Petrophysicist FIT 12.01 1000 2000 3OOO 4OOO '"' 5000 6000 7OOO 8OOO 9OO0 10000 DRILLING TIME AND MUD WEIGHT CURVE PAl Spark #1 L .......... ___ . ' _ ; ..... !-:-_i_~ Move ~n ng 3/21/2000f ,'___ ; : : ] -~ .... : ....r- ~ ~ : : 7- : i .......... : ....! ....... ~ ....; ................. ; Run 7-5/8" Surf. ............. .._ .... ! , I~- -:: .... -:~ .... ~, .... :-, .... ,i{t FIT15.9 --~-- : : ' '_ ..................... ; ........ _: ........ ] .... _.:_ .'-~-- Depth ~'-Mud Weight Plug back · Wt. Up f/sloughing shale ' 12.0 11.8 11.6 11.4 · 11.2 11.0 - ..................... 10.8 · .... .............................. 10.6 . - - 10.4 : .... ~iii~i;~ ! __~i;ii:~i;~_ ~':__i_i-;-' '_ '~:i.~ ~ 10.2 __~ .......... ; ;_ __; .... . .......... ;_ . ; ', : ~ : i · . : 10.0 ' ' [__ '_ .--;;:'i i '.-__':' : ':i' ~ 9.8 , ~ ~ ....... . 9.6 i i ...... i .......... '~ F .... ; ..... , .... ~ .... ',- -;-- ~ .... ~ .... ,..- ..... ,, ,, ....i : ' .:- - ~ r ...... : .... -,'~ .... . ....... : ..... · . ........ ~ ~ .... ] , , ,' , ~ , ; I ; ; ; i ; : ; : : ~ '. ~ ~. .~ ~. .~ &. .~ =. ~. ' : ~- 8.8 ~____ ,, ___~ .... L .... ; .... .... ~ .... ~ L .... , ...... 8.6 i i i i ; : ; i ; ~ .......... :--- i----~-¥-~ : : ' ' i .... ~- : --~ .... ~ ....; ....:--- < .... ; ....'- .... : : --{ .... -:---: ~' .... ; ....~- t I ..... : .... t · i .... '. ..... : .... : .... r---~---:Jholeopenerrun: 8.4 r .... i--1 -! .... !---i .... i-' : ~ '! ;. ...................... ~ .... ~ ......... I .................... ~ .................. 4 ; :_ ......... 5__ ~ ; .... : ....... ; _~ ___k__ ; ...... ; ...... i - ' . : ; i : : : : I : ' : 0 5 10 15 20 25 30 35 40 45 TIME TO DRILL (DAYS) jt 9/99 Pressure psi 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000 12,000 13,000 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,0~0 11,000 12,000 13,000 : -. Frac Gradients · ,. .: -.: Res Prs from Mud Wgt · ': .. ~',~X Seal-A-01 -'" · ScaI-A-O I X ScaI-A]02 ( )1 I · . ; o ScuI-A-O2 ()11 -. X Seal-A-02 RI) ~ ' ~' - ' ' ' '= · Seal-A-C)2 RI) ' X Seal-^-03 · :' · Seal-A-l)3 :- ' X .goal-A-04 " ' · Sc:d-A-04 · ' X Norih Star I X := "':' ' ~ NorlJl .%ltir I X Northstar 2 · · ,: ..... .;: ~.: ~: · '".. '~. ':.' -" --;,-...il:: .~', :-:'..!iii:':- :'ii........:....-" :..:'ii: '" "::~-i::" :)', ...... Reservoir~ __Prs ~from DST ,:. · - -: )i ::.---':~ :' - :'-: · a s~.l-A-0~ :' · :'~'.'.:'~':i'.. ':!:- - '. ' '."i" a · . ' ', ~ ~,1.- . [ ]~. · · .. . ::'-. ...:. ..i' :. . pressure .~. ~ ...~~: . :. ::: :-- ;- :::..... ': - :.-,.,-: .... : ~c~.:i---,i~[:.:_~-~os~.__:..,..:~-- ---- ':" .... ' ~[ fracture pressure grad~en '- . ".~. . - ':. 'x .... :: ,--.. ~-'.,. ~,:~:-::,::~'..:-: ~:~"-.~'-::::f~;- gradient i :~:-.. .-,<: ..:.'.-.i-_..'~... :. ::: ?...,..:_?,l;.=. ;~:.;:~- .... .,~ ...... - ..... ~aeh Fm I - - ::. ". ';-:::.-,-;z::,.-:r ;~.. : ...... ; ......... .:. ...... 1, ishakSa~m.J~iver !'m' :; .::-. ~.~: .:~. t>¢. · · Frac Gradients ~,, Seal-A-01 Seal-A-(~2 OH Seal-A-02 RD Seal-A-03 Seal-A-04 North Star 1 Northstar 2 Res Prs from Mud Wgt Seal-A-01 Seal-A-02 OH Seal-A-02 RD · Seal-A-03 Seal-A-04 North Star 1 Reservoir Prs from DST A Seal-A-01' .. Seal-A-02 OH A Seal-A-03 A North Star 1 11,000 Nigliq #1 Subject: Nigliq #1 Date: Wed, 14 Feb 2001 13:50:07 -1000 From: "Scott D Reynolds" <sreynol2@ppco.com> To: tom_maunder@admin.state.ak.us CC: "Chip Alvord" <calvord@ppco.com> Tom, With the recent changes to the exploration drilling schedule, Doyon 19 will replace Nabors 14E as the drilling rig utilized to drill the Nigliq #1 exploration well. I believe all of the necessary rig documentation is on file at your office. If you need any further information, give me call. Regards, Scott D Reynolds Drilling Engineer, Alpine 1 of 1 2/14/01 3:07 PM Nigliq cemen~ volumes Subject: Nigliq cement volumes Date: Wed, 14 Feb 2001 11:07:11 -1000 From: "Scott D Reynolds" <sreynol2@ppco.com> To: tom_maunder@admin.state.ak.us CC: "Chip Alvord" <calvord@ppco.com> Tom- I recalculated the cement volumes for the surface casing of Nigliq #1. The 7" looked good. ! am attaching the permit to drill file so you can see the changes made on the cement calculations page. I also fixed the numbers on the form but it lacks any sort of signature. (See attached file: Nigliq_~l_ Permit Information.df) -Regards Scott Name: Nigliq..~l_ Permit Information.rtf ~Ninlin ~'1 p~.rmif Infnrrnnfinn rffl Type: Rich Text Format (application/rtf) ~""~"'~ .............................. I Encoding' base64 IDescription: Rich Text Format 1 of 1 2/14/01 1:50 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F' E B 092001 PERMIT TO DRILL 20 AAC 25.005 Aiaska Oii& Gas Cons. Co~,nmission la. Type of Work Drill X Redrill I lb Type of Well Exploratory X Stratigraphic Test Ar~'?'0rSC3~velopment Oil Re-Entry DeepenI Service Development Gas Single Zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool PHILLIPS Alaska, Inc. DF 43' feet 3. Address 6. Property Designation N/A P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380092 ,"~'~- 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 ACC 25.025) 156' FSL, 1031' FWL, Sec.2, T12N, R4E, UM N/A Statewide At target (=KUP LCU ) 8. Well number Number 1019' FSL, 320' FEL, Sec. 2, T12N, R4E, UM Nigliq #1 59-52-180 At total depth 9. Approximate spud date Amount 4260' FNL, 4975' FEL, SEC 2, T12N, R4E 2/12/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line 8691' MD Temptation lA is 10250' 323 ' from feet Feet 2560 8543' TVD feet Ad L380092 ,'~ ~ 60 ,Z~v/ 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2~)) ' ' -~ Kickoff depth 1 300' feet Maximum hole angle 1 6.29° Maximum surface ~ psig At total depth (TVD) 401 5 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data) 20" 16" 62.5# H-40 Weld 80' 37' 37' 117' 117' +/- 200cf 12.25" 9.625" 36# J-55 BTC 1963' 37' 37' 200.~r/j~...,..,~,.,., ~,~,,~ r 230347 sxSX ArcticSetclass G III L & 8.5" 7" 26# L-80 BTC-MOE 8654' 37' 37' 869~''~'~ ~' r8543' 311 Sx Class G N/A 3.5" 9.3# L-80 8rd-Mod 7034' 32' 32' 7066' 6918' tubing 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 Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drilling Team Leader Date Commission Use Only I., - er Isee c°ver'etter f°rother Permit Number APl number Approval date ,.~ ~o/-~G so- /"o ~- 2_0%'70--0o requirements Conditions of approval Samples required ('~'-,¢ No Mud Icg required /~'~'3 No Hydrogen sulfide measures , ~"¢e;" ' ~~ Directional survey required ~(-'""/ No Required working pressure for DOPE . ' /'/J~ 2M<.~,~¢:~L.,_~.,. 3M ~ 10M 15M Other: ,--, ~ r~' ~,~ '.~ 1 ~,~r¢~:~li~ ~ '" ~' i... :;.~ ~",'K:.;!'. t'.~i.;.;,'.!7~¢:~ by order of ~Appro.ve~d.?. ...._~ ~.,t, ,~;.,, ........... Commissioner the commission Date 3"'-~2~, Form 10-401 Rev. 7-24-89 Submit in triplicate Niqli~ #1 Summary Drillin.q Procedure . . . . . . 10. 11. 12. 13. 14. 15. Install diverter on pre-installed 16" conductor. Move in and rig up Nabors 14E. Function test diverter. Spud and directionally drill 12 1/4 inch hole to the 9-5/8" surface casing point (2000' MD / 1989' TVD) per the directional plan. Run MWD/LWD logging tools as required for directional monitoring and for gathering formation data. Run and cement 9 5/8", 36#, J-55, BTC casing string to surface. A TAM port collar will be placed approximately 1,000' TVD below the surface. The port collar will only be used if cement does not circulate to the surface. If it is determined that cement is above the port collar, a top job authorized by the AOGCC may be performed in lieu of the port collar. Install and test BOPE to 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe pr 20 ACC 25.030 (0.5 ppg less than the FIT or LOT EMW) Directionally drill the 8-1/2" hole to 8691' MD per the directional plan. Cut possible core through the Nechelik. Run open hole evaluation logs as required by the logging plan. Depending on Kuparuk C and Nechelik upside well may be plugged back and sidetracked per "Nigliq #1 Major Operations Decision Tree" If the well is to be sidetracked, a P&A plan and a directional plan will be formulated for approval by the AOGCC prior to sidetracking. If the well is to be tested, run and cement 7", 26# BTC-Mod production casing. Pressure test the casing to 3500 psi. Go to step 11 If the well will not be tested, P&A the well per AOGCC regulations. Go to step 14. Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU tree and test to 5000 psi. Shut in and secure the well. RDMO Nabors 14E. Hook up well for flow testing to surface tanks. Produced fluids will be trucked to Alpine or Kuparuk production facilities. Test zones as appropriate, abandoning each using a CTU. When complete, plug and abandon the well per AOGCC regulations. RDMO CTU. NOTE: P&A may be completed with the rig if no testing is conducted. Thoroughly clean location and block off access ice road. FEB 0 9 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Well Proximity Risks: There are no well proximity risks associated with Nigliq #1. Drillinq Area Risks: Examination of six of the seven nearest offset wells: (Fiord #1, #3/3A, #4, #5), Nechelik # 1, Temptation #1/1A, reveal no subsurface shallow hazards such as abnormal pressure or lost circulation zones. For the offset well, Fiord #2, a gas influx was encountered at a depth of 2915' MD (2500' TVD). The gas influx occurred 684' below the base of the surface casing which was set at 2231' MD (1989' TVD). The mud weight at the time of the gas influx was 9.2 ppg. The well was shut-in with 50 psig on casing & 25 psi on drill pipe. The kill weight mud needed to kill the well was 9.4 ppg. The mud was weighted up to 9.7 ppg and the gas influx was circulated out. A flow check indicated the well was dead. The planned mud weiqht of 9.7ppg to 10.1ppg for Nigliq #1 is sufficient to mitigate possible occurrences of this nature on Nigliq #1. No weak formations have been experienced, particularly at shallow depths in the offset wells. The mud weights planned for Nigliq #1 are conservatively based on pore pressures determined from RFT data obtained from the closest offset wells Temptation #1/1A and Nechelik #1. Further examination of drilling area risks will be performed as soon as the "Shallow Hazards Analysis" for Nigliq #1 is completed. Upon completion, the results will be promptly forwarded to the AOGCC for review. Nigliq #1 DRILLING FLUID PROGRAM SPUD to Intermediate hole to TD Potential Sidetrack 9-5/8"surface casing 8 Y2" Hole Section Section - 8 Y2" Hole point - 12 ¼" Density 9.7- 10.1 ppg 9.9- 10.4 ppg 9.9 - 10.4 ppg PV 16 - 26 10 - 25 10 -25 YP 20-60 15-25 15 25 Funnel Viscosity 80 - 300 30 - 40 30 - 40 Initial Gels 40 - 90 4 - 8 4 - 8 10 minute gels 90 - 115 <18 <18 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) 4 - 12 cc/30 min (drilling) PH 8.5 - 9.0 9 - 10 9 - 10 % Solids _+ 10% 4 - 7% 4 - 7% Drillinq Fluid System: 3 High speed shale shakers, one 2 cone de-sander, one 16 cone mud cleaner, one high volume centrifuge and a Trip Tank. Safety features include a Pit Level Indicator with visual and audible alarm, flowline flow sensor and a six sensor Gas Monitoring System with audible and visual alarms. Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 10.1 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 10.3 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Niclliq #1 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 117 / 117 11.0 51 55 9 5/8 2000 / 1943 13.5 913 1170 8-1/2 hole 8691 / 8543 16.8 4015 N/A · NOTE: Nabors 14E 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") FEB 0 9 001 Alaska Oil & Gas Cons. Con, mission .Anchorage ASP = [(FG x 0.052)-0.1} D = [(11.0 x 0.052) - 0.1] x 117 = 55 psi OR ASP = FPP- (0.1 xD) = 913 - (0.1 x 1943') -- 719 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(13.5 x 0.052)-0.1] x 1943 = 1170 psi OR ASP = FPP- (0.1 x D) = 4015 - (0.1 x 8543) -- 3160 psi CASING PROPERTIES. Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 27992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi Wt Connection TENSILE STRENGTH OD (ppf) Grade Range Type JOINT BODY 9-5/8" 36 J-55 3 BTC 394k lbs. 564k lbs 7" 26 L-80 3 BTC-Mod 364k lbs 415k lbs Casing Setting Depth Rational 16"- 117' RKB 9-5/8" - 1989 TVD' RKB 7"- 8533 TVD' RKB Conductor Casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to the next casing setting point. 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 there is not an upside potential indicating a well test should be carried out. Alaska Oil & Gss Cons. Commission Anchorage NIGLIQ #1 Well Cementinq Requirements 9 5~8" Surface Casing run to 2000 MD 1 1989' TVD. Cement from 2000' MD to 1500' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1500' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: 1500' X 0.3132 ft3/ft X 4 (300% excess) = 1879.2 ft3 above permafrost Total volume = 1879.2 ft3 => 423 Sx @ 4.44 f¢/sk System: 423 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: (2000-1556) X 0.3132 ft3/ft X 1.5 (50% excess) = 208.6 ft3 below permafrost (1556'- 1500') X 0.3132 f¢/ft X 4 (300% excess) = 70.2 ft3 above permafrost 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 208.6 ft3 + 70.2 ft3 + 34.7 frs= 313.5 ft3 --> 268 Sx @ 1.17 ft3/sk System: 268 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 868~MD /8S=33' TVD Cement from .~ MD to +/- 6766' MD (minimum 500' MD above top of Nechelik formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8681'-6766')oX 0.1268 ft3/ft X 1.4 (40% excess) - 340 ft3 annular volume 80' X 0.2148 fi°Iff = 17.2 ft3 shoe joint volume Total volume - 340 + 17.2 - 357 f¢ -> 311 Sx @ 1.15 ft3/sk System: 311 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersa~nt, 0.25% D800 retarder O "~ and 0.18 Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk ~ By Weight Of mix Water, all other additives are BWOCement NIGLIQ #1 Well Cementinq Requirements 9 5/8" Surface Casing run to 2437 MD / 2400' TVD. Cement from 2437' MD to 1937' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1937' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1937'-1556') X 0.3132 ft3/ft X 1.5 (50% excess) = 179 ft3 below permafrost 1556' X 0.3132 ft3/ft X 4 (300% excess) = 1949.4 ft3 above per_mafrost Total volume - 179 + 1949.4 - 2128.4 ft3 :> 480 Sx @ 4.44 ft~/sk System: 480 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (5~0% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft° shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft~ -> 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft~/sk 7" Intermediate Casing run to,~ll MD / 8/,5S~' TVD ~'~,ql /~. Cement from 8,66~1' MD to +/- 6766' MD (minimum 500' MD above top of Nechelik formation) with Class G + adds @ 15.8 15PG.. Assume 40% excess annular volume. ,, Slurry: (8681' - 6766')o X 0.1268 fts/ft X 1.4 (40% excess) = 340 ft~ annular volume ,"'80' X 0.2148 ft°/ft = 17.2 fts shoe joint volume "' Total volume = 340 + 17.2 = 357 ft3 => 311 Sx @ 1.15 ft3/sk ,,, ,~ 311 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder o 3 and 0.18 Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk %,...) FEB 0 9 2001 Alaska Oil & Gas Cons. Commissior, .Anchorage ~ By Weight Of mix Water, all other additives are BWOCement Ni.qliq #1 Drillinq Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5~8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Moderate Monitor cellar continuously during interval. Well Collision None N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps, run gravel isolation string. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations > 1989' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole / 7" Casin~ Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Moderate BOPE drills, Keep mud weight above 9.7 Surface Formations ppg. Check for flow during connections and >1989' TVD if needed, increase mud weight Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. 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 .Alaska Oil & Gas Cons. Con'~n'fissior'~ ,Anchorage Nigliq #I Drilling Hazards Summary. doc prepared by Scott D Reynolds 01/16/2001 Page I of 1 PHILLIPS Alaska, Inc. NABORS 1 4E 21-1/4", 2,000 PSI DIVERTER SCHEMATIC 4 3 2 1. 16" CONDUCTOR. 2. STARTING HEAD FLANGE. 3. DIVERTER SPOOL: 21-1/4" 2,000 PSI WP FLANGES. 4. KNIFE VALVE: 16" FABRI-VALVE. 5. ANNULAR PREVENTER: HYDRIL MSP 21-1/4", 2000 PS~ WP. FEB 0 9 ZOO1 Alaska Oil & Gas Cons. Commission Anchora9e PHILLIPS Alaska, Inc. (" NABORS 14E 13-5/8", 10,000 PSI. BOP STACK 4-1/16" ClW E~ 10,000 psi WP/ Manual Valve~ Choke~~ 5 4-1/16" CIW ~ 4 HCR / 10,000 psi WP 3 I 3-1/16" CIW 10,000 psi WP Manual Valve 10,000 psi WP 1. Landing Ring. 2. Casing Head. Alaska Oil & Gas Cons. Cornm~. ~,nchorage 5. Drilling Spool: 13-5/8" 10,000 psi WP with (1) 3-1/16", I0,000 psi WP kill line outlet & (1) 4-1/16", 10,000 psi WP choke line outlet 6. Double Pipe Rams' 13-5/8" 10,000 psi WP, Hydril MPL with pipe rams on top and blind rams on bottom. 7. Annular Preventer: 13-5/8" Hydril 5,000 psi WP top flange x 10,000 psi bottom flange. 4. Single Pipe Ram: 13-5/8" 10,000 psi WP, Hydril MPL with pipe rams. 3. Adapter Spool: 13-5/8" 10,000 psi WP x 13-5/8" 5,000 psi bottom flange. Phillips Alaska, Inc. Structure: Nigliq Well : Nigliq Field : Exploration Location : North Slope, Alaska 1200 1120 1040 960 880 800 <- West (feet) 960 880 800 720 640 560 480 4(10 320 240 160 80 0 80 160 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 1200 1120 TARGET / TD 1040 LOCATION: ,,,c,,~ 1019' FSL, 320' FWL SEC. 2, T12N, R4E 960 880 8O0 720 040 A ~6o z 48O ::3" 400 320 320 240 240 160 160 ESTIMATED SURFACE LOCATION: ~ 8o 156' FSL, 1031' F'WL SEC. 2, T12N, RCE o o;e*<~ o ,o 3 0.49 AZIMUTH ,,o 11 18' (TO TARGET) 240 ~ , , ~, , , ,, ,, ,, ,, , , , , , ~ ,, ..... , 0 , , , 240 960 880 800 720 640 560 480 400 520 240 160 80 0 80 160 <- West (feet) Ic~otoub~Jo.- For:$Relmolds[ I Date plotted: 5-dan-200f I ] Plot Reference Is Nlgliq #1 Versron I Coordinates are In feet reference slot ~1, I ~ I 720 640 A I /-,, 560 ..i-. 480 0 400 z FEB 0 9 ,!001 Alaska Oil & Gas Cons. Commission'; Anchorage 4O0 600 1200 1600 . 2000- _ 2400- _ 2800- _ 3200- . 3600- 4000 4400 48O0 5200 56OO 6000- 6400- 6800 7200 . 7600- 8000- 8400 8800 Phillips Alaska, Inc. Structure: Nigliq Well : Nigliq Field : Exploration Location : North Slope, Alaska Est. I~B Devotion: 45' KOP 2.50 5.00 7.50 DLS: 2.50 deg per 100 ft 10.00 12.50 15 O0 ~' ' EO~/8 Casing Pt ~ SeqlO0 Seqg9 5eq98 5eq97 ~. Begin Angle Drop 1 5,OO 13.50 )~ 12.00 ~, 10.50 ~ DIS: 1.50 deg per 100 ft 9.00 & 7,50 ~ 6.00 3.00 ~ 1.50 , TK/Marker DShale TGT - T/Kup C~ TOT-B/ Kup LCU Est. TD End of Drop Seqg5 HRZ B/ HRZ TGT - T/ Nechelik TGT - B/ Nechelik Creoted by jones For: S Reynolds Dote plotted: 5-Jon-2001 Plot Reference is Nlgliq #1 Version ~5. Coordlnotes ere in feet reference spot ~1. True Vertical Depths (]~'ence Est. RKB. mrgq MAXIMUM ANGLE 16.29 DEG TARGET ANGLE "VERTICAL" m m I i i I ) i 0 ~0 8OO 1200 Verflcol Section (feet) -> Azimuth 320.49 with reference 0,00 N, 0.00 E from inlet #1 Phillips Alaska, Inc. Structure: Nigliq Well: Nigliq Field : Exploration Location: North Slope, Alaska Point KOP EOC 9 5/8 Casing Pt Seq 1 O0 Seq99 Seq98 Seq97 Begin Angle Drop Seq96 End of Drop Seq95 HRZ B// HRZ K1 Marker T/ D Shale TOT- T/Kup C TOT-B/ Kup LCU TOT - T/ Nechelik TOT - B/ Nechelik J5 Est. TD PROFILE MD 1500.00 1951.79 2000.00 5766.65 5895.76 4185.59 4871.01 5061.95 5785.72 6148.27 6551.27 6879.27 7027.27 7062.27 7112.27 7152.25 7162.27 7266.25 7416.27 7875.27 8691.27 COMMENT DATA Inc Dir TVD North East 0.00 520.49 1500.00 0.00 0.00 1 6.29 520.49 1945.04 71.05 -58.57 1 6.29 520.49 1989.51 81.46 -67.18 1 6.29 .320.49 5685.00 465.89 -582.55 1 6.29 520.49 5807.00 491.41 -405.22 1 6.29 520.49 4085.00 554.11 -456.92 1 6.29 520.4-9 474-5.00 702.96 -579.67 1 6.29 520.49 4928.27 744.29 -615.75 5.44 520.49 5658.00 849.40 -700.45 0.00 520.49 6000.00 862.67 -711.57 0.00 520.4-9 6185.00 862.67 -711.57 0.00 520.49 6751.00 862.67 -711.57 0.00 520.49 6879.00 862.67 -711.57 0.00 520.49 6914.00 862.67 -711.57 0.00 520.49 6964.00 862.67 -711.57 0.00 520.49 6985.98 862.67 -711.57 0.00 520.49 7014.00 862.67 -711.57 0.00 520.49 7117.98 862.67 -711.57 0.00 320.49 7268.00 862.67 -711.57 0.00 520.49 7725.00 862.67 -711.57 0.00 520.49 8545.00 862.67 -711.57 V. Sect Deg/1 O0 0.00 0.00 92.06 2.50 105.59 O. O0 601.27 0.00 656.94 0.00 718.20 0.00 911.15 0.00 964..71 0.00 1100.95 1.50 1118.14 1.50 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 1118.14 0.00 ,'L\Iaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Nigliq Nigliq slot #1 Exploration North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : Nigliq #1 Version #5 Our ref : prop~233 License : Date printed : 5-Jan-2001 Date created : 26-Oct-2000 Last revised : 5-Jan-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 368418.218,6002816.395,999.00000,N Slot location is n70 24 58.282,w151 3 48.116 Slot Grid coordinates are N 6002955.000, E 369451.000 Slot local coordinates are 156.80 N 1030.26 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Nigliq,Nigliq Exploration,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : Nigliq ~1 Version #5 Last revised : 5-Jan-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C O O R D S G E O G R A P H I C Depth Degrees Degrees Depth C O O R D I N A T E S Eastin~ Northing C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.00N 100.00 0.00 320.49 100.00 0.00N 200.00 0.00 320.49 200.00 0.00N 300.00 0.00 320.49 300.00 0.00N 400.00 0.00 320.49 400.00 0.00N 500.00 0.00 320.49 500.00 0.00N 600.00 0.00 320.49 600.00 0.00N 700.00 0.00 320.49 700.00 0.00N 800.00 0.00 320.49 800.00 0.00N 900.00 0.00 320.49 900.00 0.00N 1000.00 0.00 320.49 1000.00 0.00N 1100.00 0.00 320.49 1100.00 0.00N 1200.00 0.00 320.49 1200.00 0.00N 1300.00 0.00 320.49 1300.00 0.00N 1400.00 2.50 320.49 1399.97 1.68N 1500.00 5.00 320.49 1499.75 6.73N 1600.00 7.50 320.49 1599.14 15.13N 1700.00 10.00 320.49 1697.97 26.86N 1800.00 12.50 320.49 1796.04 41.91N 1900.00 15.00 320.49 1893.17 60.25N 1951.79 16.29 320.49 1943.04 2000.00 16.29 320.49 1989.31 2500.00 16.29 320.49 2469.23 3000.00 16.29 320.49 2949.14 3500.00 16.29 320.49 3429.06 3766.65 16.29 320.49 3685.00 3893.76 16.29 320.49 3807.00 4000.00 16.29 320.49 3908.97 4183.39 16.29 320.49 4085.00 4500.00 16.29 320.49 4388.89 4871.01 16.29 320.49 4745.00 5000.00 16.29 320.49 4868.81 5061.95 16.29 320.49 4928.27 5148.27 15.00 320.49 5011.38 5248.27 13.50 320.49 5108.30 5348.27 12.00 320.49 5205.84 5448.27 10.50 320.49 5303.91 5548.27 9.00 320.49 5402,46 5648.27 7.50 320.49 5501.43 5748.27 6.00 320.49 5600.73 5785.72 5.44 320.49 5638.00 5848.27 4.50 320.49 5700.31 5948.27 3.00 320.49 5800.09 6048.27 1.50 320.49 5900.01 6148.27 0.00 320.49 6000.00 6331.27 0.00 320.49 6183.00 6500.00 0.00 320.49 6351.73 6879.27 0.00 320.49 6731.00 7000.00 0.00 320.49 6851.73 7027.27 0.00 320.49 6879.00 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 0.00E 369451.00 6002955.00 n70 24 58.28 w151 3 48.12 1.39W 369449.64 6002956.71 n70 24 58.30 w151 3 48.16 5.55W 369445.57 6002961.83 n70 24 58.35 w151 3 48.28 12.47W 369438.80 6002970.34 n70 24 58.43 w151 3 48.48 22.15W 369429.33 6002982.25 n70 24 58.55 w151 3 48.76 34.56W 369417.18 6002997.51 n70 24 58.69 w151 3 49.13 49.68W 369402.39 6003016.11 n70 24 58.87 w151 3 49.57 71.03N 81.46N 189.70N 297.93N 406.17N 58.57W 369393.70 6003027.04 n70 24 58.98 w151 3 49.83 67.18W 369385.28 6003037.63 n70 24 59.08 w151 3 50.08 156.43W 369297.95 6003147.41 n70 25 00.15 w151 3 52.70 245.68W 369210.63 6003257.19 n70 25 01.21 w151 3 55.32 334.93W 369123.30 6003366.98 n70 25 02.28 wlS1 3 57.93 463.89N 491.41N 514.41N 554.11N 622.64N 382.53W 369076.73 6003425.53 n70 25 02.84 wlS1 3 59.33 405.22W 369054.53 6003453.43 n70 25 03.11 wlS1 3 60.00 424.19W 369035.98 6003476.76 n70 25 03.34 w151 4 00.55 456.92W 369003.95 6003517.03 n70 25 03.73 w151 4 01.51 513.44W 368948.65 6003586.54 n70 25 04.41 w151 4 03.17 702.96N 730.88N 744.29N 762.25N 781.24N 579.67W 368883.85 6003668.01 n70 25 05.20 w151 4 05.11 602.69W 368861.33 6003696.33 n70 25 05.47 w151 4 05.78 613.75W 368850.51 6003709.93 n70 25 05.60 w151 4 06.11 628.56W 368836.02 6003728.15 n70 25 05.78 w151 4 06.54 644.22W 368820.69 6003747.41 n70 25 05.97 w151 4 07.00 798.27N 813.32N 826.39N 837.46N 846.52N 658.26W 368806.96 6003764.68 n70 25 06.13 w151 4 07.41 670.68W 368794.81 6003779.95 n70 25 06.28 wl51 4 07.78 681.45W 368784.27 6003793.20 n70 25 06.41 w151 4 08.09 690.58W 368775.34 6003804.43 nT0 25 06.52 w151 4 08.36 698.06W 368768.03 6003813.63 n70 25 06.61 w151 4 08.58 849.40N 853.58N 858.63N 861.66N 862.67N 700.43W 368765.70 6003816.55 n70 25 06.64 w151 4 08.65 703.88W 368762.33 6003820.79 n70 25 06.68 wlS1 4 08.75 708.04W 368758.26 6003825.90 n70 25 06.73 w151 4 08.87 710.54W 368755.81 6003828.98 n70 25 06.76 w151 4 08.95 711.37W 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 862.67N 862.67N 862.67N 862.67N 862.67N 711.37W 368755.00 6003830.00 nT0 25 06.77 w151 4 08.97 711.37W 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 711.37W 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 711.37W 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 711.37W 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 FEB 0 9 2001 Alaska Oil & Gas Cons. Commissio~'l Anchorsge Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from Est. RKB (43.00 Ft above Mean Sea Level). Bottom hole distance is 1118.14 on azimuth 320.49 degrees from wellhead. Total Dogleg for wellpath is 32.59 degrees. Vertical section is from wellhead on azimuth 320.49 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nigliq,Nigliq Exploration,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 7062.27 0.00 320.49 6914.00 7112.27 0.00 320.49 6964.00 7132.25 0.00 320.49 6983.98 7132.27 0.00 320.49 6984.00 7162.27 0.00 320.49 7014.00 7266.25 0.00 320.49 7117.98 7266.27 0.00 320.49 7118.00 7416.27 0.00 320.49 7268.00 7500.00 0.00 320.49 7351.73 7873.27 0.00 320.49 7725.00 8000.00 0.00 320.49 7851.73 8500.00 0.00 320.49 8351.73 8691.27 0.00 320.49 8543.00 RECTANGULAR COORDINATES 862 . 67N 711.37W 862 . 67N 711 . 37W 862 . 67N 711.37W 862.67N 711.37W 862 . 67N 711.37W 862 . 67N 711.37W 862 . 67N 711 . 37W 862 . 67N 711 . 37W 862 . 67N 711 . 37W 862 . 67N 711 . 37W 862 . 67N 711 . 37W 862 . 67N 711.37W 862 . 67N 711 . 37W PROPOSAL LISTING Page 2 Your ref : Nigliq #1 Version ~5 Last revised : 5-Jan-2001 GRID C O 0 R D S GEOGRAPHIC Easting Northing C O O R D I N A T E S 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 368755.00 6003830.00 n70 25 06.77 w151 4 08.97 06.77 w151 4 08.97 06.77 w151 4 08.97 Alaska Oil a Gas Cons. Commissio~ Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from Est. RKB (43.00 Ft above Mean Sea Level). Bottom hole distance is 1118.14 on azimuth 320.49 degrees from wellhead. Total Dogleg for wellpath is 32.59 degrees. Vertical section is from wellhead on azimuth 320.49 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nigliq,Nigliq Exploration,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : Nigliq ~1 Version #5 Last revised : 5-Jan-2001 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 1300 00 1300.00 0.00N 0.00E KOP 1951 2000 3766 3893 4183 4871. 5061 5785 6148 6331 6879 7027 7062 7112 7132 7132 7162 7266 7416 7873 8691 79 1943.04 00 1989.31 65 3685.00 76 3807.00 39 4085.00 01 4745.00 95 4928.27 72 5638.00 27 6000.00 27 6183.00 27 6731.00 27 6879.00 27 6914.00 27 6964.00 25 6983.98 27 6984.00 27 7014.00 25 7117.98 27 7268.00 27 7725.00 27 8543.00 71.03N 81.46N 463.89N 491.41N 554. llN 702.96N 744.29N 849.40N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 862 67N 58.57W EOC 67.18W 9 5/8" Casing Pt 382.53W Seq100 405.22W Seq99 456.92W Seq98 579.67W Seq97 613.75W Begin Angle Drop 700.43W Seq96 711.37W End of Drop 711.37W Seq95 711.37W HRZ 711.37W B/ HRZ 711.37W K1 Marker 711.37W T/ D Shale 711.37W TGT - T/Kup C 711.37W Nigliq Tgt/KupC Rvsd 5-Jan-01 711.37W TGT-B/ Kup LCU 711.37W TGT - T/ Nechelik 711.37W TGT - B/ Nechelik 711.37W J3 711.37W Est. TD Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2000.00 1989.31 81.46N 67.18W 9 5/8" Casing Pt Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nigliq Tgt/KupC Rvsd 368755.000,6003830.000,0.0000 6984.00 862.67N 711.37W 26-0ct-2000 Nigliq TgtT/Nechilik 368755.000,6003830.000,0.0000 7118.00 862.67N 711.37W 26-Oct-2000 Alaska 0~ ~ Gas Cons. CommiSSiOn Anchorage Phillips Alaska, Inc. Nigliq Nigliq slot #1 Exploration North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : Nigliq #1 Version #5 Our ref : prop4233 License : Date printed : 5-Jan-2001 Date created : 26-Oct-2000 Last revised : 5-Jan-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 368418.218,6002816.395,999.00000,N Slot location is n70 24 58.282,w151 3 48.116 Slot Grid coordinates are N 6002955.000, E 369451.000 Slot local coordinates are 156.80 N 1030.26 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Nigliq,Nigliq Exploration,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 320.49 100.00 200.00 0.00 320.49 200.00 300.00 0.00 320.49 300.00 400.00 0.00 320.49 400.00 500.00 0.00 320.49 500.00 600.00 0.00 320.49 600.00 700.00 0.00 320.49 700.00 800.00 0.00 320.49 800.00 900.00 0.00 320.49 900.00 1000.00 0.00 320.49 1000.00 1100.00 0.00 320.49 1100.00 1200.00 0.00 320.49 1200.00 1300.00 0.00 320.49 1300.00 1400.00 2.50 320.49 1399.97 1500.00 5.00 320.49 1499.75 1600.00 7.50 320.49 1599.14 1700.00 10.00 320.49 1697.97 1800.00 12.50 320.49 1796.04 1900.00 15.00 320.49 1893.17 1951.79 16.29 320.49 1943.04 2000.00 16.29 320.49 1989.31 2500.00 16.29 320.49 2469.23 3000.00 16.29 320.49 2949.14 3500.00 16.29 320.49 3429.06 3766.65 16.29 320.49 3685.00 3893.76 16.29 320.49 3807.00 4000.00 16.29 320.49 3908.97 4183.39 16.29 320.49 4085.00 4500.00 16.29 320.49 4388.89 4871.01 16.29 320.49 4745.00 5000.00 16.29 320.49 4868.81 5061.95 16.29 320.49 4928.27 5148.27 15.00 320.49 5011.38 5248.27 13.50 320.49 5108.30 5348.27 12.00 320.49 5205.84 5448.27 10.50 320.49 5303.91 5548.27 9.00 320.49 5402.46 5648.27 7.50 320.49 5501.43 5748.27 6.00 320.49 5600.73 5785.72 5.44 320.49 5638.00 5848.27 4.50 320.49 5700.31 5948.27 3.00 320.49 5800.09 6048.27 1.50 320.49 5900.01 6148.27 0.00 320.49 6000.00 6331.27 0.00 320.49 6183.00 6500.00 0.00 320.49 6351.73 6879.27 0.00 320.49 6731.00 7000.00 0.00 320.49 6851.73 7027.27 0.00 320.49 6879.00 RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : Nigliq #1 Version #5 Last revised : 5-Jan-2001 Dogleg Deg/100ft Vert Sect 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP 2.50 2.18 O.00 N O.O0 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 1.68 N 1.39 W 6.73 N 5.55 W 2.50 8.72 15.13 N 12.47 W 2.50 19.61 26.86 N 22.15 W 2.50 34.82 41.91 N 34.56 W 2.50 54.33 60.25 N 49.68 W 2.50 78.09 2.50 92.06 EOC 0.00 105.59 9 5/8" Casing Pt 0.00 245.88 0.00 386.17 0.00 526.46 71.03 N 58.57 W 81.46 N 67.18 W 189.70 N 156.43 W 297.93 N 245.68 W 406.17 N 334.93 W 463.89 N 382.53 W 0.00 601.27 Seql00 491.41 N 405.22 W 0.00 636.94 Seq99 514.41 N 424.19 W 0.00 666.75 554.11 N 456.92 W 0.00 718.20 Seq98 622.64 N 513.44 W 0.00 807.04 0.00 911.13 Seq97 0.00 947.33 0.00 964.71 Begin Angle Drop 1.50 987.99 1.50 1012.60 702.96 N 579.67 W 730.88 N 602.69 W 744.29 N 613.75 W 762.25 N 628.56 W 781.24 N 644.22 W 798.27 N 658.26 W 1.50 1034.67 813.32 N 670.68 W 1.50 1054.18 826.39 N 681.45 W 1.50 1071.11 837.46 N 690.58 W 1.50 1085.46 846.52 N 698.06 W 1.50 1097.22 849.40 N 700.43 W 1.50 1100.95 Seq96 853.58 N 703.88 W 1.50 1106.37 858.63 N 708.04 W 1.50 1112.91 861.66 N 710.54 W 1.50 1116.83 862.67 N 711.37 W 1.50 1118.14 End of Drop 862.67 N 711.37 W 0.00 1118.14 Seq95 862.67 N 711.37 W 0.00 1118.14 862.67 N 711.37 W 0.00 1118.14 HRZ 862.67 N 711.37 W 0.00 1118.14 862.67 N 711.37 W 0.00 1118.14 B/ HRZ Ail data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from Est. RKB (43.00 Ft above Mean Sea Level). Bottom hole distance is 1118.14 on azimuth 320.49 degrees from wellhead. Total Dogleg for wellpath is 32.59 degrees. Vertical section is from wellhead on azimuth 320.49 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~ FEB 0 9 2001 Alaska Oi! & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Nigliq,Nigliq ExDloration0North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 7062.27 0.00 320.49 6914.00 862.67 N 711.37 W 7112.27 0.00 320.49 6964.00 862.67 N 711.37 W 7132.25 0.00 320.49 6983.98 862.67 N 711.37 W 7132.27 0.00 320.49 6984.00 862.67 N 711.37 W 7162.27 0.00 320.49 7014.00 862.67 N 711.37 W 7266.25 0.00 320.49 7117.98 862.67 N 711.37 W 7266.27 0.00 320.49 7118.00 862.67 N 711.37 W 7416.27 0.00 320.49 7268.00 862.67 N 711.37 W 7500.00 0.00 320.49 7351.73 862.67 N 711,37 W 7873.27 0.00 320.49 7725.00 862.67 N 711,37 W 8000.00 0.00 320.49 7851.73 862.67 N 711.37 W 8500.00 0.00 320.49 8351.73 862.67 N 711.37 W 8691.27 0.00 320.49 8543.00 862.67 N 711.37 W PROPOSAL LISTING Page 2 Your ref : Nigliq #1 Version #5 Last revised : 5-Jan-2001 Dogleg Deg/100~t 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vert Sect 1118.14 K1 Marker 1118.14 T/ D Shale 1118.14 TGT - T/Kup C 1118.14 Nigliq Tgt/KupC Rvsd 5-Jan-01 1118.14 TGT-B/ Kup LCU 1118,14 TGT - T/ Nechelik 1118.14 1118.14 TGT - B/ Nechelik 1118.14 1118.14 J3 1118.14 1118.14 1118.14 Est. TD FEE 0 9 2001 Alaska Oil & Gss Co~s. Commissio~ Ar~chorage. Ail data is in feet unless otherwise stated. Coordinates from slot ~1 and TVD from Est. RKB (43,00 Ft above Mean Sea Level). Bottom hole distance is 1118.14 on azimuth 320,49 degrees from wellhead. Total Dogleg for wellpath is 32.59 degrees, Vertical section is from wellhead on azimuth 320.49 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nigliq,Nigliq Exploration,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : Nigliq #1 Version #5 Last revised : 5-Jan-2001 Comments in wellpath .................... .................... MD TVD Rectangular Coords. Comment 1300 00 1300 00 0.00 N 0.00 E KOP 1951 79 1943 04 2000 00 1989 31 3766 65 3685 00 3893 76 3807 00 4183 39 4085 00 4871 01 4745 00 5061 95 4928 27 5785 72 5638 00 6148 27 6000 00 6331 27 6183 00 6879 27 6731 00 7027 27 6879 00 7062 27 6914 00 7112 27 6964 00 7132 25 6983 98 7132 27 6984 00 7162 27 7014.00 7266 25 7117.98 7416.27 7268.00 7873.27 7725.00 8691.27 8543.00 71.03 N 58 81.46 N 67 463.89 N 382 491.41 N 405 554.11 N 456 702.96 N 579 744.29 N 613 849.40 N 700 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 862.67 N 711 .57 W EOC .18 W 9 5/8" Casing Pt .53 W Seql00 .22 W Seq99 .92 W Seq98 .67 W Seq97 .75 W Begin Angle Drop .43 W Seq96 .37 W End of Drop .37 W Seq95 .37 W HRZ 37 W B/ HRZ 37 W K1 Marker 37 W T/ D Shale 37 W TGT - T/Kup C 37 W Nigliq Tgt/KupC Rvsd 5-Jan-01 37 W TGT-B/ Kup LCU 37 W TGT - T/ Nechelik 37 W TGT - B/ Nechelik 37 W J3 37 W Est. TD Casing positions in string 'A' .............................. Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2000.00 1989.31 81.46N 67.18W 9 5/8" Casing Pt Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nigliq Tgt/KupC Rvsd 368755.000,6003830.000,0.0000 6984.00 862.67N 711.37W 26-Oct-2000 Nigliq TgtT/Nechilik 368755.000,6003830.000,0.0000 7118.00 862.67N 711.37W 26-Oct-2000 0 9 001 ,Alaska Oil & Gas Col'~s. Commissio~'~ Anchor'age U.I ' -1000 -2000 -3000 -4000 .5000 -6000 '7000 -8000 ';9000 --10000 DRILLING TIME AND MUD ·WEIGHT CURVE TEMPTATION #1 / lA Depth· ~,~,---,--~ Mud Weight i 16' csg pre-set @ 110' J ............ I _ _ _ L 1 J .L t .... I___ _ ~ .... ~ .... L_--.Jt I ........ L---J~ [ ~'~ ~L ................... ~k I- I I I I I . I I '. '. - -----I p---- -- -'1 ..... ' I'- ..... I- -f -I .... -----f .... I- : p -- -- -- -I- ........ I.- -- -- -- ..l- -- -- -- --I t-- ...... ~1 ---- I r-- 1 ' I I I I I I _~ _, .... , .... L___, ........ !---- .'-----.' .... : ....... ~ ...... ~---~ ....... , , , , ' '. --~" -- I I I I I I I -- · -- -I I- _ _ ..I .... I .... I- ..... I-- I- -- -- -- -~ ..... X .4. r--''~''~ .... '~L _ J. ~ ....... L _-- -- .I. -- ---- .-I .... I-- ...... "J-- -~--'----~ ....... '---~--' -- I ! I I I I I -'¥ 'lDdl112-1/4'-' 'I- ~ , . * , ' ~ ' ' ~ ...... ~ / / ' i i i i . i i . i i i I XI i I I J / - I i , _ _ _ i..... ........ - ___~L I - .L____I ...... ._L'___.l_-: J .... I ....... J .... ' ........ --' ....... -z_----~ .... I- I ---~ .... ,- - - ' ' ! '. _~ ~_ _ _ _. - -~ - - - B~gin ddlling Temp. #lA I- - - -, - - -'-' .... '- ........ ! .... ,~ - - - '~ -I .... ------f~,----I .... I------+ ........ I-----~'--. ..... I -- ~ * i i J I ~ I i ......... I .... I . I ___._f ............ , _ _~'_ --' ............... I ------~ ........ i" ........ I .... I I ---l-~--%, , I I ~--- . .................................... .- .......... Set 9-5/8 at 1817 - - T ~ , ' ' ~ ' ..... - - , ___., ___~._ _ _~.. __'_ .............. . _ _ _ ~ ............ I -~.,.-! .... .~ ............. , ...... ' I 'NP' ~ I I I I I ] ' '~ ' i I [ i , , , '~ , , , , ' ' '~ ' '~ ~ ~ ~ ~ __L_-- J. .... i .... .... _, .... , .... C _ _~- -~ ............ ~---~ .... ; ....... i- ~ - -',-~ i , " ' ...... _ _: .... I I I '~[ I . - ~ -- ---I ........ I-------'t .... I .... I- ........ I .... I-------'f-- ---~-, .... , .... ~----~t ..... '---~---- +----~ .... ~- ...... "- - - 7'.- -¥ - ," , , , t , , , ' ' _ I I I I ' [ I I I I N, ' .......................... · I [\ ........... - ........ .---x- T---~ ........ F---1 .... [--- F .... T .... ~--'-C---T_~_E ~ ...... J .... T- I [ [; X .................... \ _ ..... _1 ....... L___-I ........ L___ .-1 .... I .... L .... I L- ,.t I , , .;-i. , ,. , , : . . .... , , , : . .... ii .... .... !-i i t! i::::N! ...... !___!iL/l:\:-:: .... .... .... !---!-.---i .... .... .... L ....... .... i .... .... i---i---.-i .... , , ,, ,. ~ ,, : _, ,, ', .'.~../~..,~,,~ .... .,,.,.,,.~~.~..~..,~ .~.~.,~ ...... ,~ .... ,-,T~,~ i%~.-,-~--"~.' - ' /; ---- ;-----;---% ' ' ' ' ' ' ' ' ....... .... ~' .... ,' .... 'r---~' ....,,, ,--,,-, ,~ :-, ......... ~'7~~i_-ii_-ii)~___:-_--~' .... : .... L___; .... ', .... L___~' .... ', .... .... -* .... , .... '- ...... -~F-~,'~-'--~'-+~-'~-~--~- ....... .-'!.-1-'. .... , -~ , \ , , , / I I I , . ' ' ~-__'_~%_ aT '_--J--~---- ........ ~'--' ..... ~---~ .... -¥--r---~ .... ~ .... r---~ .... .... 7 .... [ .... I'----T--~---'~"I-~]r--T=- I '~ I J ' ~' ' ' - ~' L J ! L ~ I ___L___.,t .... ! .... .... .~ .... , .... .___.-_/_ .... %.~__.~_--~.----¥-. .... t_Cf.-~-,,---.,~---i ..... -¥-,---, : , , ~ , , , , I I I I ~ ~ ' ' ~ ' -- ' ~ ; t'~-'-'-'-'-'-'-'-'~, i i i i i i i ...... .'-- I I I I I .... I .... ~___.~ .... II .... , /,, , .... ,- ........ .... , .... .... ~--~,%-- , ---, ',tT .... ,\ , , '. I ' ! ' ~' ~ .; ............ : ......... ~---~ ......... .... .___, _,_ _%_.~___ +,- ..... ~,.__. ___ ~ .... ,*' ...... ~__ ~___ _,, ........ , - ....... -,-_.. _~_- , , , , , , , -,--'-TI_/_ --i----I_%_ I----TI It- ........ ~ - ~' ~ -I1.- - - -!1 I '-I--I ........ -I-- ..... I--!~1 .... ................................ IlI I -~L~ _Il _11 .... Li- -- - - '~_ _ - J .... .... II .... .... L~----]-- - - I _ .... _ ~ _11 .... .... .... -t--~---%~---+ ...... ~-x-~---~- .... .~ ..... 1--i ..... , .... ,~---I ........ ;-~-- ,--- , ~ , , , ' ,, , ,-...~ , ,, , , , , ..... , \; , ; I ; ;. ; ' I I I I I ............................ I ___;. , _, .... ----' ---1-' ----' .... ! ...... 1---! .... ! .... ~---- ~ ........ k-- N,i---,,- , ~ .... ........... I I I I .... ~! .... ,' , ' '. V ' '. - I I '. . .~ ..... L---~ .... , ........ 4 .... , .................. .... ,~ .... , .... ~___+ ...... ~:___~k___~ .... ~ ..... /__- ~. .... ..~ .......... i ,% , , / , , - ~, , , , ,_ ~__~____' .... ' ...... /-_ ~-~ .... ',---- ~---- ~ ........ F----i\---, .... ~---~ .... , .... ~---~ .... , .... .... r-- .................. '-i .... I-- - ' .... T , , T .... ,- - - - T\ ! ! i : : . . .... L _ _ J J -~- ....... ,- - - - -~ .... ' .... ' - - - ' .... ' .... .... ~ ......... '---'~ ........ '---~'~ ............. t----; ..... , .... T---, ........ ;--- ' \ ' · -' ........ ~' ' ' ~ - I ' II ' ·[ I I i ~ , , Drill 8-1/2 hole toTD7750 , , . I . ', : , , ; , \ IDnll8-1/2' noieto ' ' , I ~ ,\--, ,1--,-..~-:--.[, , , ,- , , ,, , i , , ' ' , , I , , ....... L _ _ - -' - - -~-'- _1 I _' .... ' .... .... ~'- I ' I I I I .... I- .... ..... - ...... I.-----4 ....... I- ........ I .... I----4 .... I .... ___ 4- .... , .... ~----. ........ ~----.---~-~ ,--IPlugoacK,o 1550 [ ,'----I----~1( , t , , , , I , ] . , ~ ' ' i [___~_l .... [ ..... [__L~_- ........ ~----I' ........ ~----1 .... ~--r---~ .... [ .... r---7 .... , .... ---i'-r .... I .... F---T ........ I .... T -~lk I.~ ,. - , ' _ L __ _ _1 _ ~ _,_ _N%.. L ' L' .I. ___l .... __ ...L .... I .... L___/ ........ L__- J. - ----~'1 .... '~"' - - ~'1 .... JI .... II'---/---J ........ - - - - ;" - - - "; - - - '-;- -%- I~ ............. ' ..... .... ' I I I I I I I ~ I I '%3dk I I I I I I I--U Ill I - I I I ~-;,J ................. __~; .... , .... L___; ........ C~__; .... J ~ ~1 ...... = ........ ~---~ .... ~_-'-',----;---~,~'~ , ' ' ' - - , , [ ] i [ [ t--..-------J , , ' : ~ _ ~ _ _.~ ~ _ _ _~ ..... , .... ,- - - ...-~---,- -, .... .... 4.--------I .... 1-------4- ......... ------~-------- ...... I I ~ I I /~"1~ '~ I I Ir"(~./'~ I ' - , , , [ [ f ' ' ~ ~ ............ ,- -~.- .-, - ~ -,- - .-.- ~ ....... ~ - - - K - - I l- -[ .... --:'-'T .... , .... K---T ........ C---T---q--:--, ......... Ei .... '. .... '. '. ;..-~_; j ~" ' ~ ;:~ _;__">,.L~___L.~_-' ....... -- -----~ .... ~---' ........ '---~---~ .... ' ......... ~----; .... ~---i ........ ;>-~-,-'~---~---~, ---'- -;--"~ I I I I I I ' I ....... J-~_ -- -- -- -- --'-- "--'~ ~'e ................. I .... .... _[ .... I .... I___.! .............................. -~ ........ T---'~- ~ C') ~ i ~ ~ ,~ J I '1 I .I I i i ' ' - -4 _ ~'~- .----r~--O -- -4 .... I----~&¢ .... I .... .... -+----~ .... ~____.._. ....... ~____~___.~___ ~_ ...... -4 -'---T~--- , - ~-~ ~ c4D t .... ~ ' I I I I I I (D - -- ....... ~ ~ ........... "1' .... I , I I .... . .......... ' ------ I (-- ~- -~----~ .... , .... ~---:T--'~ ..... ~'---~'---'~-- ' ~. : [ ] ~_o.0 ] ~ , ~,. .... , .... ~ ~ _, _ __,.t ........ L___I ........ L_-.~J.---J---- I_ ...... ~ ....... ~ - ~---,'~::-.l~ ] I I I I I I Spud 3/25/96 , 10.7 10.6 10.5 10.4 10.3 10.2 10.1 .9.9 9.8 DAYS 0 5 10 15 ~' "~--~ 20 25 ~ Rig Release 4/17/96 9.7 DRILLING TIME AND MUDWEIGHT CURVE NECHELIK #1 Depth Mud Weight 1000 2OOO 3000 4000 5000 6OO0 7O00 8OO0 9000 : 10000 11000 ! ~ i i i i I i i i i i i i i l 120'" csg pre-set @ 90 I .... , , , , .... i I ---- - J 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 __L___/ ........................... 0-~ I I '-~, ~', .~, , , , , , · , , , , , ! ,. . ~--~. o, i,l~ , , ' ' ' I I ! I I I ~ ] ' -- -% ' \, , , i; t, , ' , , ~'.~' ..... ~-~ , ' .,~ 'l---: ~I[ I I i I t i i I I ' ! O~ 'I . 'C:~ l INk i , : ~lt -- J i-- -~-- 4- -- -- -- -4 - [------ ---I---------1 .... F-------I' .... l-- ----_,['--- --,--~.~ ------ . '~ t~---- -- . · -- -- -[' --Nk-- -- --] .... I- ....... [-- -- -- -~b -- -- -- -I .... [ ............. ; -- [ I ..~[ J ~! ~. [ I i~ I I ~I ' I I [ [ ~ [ I ~-/~] I ~ti ~ I I tI . ] I I I I I I I , I r~l I ~'~- .'/~ I l ·I II I I I I ~ I ] I ~I I i i i .~. :il [ / · ~l ~ _lI · I ]- ._[ ..... l .... '1 ..... I .... ,.~-~,~p~9~T~/~..'.~ ..... ~ .~__~? il il [ II IS et 13-~8n cs.~ [ X [[ ~ i i i i i i i i i i i [ -i i i i . [ i i i i i I at2700 . I]~i ! · !~ t'. , / .j , ll __ __ __ ._J .... I________/ .... I .... L___/ .... I__l _L---J ........ iL---I' __ _1 , I' ''~,] ;' - - ~' X !I I t I I 1, II 'I ' I, I, II II li : I I I ' ' ][I . I I ~.~It I I I [ ] i I I I : [ I ! , , , l I I I :~ '.1 I I I I I i -- IV'Ill. I I I I I I : I I I I I I i I I ' I , [ I I I I 11 I . I I ~ I I _ I 'l I I I :[ I I I I l I I ~I I'~k I ' I I ' I I I I I I I I ~ I I I .... I I I , I ti ~ I I I _ .................... _ -- -- --, .... ~ -- -- -- T .... 1-- I --~- r -- -- --N .... I .... -r ........ r--'1 ~-'1 ....... r---n .... I .... --T-l-l]-- I / / 1I ,~ ~: , , · I I I I ' I I I I I I !~l I I I I I I: ll~l . ii ' I I I I : I I I I I I ~ i , : !Ddll 12-1/4 hole l ', I I I I : I I I il I I ' I I : [ I I [ [ ! . I X il' I I ' i i · i i i ' I [ i i ~ i i i i ] i · , i i ~1 i I I I I I I , .... ' ~ ...... ~ ] [ ~ i ~ .... I----~--F------~ ............... I '~ I I lilt 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 I I I I I I ":-1 ' '\ 'I'I i I , , , l I .... [ [ Corln i · i i i i .... il i Il I I! N~i I C°ring · ........... ......... I [ I I I ~ I J I I / ~ I ____/ .... I .... L---J ......... L_ l_/ iL- - I ~1 ___ J..~ = _ _1 .... L _ _~½ ..l ......... .~ - - - ~ -~ ...... 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 % I I I I I' I I t I I I I I I : I I { , , i , ~ ~l~ , 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 T ~ I ' ' I : I I I I I I I~ '~Jl~_l I I I I I . I :1 I : I I I I I I ...... T ........ T .... -i1--.-[ .... T .... I .... C ---T .... i .... ~- -- -- -- q .... I .... r -- -- -- q .... ..... ~-[--, .... r-i--~ .... ,--- r N , ------, ~ .......... ; I I I I I I I I I '~. I I I I I ! I ~ I I I ! I I ! I '~ ' 'l I I Il I I I ' I Nk J ......... ~ ...... J I I I J I I I I I : : ' 'q~' I : I ' ' ' ' J I I I i I I I I I I I. ~ J ~ [ __ L __ i __ ~ __ __ j~ .... ~ -- J -- ~ .... i .... r __ I __~ .... I -- ~ -- I ~ i I -- ~ .... .... ~ -- -- .~ --I' -- -- -- ~ -- -- -- ~ .... I .... p -- -- -- ~ .... 11 .... ~1 --:-- -- ~ -- -- -- ~ -- -- -- T ',l- T T ~ ~- - - - ~ i i i i i i i i - --J' I I I I I ~ ~ I- . I "J~l~_ ~. I I I I I I I I I I I I I I I ' n~ , I ' : i JL°gglng I T ~ ' ' ...... ~ I I I I I i I 'J - I T~l--~ J I l J ' 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 I l I I I I l ll - t I I I I I -- I ~ .I. ____; .... L .-~--~. L----J .... ___/ ........ L------J .... I .... L_--~ .... I I .... : I [ J J J J .... I .... /___J I I .... .L___..L------ ~ I ....................... - I' I ---~ ........ I~' '~ I I I--' I ] I I I I I I I I I I I I IIur[ii, ~,ore o- I1"' J I "~l.~L~. I. [ : ' ' ' ' ' , I , , , : - : ' : ' [ hole to TD of 10,018 J II T ~ 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 I I I _ I I i ................ I I I I I I ......................... ~ ...................... I .... ~----~- I I .... '[ .... J .... j--- ----'i ..... . ' ---- [ -- -- -- -i .... [ [ I I I I I [ I I I I [ I I I : I '1 I I I I I I I I I I I I I I I I ' I I I I ' I , [ , I ] I : ,- ' I I I ' ' , ' ' I ' ' , ' : Spud 1/17/82 0 5 10 15 .. 20 25 30 35 40 45 'DAYS 5O 10.7 .10.6 · .10.5 10.4 10.3 10.1 10 9.9 9.8 9.7 9.6 Rig Release 3/7/94 .. -2o0o -4000 J-8000 -1-0000 ;12000 DRILLING TIME AND MUD WEIGHT-CURVE ~ Depth .. FIORD #1 ~.. Mud Weight 20' csg pre-set @ 108' ' ' -- · I ' 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 I I I I [. -__-~_-J -.L--L- I .I I / I J .[ L I I / I _J__A__L__I I__J__l-_L ..... I__J__J.__L .... I . J_ ~ , _ I ~- i / 'l I . ; I--- i' - ,~--,-'l T i- ; i i- I I I ?--i i i -~ ' I I i I i I q,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 =.~-v i i i --~-I---- ;"i--h-,,..,, .-- ..A.; . [---I-----4--'--'1- ..... I-----!-----I'----'~ ..... '----'----'----''--'----'----'----'----'----'----'----'----'--'' ....... -I -- ~. ~F -- --1- -- -- ~-- -- --I-- -- -I -- .~ . IIJrlll 'l/-'llZ nole/. . . . . I ~ ~ . . i i ! . ~ i . . I . ~'" I ../~1 . ' i . . . · I I - ' / I i -= = I = i , , i , ! a i , , : - , i , ~ I ,~.~'.:! i I i , --r--[--q--r ..... ~---~-''~--r ..... .--r.---f--r ..... .--.--.--,--,--.--.--.--,--,--.--.--.--.-- -'-r't.--3~--r - -F--I--3- _ _1.~ _ J_ - J _ _ / _' .... I_ _ J _ _ / ~. -- L ..... I_ _ J_ _ / _ _ / ..... I_ _ J-- _ J'-- - I - -- ~- - --'-- - J - - / -- - L -- -- ~ -- -'-- -- J - -- J ~'~- - - F-T~"-- -- J ~ - ~'; - L - - ~- - -'- - J - I I - i' I ' # I I I I ' I I . I I I I I I . ~. ]Set 13-3/8 csg@ 2388 [, ~_, . . . ~:, ,__,_ ..... .__j__z__L__ " " '~' ~ ~ ~ ' ~H."~ .' =~-'~_~-,~ .' .' .' - - - 5 '~l~i--~ T~ . . . ". h-.Iq--3-- T ...... i-] -~-- T I i i ~ I - -- ~l- - 3 - - T ~ ~_~ -.- ~..~- - 'i ~;~-?-~- - F ..... I--q- ' , ' [ m X I ' ! ! ! ' m i m /-m m m m ! m I I.' m m m m i. i e i%/- ; C~5 , ~.m~ i m ' I ___l__-I_ ~ J_~i~ .... '_1-- J-- J--:t.'-- .__,_'j_'m__L__.__,_' _m__~__ ~ ..... I___l__l__m-_ .... I---I--~-- ~-:- ~-~- -I-~- ~L ~ -m ..... l----J- ' , i , ~l . , i , i ,~ m [ ' 'l , , , i , , , , i , i~ ~ , L.-t~. , , i , , v ti , ,' , ,.- · ,~' , , ., : [ ~; , , I [ , , ' ' ' '~,' i ' ' ~L~ ' ! -' ..... -'l----1.----l~r ..... I-----I----l----T--'-----,'"---.----.----.----'----,--' 1--'T--r ..... i----t-'-T--r ..... i--"l--l'--r(~ .... i---1-~-'~ -r ..... i--i- 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 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 _1___1_ ---I---~--~--,~ ..... I---[--~--T~T~i-I:--m-'-~--? ..... I--ri , , , I I ' I ---,--~--7--F ..... i--'~-T--F .... , 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 I - '~! I I I I t I I ' I I I I . I I I I I I I I I I I .I I I I. , -I r I : ~r , i i i !p i . I- m I I I , , I ,' I . ..... -~---~--r fl[F - --,---I-- [--r .... 'l'-'3--'T--r ..... ,--,,--'----,--,--'--'--'--'---'--'-''--' ..... I---I--T--I- ..... I---I- I m I m \ , m' m il m i m I- m I iI I ~li ~k I , m , m m m m m , i m i i · . i I J J J_ ' I J .[ -'- L ..... i ..... .1._ L-- _I__J__/__L .... m__J__J.__L ..... I__.J__ J.__L ..... I__.J_ -JDrml112-1/4' hole~- \- - -,--- ,--; , -- , -- :--,-- ,-- , .., , j.~,_ ,L__~ , , , , , , , , . ,.__, m -. _ m 4~ ~i, A, Jl, , ~ , , , - , , ~---r~ , - ~~~~'"~"~~" "~"~' ---I-'-~--'1---4'-- F ~-I-J~'1-1'1-'-4'-- :--I--'"l--'t--~--~l---I---I--'f--t' ..... I----I--'T--I- ...... I---I--'~--P ..... I---I-.-4'--P ..... I---1- "! ]' a -I [ ~tI ~ ~ I ! ']' : .m ! I I '' ! ! r I [ 'l , , . m I m ! I ! I I m I ! I ! m J '~'J[ ~ I [ m ! m ', ! ! e a' I m I I , I m m m , I I , I I ..... -~--i--T-- J 'JiJ--R[Jl--T-- T--m--q--i--T ..... m--q--T--T ..... ,'-q-'-T--r ..... ,--'i--.T--r ..... i--'i-=T--r' ....... 'i-. I I -! I I ~ m~ m , m I I I I I m' I 'm I I- I I l- I' I I I I I I I I I I I I I I I .11- Ii .II : , ~ : il ii Il Ii . ,I Il tI II I, II I ' ' ' · I I I I - I I I I I '1 I I I I J I I I I I I I I I I. I I I I I I I I I I I I ..... ~--~--~-- - ,-,--.-__--.--,--,--.--.--. ..... m--~--~--r-'-~-m--~--~-~r ..... m--~--T--P ..... I-----I-- T----r ..... · I J I I I I .I . ' . I I' I I I I I I I I I I I I I I I .- . . . ; ~; . . . -/Cores #2-4 I . - i . . . . . ' ' ' ' ' ' - ' ' ' ' ' " ' " ---m--~--~--T-- i-'~-m--1--T-I ,,--,-,,---,-'-,--,--,' .... ,--~-"~--F .... ,--3--T--F ..... ,--R-TT:-F ..... ,--5- I I m ' m l{ i ~ I , .- m m I m J ! m i m I m I , I m m I m , m i m i ..... -.I-----I----4----- J-- --I---- ~4- ..... I----.-4---- n ----J-----l---'- , , , , - -',~..~, , [Ream key seat, log, set 9-5/8 @ 7981 [ i , ...... , ", - - *, ........................ , , , , ,' ' , , ' I ' m I I ,]l~.~r~ ~1 I m ' ~ ~' I I ' - - : I m m i i m ' I I I , , I m '----I------I----1--'--T .... ijvv, v .H I--'T .... ~'--I--'I'---T ..... i---I---r--r ..... i---I--3'--F ..... i---I--.T--F --I-----I--T--r ..... I---I- i ~ .i . m .~"IT~ i ~ m m i I , m i m m m. m I m. m m , I I . m I m I I I I I I I I J J ~J~ I ~. I ,~ I ~. I I I I I I ' I I I I' I I I I I I J 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 I J [ I I I I I ' I ' I . ' I ~,1 I I '1 I I I I I I I I . I I I I I --- --I-- -- ~- -- '4' -- -- i- T- ___p__-d__.i.----i- ..... 1------I----+----I- --I-- -- --4 -- -- -I- -- -- I- - - ~l: - ~ - - ~ - ~ ~ .....r m- - ~ - - ~ - - ~- - - - ' -i- - ~ - ~ ~ - - ~ - -I 250J i , ' , - , ~ , i ., , . i I ' "~ ' IDril18-1/2"holeTOtd@10, . , , i , , , , , i I I ' m I\ I J ' I ~ m ~ ~ I I I I i I I I I ~ ' I I I I I I -- --I-- -- -~ -- -,-.--,--,--,.-,---.--,--,--, ..... i---~-- i-- r ..... i- - 'i-~[3'_ - - r .... ',--'--'--'--,'-'--"--'--'- -i---I--T--r- I. i i m , i i' i , m i , m m '~.~m I I m I | m , , I . I' ,. I I I I' .; _1__--I--._ J'~ -- L--I __I__J__J__L--' .... I__J__J---L; .... I__J_ ---J--'--~- ' ---''-'----''--'---'----'---'----'--' ..... I__J__.[_--L-- __1__ J_ I I I I / I I I . I I I I I I I I T~ - I I I I J I I I I I I I I I I Iamls~ ~' I I I I I - ' I I I I I I '1 I ~ I I' I I I I I I I I I I · II .i. il ~k /I I I I I ' I I I I ' I ' I I ' I ' ~ I I J rlu~ I./aum. J 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 -I I I i. ~ I I I I I I I I -I I I I I , .., , , , , , , , ,. ,- ., ,. , , ILog I'"~. ' ' :; ' ' ~ ~-' ' ---I _-I-. .... -_l----I .... 4- ..... I----.-I----J----L ..... I----- 4-- -- ..t ---- ~---J ,__.__.__.__.._,__.__.__. .... ~__.-1__.~.__~.__ __~_! _ _l 'i 'l ] , , m i I I - - m , t m i i I i . i , ~ , i [r3c~T'-m m , , , , , , , ~ ~- ', ~ .;' ~_ ', -~ ~'__~_ ',__~' ....... ,_ I '----I--~--I-- ---[---- ~ -- --I-- --"-I .... '-- ; ................. I I I '1 I I I ! I I -, [ I I I I I I I I I I I I I I r ___I__.~__.J__£~'~ I I f- - I . i J__l_ ..... i_ I I m I__J__l_- L; ..... i__J__i__L-- I i m _! I --'m,--i--al-- - i i m m m i .'T F i i m m .i [ [ m i i m I --i--., ! I I II . I .1' I I I I I I I I II I I II I I I - I I I I I ~- -- --I-- -- .;4-- -- -I -- -- 1- .... ~1-- -- '-I ' -.I -- -- 4--- ' _ _ _1_ _ .-I_ ;.. ~t .-- -- 4- ~ .... I-- -- -I---- -I- -- -- 1- ..... I-----I----4.----1- ..... I-----I----4-----I- ..... I-----4----4-----1- ..... I-- ---I - I ' '1 I II I I I I I I I I I I I I I I I I '1 I . I I II I I I I I I : I I I I '1 I I I I I I I '1 I I- I I I I I ' I I '1 I I '1' I . · . . .30 40 '50 60 11.2 10.8' 10.4 9.6 9.2 8.8 7~g Release 4/1 8/92 ' + Depth I DRILLING TIME AND MUD WEIGHT CURVE ......... ,*Mud Weight rlunu .~ 16" csg pre-set @ 110' , ............. , , , , , , , , I I I I I I I I I I , , I-- - ' J' '7 ' i ....... ~' .... r ........ ] ..... I .... ~ .... J- .... I ........ r .... i .... ~ .... ~- .... i i . i i i i i i i i i i _ _ _1 .......... J._ .... i .... L___~ .... 2__ ...................... -: .... r ........ '; .... ;-------'] .... ~ ..... [ .... ~ .... F'-- , I I I I i i i , , i - I I .I ! I I I I -- .4 ......... I .... .-I .... I- .... I ......... I-- .... I .... .4 .... I- .... .-~---,-IDrill 12-1/4' I' -- -' ............. ' .... '~ .... P ........ '~ .... ~ .... ,--- , , , , ' ' ~ 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 I I ~ I I I - .............. ~ ......... ~ .... -I .... F .... I ......... F .... I .... I .... F .... --¥ ..... I .... r .......... --r----I .... ~ .... r .... i--- ~ i , - ~m~.~ . ]]_ I '1 I I I - I .......... ~I~ _ _ _ ;~ ........ I I I · -- .............................................. [~ I I :~ I ........................... r ........ ~ .... r - i I I I I · . I I I 4- I I · · I I I I ........ -~ .............. ..... _~ .... L .... '~ ......... L .... 'J Kick @ 2509 TVD Weight up to !1.4 PPgl-. .... = ......... , .... , I I I I · I / '~ ' ' [ -- ' L I J ....... I .... J .... L -- .-~-~-' _1 ......... L .... I .... J .... L .... ------~ _ _ ~..,[ .... I ' L .... I .... -t .... [- ........ ~ .............. ~ I I I I I I I I I I I I i i~ ISet9-5/8 at 1817 I ................. ~ .... .~ ....... ~.~ ..... ' . , ~ ~ ,I ,, ~.~~.~ .... ~.r , , , , ~ , , ~ %. ' ' [ ' i ' ' ~ ' ' '. -t ---~' - - -, .... -, .... ,- .... i ......... ~- .... , .... -' .... '- .... ..... ,- - _ ~ .... .~ .... .& .... :~ .... ~- - _ _ -~ .... .~ .... ~- - -~._- .... -~ .... ~- .... , .... · I I I ~ t~ I ..~*-[',-~.~-':~z,,_~ I I I I I I I I I · · - ' ' ~; .... -Z"2Z ~-' _ ....................... ' ..... r .... , .... I .... r .... ......... .... .... , ..... .... .... : , , , I , ~,_ I '- I I J ~'~ I I .,~-" ' -- ............ I ' I I'~ ............. ; .... ..-,-,-,-,-,-,-,-,~', ~ ........................................ i" .... I-- ......... i T .... i- .... [ ......... -. %. F - - - .l: ]- - - [ .... ~~.~.. ..... i I [ [ ii [[ , , ............ [ , , , , _.LrL ' ___L ........ -' .... L ................................................ I '---- I I I I I ! I · I I . x I I I I . , , i , I ' ' - I J [ ~ ~[ - , I- I I- I --4 .... i- .... · 4 I- ---- .......... I---- - [ .... .4 --"- - - I- ........ 4 .... I- ........ 4 ......... , .... .4 ............ '~ .... . .... ,------ , ................ \-_l- , , , , , , . I IL'.. I I , ' , , , .... ~ .... ., .... ~_ ........ _; .... ~_ ........ ~, ......... , .... ., .... ~_ .... , ..... ____~ .... , .... ~ .... ~ .... ..... i .... ..t .... ,- ~---I---T --- ['- I'~h, - [ i i i i i i i i i i I I I I I :'~I[ , ' " _ .......... --------. .... r .... I .... ~ .... f .... I .... q----r .... I- I ...... fi----' --IN[-----'I' .... r ........ 1' .... I-----'--I .... / I -- ~ -- ' ..... I .... ~ ............ __ ' ; I I ~ I I ; I I I I I I I I ~ I I I [ ~ ~ ................... , I ___.1 ....................... ~ ........ -- ....... ..~ .... r ........ ]--' ........... "~ ~-3-- -- -- i- ........ ] .... [ I I I ~' ...... I I I I ~ I ' ,f..,3 ~-~--~ ' [ , , \ ~ I [ ' ' ' '~- ' ' ~ -, , , , , ~ , \ , , ' ' ' ! I~ ', ',:':'-~- L ___: .... · .... · .... I I I I X I I I I ~ ' ' . t - - - ~- i 4 ....... I .... .4 -q"*.- - - r.'m,- - -I-: ~,-' ...... ~- .... I .... .4 .... ~- .... -- .... I .... 4 ~- -- -- -- t- .... I ......... I-- -- -~ ~--i-- -- -- M--I-- -- -- 4 .... ~- ....................... .. · : , , , . , , -- , , , , · ~ ~ ,~ ~ , , , , I I' I ~ I I I I ~ tC~ I i;-~ .~ I I I _ _ _ .... '-_ 2 .... I~ ................ [- -i .... ~- ~ - r ........ 3 .... r .... i .... I .... , ..... I-- -- -- ~ .~.~- -- -- I-' .... ]~ ~J--~ ...... I- .... I .... I .... F .... : ', ; , ; ;\ , - , , , ~P,,~ ~c~ ,~-~-~ ' ' ' ' , ' I I ~ I I I I ~ I '/' I I ~ ~,-' I I I ' ' ' ! - - %' I I ~ ~ ~ -.- I I I I .... I I I I I _l ..... , . -- ....................... '-~ ..................... ................................ I .... I ' · ~ L] I ;'--'t I I I I , , , , -', .... ~---~i~ IDnl18-1/2 hole to TD 8400 I ...... ~, , , ~ , I ' ~_~ ............. L -- L - _1 .... .t .... L~- --I I' ' ......... I .... · ~_ _ _ F:~ _ _ _l.~ _~_.~ ...... r ........ i .... , .... ..... :__~_I .... t .... : ......... L_,~__:___~'____L~ ..... .-~ .... . ........ i ............. i~---F-- ,--~ i : . ~ ,~ ' ' I ~ i [~ I [ ' I I I ~ I I --~' "~ -:' -I- ~ , -t -~- .... -t .... h .... , .... -t ......... , .... -I. ~-- - r- .... ! ......... ['- .... , .... -~ .... t- .... ........ -t ........ I ......... ~ .......... - .... -~ · -, ,, , , , ...... , , ' .... :t' ', ,, , t ": : ': \. ................... ' ' ' , ,' ' ' ' ,' ,' ' ,' ' ~l~ '"r --ti-- -- -- --~ ' '"r --t .... T .... .... 'ri I'-. -- ...... [ ' .... ir ~---i'---- 7 J i .... ~- .... i '~ %---~ i .... iF ........ [ ] I ......... ii .... 'i ..... ,~---~ .... r t---, ......... r.l ....... '; x--- r-------x-'~ .... r .... , .... -~ ......... , .... ] .... r .... , ..... [ .... r .... , .... ] .... r-- -i ..... I .... I .... L .......... L J~-- -- -- --I .... .,1. .... L .... I___~..~ .... L ........ ' ......... I .... J .... L .... I .......... L .... I .... J .... L .... I I~ I ~ I ! [ ~ I I ] I [ i I I [ I . - :~ - i ___~ .... ......... ~ .... ~ ............ ,~_ ....... ~ .... ~ ........ a'~.=_ ~ ........................ ~ .... ~ .... , ..... ~ .... ~ .... ', .... ~- , , , , ~l , ',1 , , , , ~ , ' ' ' ' ' ' ' , % t ,1 , , ,-% , ' ' ' ~ ' ' ' ' ' I ] :. ] ~t , I [ , ] I I~. i [ , ' [ ' ' " ' ' ' ..... I- -- T -- '1' .... I- ---"~'-- --I .............I-~ I .... -[ .... r ........ .... ~'1' .... ....r ~-r - - -I .... '1' -I Core from 7772 to 7813 MD I - - -I ..... : .... F .... I .... 1 .... Ir .... ........ ' .................. '~ ............. i- ........ '~ .... F - --~l, .... ~ -I ~- - - -I ....... '~ - F .... ir - - - i .... --- I . I I ~It I It I I a ~ I .I ' ' ' I ' I I l~ I I~ 'i i - I _l .... '_~. I L [ ' i-- _L__- i ..... [ ___Lr~--t___-J .... L .... ..... , .... T .... r--~-, ......... i! ........ i-~--F:' ...... ~----r .... ,--'"~.~ f ', , ' ,. . . ' IP&AI ' ' ..... ~_-L_.~ .... L__~, ......... t[ .... ' .... .z .... L ...... · .... L .... , .... ~ ~ .... · .... L .... '-ILooolno I--'1 I .... -~ .... L .... - , 1, 1' , , , ' ' ' " T--~"-~ ' '/- ~ "l · ', ~I. , I. I I I I I I ' ~ ~ ~ i , '' ~' ~ ' I I I I '1 I ~l I ~'1 I - ' ' --Ii 'f I .... IP -- ''-- til ....... ~""~F'-- I1" .... II .... ~r I .... II- ........ -I'1 .... . Iff .... ' II- - - ~' -I I ........ II .... -t I ~"~""~ - - --N~d~ .... I ...... ~. ~ t- --I· .... "t ~1 .... .... ~ I- .... .... ..................................... F ........ I ............ I .... I- .... v v v - - ' ~ ~ It 7~--F ~, r ~, , , , , r , , , , _, I I I ~ ~ · _ ......................................... ' ........ - ' T ~' ~---r ........ ~ .... r .... ~--- i i i i .i i i i i i i ..... ~ · , , i i I' I I I I _1 i i i _l .... J_ '. L .... i .... 2 .... L ........ -' .... '- ..................... -. .... I I I I I I I I I I I. I I I I I I I I 0 5 10 15 20 25 11.8 11.5 11.2 9.7' 9.4 9.1 · Rig Release 3/7/94 Spud 2/11/94 DAYS -1000 -. -200O -3000 -4000 ~ -5000 .. -6000 _ -7000 -L8000 -9'000 --10000 ' Sp,ud ~/23/95 . J16" csg pre-set @ 108' J I i i _ _1 .... -L - - - -[ I I I -I- - -- I- - - - -'f --- - / I I DRILLING TIME AND.MUD WEIGHT CURVE FIORD #3 / 3A i i i i L___J ..... ~ .... L I I I I .... I .... / I I I ..... i"- =- 5 .... ~ .... F--- i i i i i I L - - - ..I .... I ..... ' - J .... ~ .... I I I I I I- - - - .-I .... I ...... ~- *-t .... I I I I I I i - - ~ .... ] ....... -i .... ] .... 12-1/4' hole / / I '-- -- -- I- -- -- -- ,,4 .... I ..... I I I I ; ....L___J .... I___ I I I I I I I I L_ I I---- I I Set 9-5/8' csg @ 1805 -- -- -- -1. - - - ~..I .... I---- I I I i J _ _ _ .J. .... I .... L _ _--.[ I I I " I I j .... r ;-il T ..[Drill 8-1/2' hole I i i i i ___/ .... I .... L___l .... I I ·/ I - -- -- -I- .... I .... l- -- -- - -I- .... / I I I T i i · I 4. .... I---- I I i .... L I .... I--- I .... L---~ I I I I I ' i' I I ' I 4 .... I -- -- -- I------- I I I "-I .... I ....I'- I I -1 ....I ....I- ------ I I I I ..J. .... I ....L _-- -- I I I -J' .... I ....l- -- - -- I I I 'i i i I I I ___J.__~_~ .... L___ I I I ----1' .... I .... I---- I I I i 'l ------4- .... I .... I------- I I I I I I -- -- -- I I L I L J. I I I I I I I I I I I J I L_--- I I I I i i i · i .... I .... /_ _ _ Begin drilling Fiord #3A .... ', .... ' I I I I I 1.. J .... I-- 4 .... I .... I I I I I I I .... I-- -- - -1 .... I .... I I I I [ i [ i' i.... I- 4 .... I ....1- -- -- -- I I I I --e-- Depth ........ Mud Weight j .... i_ I I '-t .... I .... I I ~ '1 I I I I I ---,~ I ,~ i -',- t--- I I I I I I I I I I t-----1 t-- ---1 .... I ....t---- I I I I I 'i --T---5 .... ~ .... T--- I I I I I I I I I ___J /___J .... I ....L--- I ..i .~1 I I I - , - - - 10.7 I I I .... I .... L I I I I --_-JLogging I:--- I I ¢___ I I I ---1 .... I .... r I I I i ', i 10.6 10.5 10.4 I I ------1 ......... I I----4 ....... I---- I I I I I. I L___I ......... L___ I I I '' i--- --1 --' ..... I-_~ -- 1 I I I t F---~ ...... [ --~ I-------4 ......... I-------4------ I .I I I i i .J ....I ....L I I I I ' 10.3 I I I r I ' jl .... Il ....iL___ Ji .... ~ -' ........ I .... l .... ,*---i ' I I ~ I 10.2 L _ - - ' - - )rill 8-1/2' hole to TD of 7410 .... ~-% - - , - - - ,,- - - - -~ - - - I I I I I Ir I J i I - - - ~ .... I .... T - - i ' ' ' ' ' ' ' ' ' ' 101 I I I I I I I I I I I l ---'---' ......... ~---I ,~---I ......... ,~--- I I I I I I I I -, .... i- i .... .... I .... I----.4 l-. - - - -.I .... I .... Plug back from TD @ , , , , , i , I I I I I 7030 to 1807 _, .... L _ _ _ -~ ...... I I I . -I ........ I- I I I I I I _1 ....L ........ 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 .... ~ .... F---'i .... , ..... i .... J- --i' ~ .... T----i .... I .... T--- -I- i- .-I - - - I ....... .-I .... I ....I- - - - 4 -- -- -- 1- - - - .4 -I- I I I I I I / " I I I I I ~..] I I I I I I .......... -.~- - - - I- - - - '"1 ...... I- -1 -I ....~' ,'- I : I _o,. , , , , , , F___~ .... ,--- ~'---,-~-- F---~ ...... T---g .... , .... T--- i- I .---I .... .4 ....I- -.~- - I- - - - .4 ...... ~- - --.4 ....I ....~---- I I I I '~ I I I I I I I ___li J L-_-J .... I ....,L__- - I I ,L____~ -,- ' ~ .... '- ''X----1_~ .... ......... Plug and"---'~Abandon' .... --'------- ' ' ' --:- t r-:-~ -,- '~:- - ~ II- ------4,/ --I-- I . -Il .... II-- II- -- ,-~-- .4 ~ I .... -~----- ~-----~ I I ......... I I.- I I I I I I I '~1 I I I I L_--J I J .... I_ L :~_ _ _ _, ,,_ _ _ _~ _ _ _ ..~ ........ L I I II I J .... I .... L II I I --I- I I .... I '1 .... I- I I 5 10 15 20 DAYS 10 9.9 9.8 9.7 25 Rig Release 4/15/95 lO00 2000 7000 8000 DRILLING TIME AND MUD WEIGHT CURVE Fiord #4 --e.-Depth -----Mud Weight ...... '. ..........'.'~. _ _ . .'. .......... '- ........... -' .... I I ...... ' ...... iiilii~iiill iiillX_~/iiiiiil] GasCutMud '@3581~ ]iiiliiiill iii:iiiiiill : i : ~ : / Raise MW to 10.5 I " " ~ " - ::::::;: ~ _ _"x~:: ;/: _~ ~ ..... :: .......... . ........... : .......... ,_ .~ ....... ~_-~ ...... ,~.~~---- 1 ----~----\ ...... ~ .......... ~ ..... , ..... ~ .......... ~--¥--.~---!- ~.- .... ................. : ..... ~i:- .......................................... ;~: .... ~"--S-: ...... ......~, ?~ (;:, ~...] ~ ~,~ ..... '. .......... '_ .....,..' ~.,_ _ . _ L ........... ' ........... ' .......... ' -~ ;.~) ....... : ~.' ............ i ............. \ ........................................ ~ ~-- ,~:---, ........ ............ , ...................................................... ~-~_. ,,:?_. _~_'~. ...... ...... ! .......... ! ..... ~ ........... ~ ........... ~, .......... i" ~ - ~5' - -!'~! ...... : .......... ~ ..... ~ .... .~ ........... ~ ........... ~. .......... ~..__~ ...... ~ ...... ...... ~ ..... i ..... ~ ..... ~ ................ .~ ........... .~ .......... ~ _ _ _r-L ....... ., ' ' I I ~ Log @ 7171' MD ~ ~ ~ ~ ~'~, ..... : ...... ..... ; ..... , , , , ..... -, ........... -, ...... ...... ~ .......... ~. ........... ~ ........... ~ ........... .~ .......... ~ ........... 4 ...... ...... ~ ........... ~ ........... !. ........... .=. ........... !. .......... ~ ........... J ...... 0 2 4 6 8 10 12 14 11.4 11.2 11 10.8 10.6 10.4 10.2 10 9.8 9.6 9.4 9.2 9 8.8 8.6 8.4 8.2 TIME TO DRILL (DAYS) Spud 2/28/99 Rig Released 3/13~99 Fiord #4 time mw graph by sdr 01 10 01.xls lOOO 2000 3000 4000 50O0 6000 700O 8OOO DRILLING TIME AND MUD WEIGHT CURVE Fiord #5 --e-- Depth -----Mud Weight - ~-i' ' ' i- - - ! ' - -i ...... !-" i' - - ! - - '! ...... ! - ' 'i' - - i- - - ! ...... i--- !--' i' - -: - ' ' ~; 'i''':' ~'/i''- i"-' ' -X! - - - J- - - ¥ - - -~ ...... ~ - - -~- ' - ~ - - -~ ...... ~ - - -~ - - - ~- - - · ...... ~- - - ~ - - -~- - - ~ - - - ~- - ~- - - T - - -~ ....... ' ~ ' ~ ' ' ~ i ~ , ~ 0 -~3~ ~ ~;-~" "~ , --~ - 19-5/8" set ~ 2788' [ - - -,- - -, - ' -, ...... , ............ ~- - - ',- - - , - - -,- - -, .... ~.: -,-~ ,~ , - ~ ;,. .... ,- - - ' "-:--';~' ' ' ~---"'':---, .......... ,-'',''-;-----','''~''-,'--:'':~'~',' ; ' . ....... . _ _ ,- - . ~ - . .,.. _ ~ - . ~-~ -,- - . ~. - ~ -,~ - -, · .: .... : , , , : : : , , , : , , .... , ' - -] - - ' [' - - ~ - ' ', ...... ~ - - -t- - ' f ........................................ :~ .................................... i ........ ' .... ........ ~°' .... '-'~ '~:~,. ~' ~ ~ ~ ' - - -, ...... ~- -~- - - :- - - -: ...... X- -:- - -',- - - ~ ...... :- - - ~- - -:- - - ~ .... ~;', .... ~ - - ~:~)- - ', .... .... :' - ",' ' ' ~ - ' ': ..... ~---:-'' ~---',-'-'--~ .... ~ ...... ?-- ~--'~ .... , ' I '--',- ' - ~ - - -~- ' -: .... -I ko~7410'MD ~._ ;_~_:___ ~.. _: ...... g __,__ .:.._ ;__~~ Ooro~01~'1o702S~ ~__ .:__ _' .... - .......... !__ :..~ ~ ~ ~ ~_..'.._'___: ...... ~~~~2 . _:___ ~__ _'...'.._ - - -',-- -:- - - ~ - - -:- - -- -- ~- - ~- - -~- - T- - ?[ - -~- - -:- - _2_ _ _ ~ ...... '~ _ _~ ...... 2_ __ ', _ _ .2. _ _:_ _ _- -- -'-'-'---~-- -' ...... ~---'---~-- -' ...... ~-- -'---:tC°r°f~02S't°7082'l~---'---~ ...... '---~-- -'---'--- 0 5 10 15 20 25 11.4 11.2 11 10.8 10.6 10.4 10.2 10 9.8 9.6 9.4 9.2 9 8.8 8.6 8.4 8.2 TIME TO DRILL (DAYS) Spud 3/14/99 Rig Released 4/5/99 Fiord #5 time MW graph by SDR 01 10 01.xls Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 PHILIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY January 2, 2001 Daniel J. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 ,Alaska Oil & Gas Cons. Commission Anchorage Re: Application for Permit to Drill Phillips Alaska, Inc.- Nigliq #1 Surface Location: 156' FSL, 1031' FWL, SEC 2, T12N, R4E Target Location: 1019' FSL, 320' FWL, SEC 2, T12N, R4E Bottom Hole Location: 4260' FNL, 4975' FEL, SEC 2, T12N, R4E CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well; the Nigliq #1. Nigliq # 1 will be drilled from a 500'x 500' ice pad located approximately 5.7 miles North by Northwest of Alpine. The well is designed to penetrate through the Kuparuk C to the base of the Nechelik. As a contingency the well will also penetrate through the base of the J3 marker with enough rathole for wireline logging. At the conclusion of drilling and evaluation operations, Nigliq #1 will be permanently abandoned. There will be a temporary storage area for drill cuttings on the ice pad. All cuttings will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Waste drilling mud will be hauled to an Alpine Class II disposal well or to a KRU Class II disposal well. Because the "Shallow Hazards Analysis" (Attachments 8 & 9 as listed below) will not be available at the start of the 30 days requested for reviewing the APD. Phillips would like to request the AOGCC start the APD review without the "Shallow Hazards Analysis". The "Shallow Hazards Analysis" should be available within 5 working days of the APD submittal. There are no shallow hazards expected at Nigliq #1. Inspection of the "Shallow Hazards Analysis" provided for Fiord #4 and Fiord #5 indicate no overpressured intervals or lost circulation zones. The surface distance from Nigliq #1 to Fiord #4 and Fiord #5 is 6 miles and 4.5 miles respectively. See discussion under "Drilling Area Risks" Please note that Phillips does not anticipate the presence of. H2S in the formations to be encountered in this well; however, there will be H2S monitoring equipment operating, as is the usual practice while drilling wells in the Colville River Unit. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed cementing program and calculations. 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Prediction of overpressured strata as required by 20 ACC 25.033 (e). 9. Seismic refraction and reflection analysis as required by 20 ACC 25.061 (a) 10. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 11. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Paul Mazzolini at 265-4603 Sincerely, Paul Mazzolini Drilling Team Leader Attachments FEB 0,9 ?n¢I ,Alaska Oil & Gas Co~qs, Commission Anchorage CC: Nigliq #1 Well File / Sharon AIIsup-Drake Paul Mazzolini ATO 1530 ATO 1570 American Express' Cash Advance Draft ~ 16 ,~,, F~..~,.~,I ~, ~/ I~u~ by I.~d P~yme.~ S~m~ Inc. En~w~, Co~o NO~ALID ~OE AHOUN~ OVEE $1000 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 P i',LLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY CONFIDENTIAL January 2, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Phillips Alaska, Inc. - Nigliq #1 Surface Location: 156' FSL, 1031' FWL, SEC 2, T12N, R4E Target Location: 1019' FSL, 320' FWL, SEC 2, T12N, R4E Bottom Hole Location: 4260' FNL, 4975' FEL, SEC 2, T12N, R4E CONFIDENTIAL Dear Mr Maunder: Enclosed is 3 copies of the "Pressure Analysis and Prediction" for Nigliq #1. The "Pressure Analysis and Prediction" for Nigliq #1 is a supporting document for the Nigliq # 1 Permit to Drill submitted to the AOGCC on January 16th, 2001. I apologize for the late submittal of this document. Problems with the software used to generate the reports delayed the analysis. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Paul Mazzolini at 263-4603 Sincerely, Scott D Reynolds Drilling Engineer, Alpine F-----II3 o 2 2001 Alaska Oil 8, Gas Cons. Comrnissior~ Anchorage Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-26%1215 P iLLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CONFIDENTIAL NIGLIQ # 1 PRESSURE ANALYSIS AND PREDICTION DISCUSSION: (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) An analysis and prediction of overpressured strata was performed for the Nigliq # 1 well as required by AOGCC regulations. Phillips does not expect to encounter abnormal pressure from any zones penetrated by the wellbore. This prediction is based on evaluation of the offset wells: Temptation # 1, Nechelik # 1, Fiord #2 and Fiord #5. Fiord #2 encountered a gas influx at 2915' MD / 2500' TVD; however, further seismic analysis that the pore pressure anomaly around 2,250' in the Fiord #4 & #5 pressure prediction analysis was due to a sandy silt interval and not shallow gas. The Fiord #2 gas influx is discussed in further detail in the "Drilling Area Risks" section of the APD. Attached are the following: Seismic Analysis for Nigliq # 1. Pore pressure and frac pressure graphs. FEB 0 2, 2001 Alaska Oil & Gas Cons. Commission Anchorage PHILLIPS PETROLEUM COMPANY To: Jeff Zawila Dave Bannan Scott Reynolds ATO-1464 ATO-866 ATO-838 From: Kathy Heinlein ATO-1346 Subject: Date: Pre-Drill Seismic Pore Pressure Prediction for Nigliq #1 January 29, 2000 Summary Seismic velocity data was used to predict pore pressures likely to be encountered in the proposed Nigliq #1 well location. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from surrounding area wells (Temptation #1, Nechelik #1 ). The local compaction trend and the translation trend model were applied to velocities from 2D and 3D seismic data to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the proposed well location. Seismic Processinq The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used for pressure prediction were generated using Phillips' AVEL software, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 CDPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in CDP fold. cuciVED FEB 0 2, 2001 Alaska Oil & Gas Cons. Commission Anchorage Pressure Prediction Procedure Phillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the predicted pore pressures. The Temptation #1 and Nechelik #1 offset wells were used to establish both a local normal compaction trend line and local velocity vs. pressure translation trend model. The model is similar to models used for previous pressure prediction in this area (Wydrinski 1999) but has been updated based upon recent drilling results (Fiord #4, Fiord #5). The model is similar to the models used for pressure prediction projects at Alpine, NPRA, and Tarn. Procedure 1 .) A Normal Compaction Trend Line (NCTL) was determined for a series of seismic lines from the Fiord West 3D seismic dataset. The seismic-derived NCTLs were variable, and it was difficult to match to the NCTLs calculated from area well data. A reasonable match was found, but further work is recommended to determine the validity of the 3D seismic velocities in this area. A slope of-4.5e'5 and intercept of 168 was used for this study. The slope matches the slope measured in the area wells; the intercept is very close (168 seismic vs 165 wells). 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (AT) in the existing wells or by seismic velocities in the proposed wells, and the Interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences, AAT. 3.) A translation trend model was established by comparing transit time differences (AAT) to mud weights, This model calculates pressure gradients (PP) using the equation PP = C2*AAT**2 + C1 *AAT + CO Where C2 = 8.01e'5, C1 = .0019, CO = .465 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). RECEIVED Alaska Oil & Gas Cons. Comrnission Anchorage Seismic Pore Pressure Prediction Pressure gradients were predicted for the Nigliq #1 proposed well location using 3D seismic data. A cube of data was calculated surrounding the proposed deviated borepath. Pressure gradient prediction displays are provided for the lines from the Fiord West 3D dataset, both in time and in depth. Predicted Pore Pressure Gradient Displays in Depth: Figure # Seismic Line Proposed Well Location 1 IL 1749 Nigliq #1 (surface) 3 XL 1244 Nigliq #1 (surface) 5 IL 1742 Nigliq #1 (td) 7 XL 1252 Nigliq #1 (rd) Predicted Pore Pressure Gradient Displays in Time with Migrated Time Overlay: Figure # Seismic Line Proposed Well Location 2 IL 1749 Nigliq #1 (surface) 4 XL 1244 Nigliq #1 (surface) 6 IL 1742 Nigliq #1 (td) 8 XL 1252 Nigliq #1 (td) Warmer colors indicate higher predicted mud weights (pore pressure gradients). No apparent shallow hazards are observed in the 3D seismic pressure analysis. A slight increase in predicted pressure is observed beginning at approximately 2800 ft. This increase correlates to a lithology change observed in the Temptation #1 well and is not interpreted to be indicative of a true increase in pressure. It should be noted that the 3D seismic data used here has a Iow effective fold in the shallow section (above 2000 ft), therefore reducing the reliability of the shallow seismic velocity calculation. It is general practice to run shallow hazards analysis on 2D seismic where 2D data is available with a higher effective shallow fold. 2D seismic data was available for this area (WKE93-17) but the velocities available were found to be unreliable for pressure prediction. Pressure prediction will be run on WKE93-17 after further refinement of the AVEL velocities. RECEIVED FEB 0 ~ 2001 Alaska Oil & Gas Cons. Commission Anchorage Pore Pressure Gradient Prediction at Proposed Well Locations Figure # Seismic Line Well Location 9 IL 1749, XL 1244 Nigliq #1 (surface) 10 IL 1742, XL 1252 Nigliq #1 (td) Conclusions 1 .) There are no apparent shallow hazards at the proposed Nigliq #1 well location observed on the Fiord West 3D seismic dataset. 2.) Overpressure has not been encountered in wells drilled previously in this area (Temptation #1, Nechelik #1, Fiord #5). 3.) The normal compaction trend observed in the Temptation #1 and Nechelik #1 wells matches the compaction trends observed in other area wells (Alpine and NPRA). 4.) The seismic-derived normal compaction trends are variable and not a good match with the area wells. 5.) Expected pressure was calculated along a 2D line (WKE93-17) to take advantage of the higher effective fold in the shallow section above 2000 ft. The calculated pressures did not match area wells (Temptation #1) and the 2D velocities available to use in the analysis were determined to be unreliable. 6.) Follow-up work is in progress to determine if the seismic velocities (both 2D and 3D) in this area can be improved, thus resolving the observed ambiguities in seismic vs well normal compaction trends, and potentially giving a more accurate pressure prediction. Kathy Heinlein FEB 0 Alaska Oil & Gas Cons, Commission AnchoFage PNtkLIP$ PETROLEUM COBi}PAN¥ Proiect: Nigliq Method: Trend Curve Pore Pressure and Fracture Gradient System Cross Section: IL1749 NCTL: 168-4.5-5 1/29/01 K Heinlein Model: OST/NS Seismic Line IL 1749 (depth) 1000,8 Figure 1 Proiect: Nigliq Method: Trend Curve Cross Section: IL1749 NCTL: 168-4.55 Model: OST/NS PHILLCPS PE'%ROLEUM CO~'~PAN¥ Pore IP~essum arid Fracture Gradient System Seismic Line IL 1749 (time) C'I)P lntervai= 11(} ~t Figure 2 Pb~SL, L~P8 PBTBOBE~7~ O©MPANY Pore Pressure and Fracture Gradient System Project: Nigliq Cross Section: XL1244 Method: Trend Cun/e ~ NCTL: 168-4,55 Model OST/NS Seismic Line XL 1244 (depth) CDP l~terval = t 18 ft Figure 3 P~ff~LL~PS PETROLEUb~ CO~¢)PAN¥ Project: Nigliq Method: Trend Curve Pore Pressure and Fracture Gradient System Cross Section: XL1244 NCTL: 168-4.5.5 1/29/01 K Heif31ei~ Modeh OST/NS Seismic Line XL 1244 (time) Figure 4 P~41LLIPS PE ~'ROLEU~%~ CO~'/~PA~,¢Y Project: Nigliq Method: Trend Curve Pore Pressure and Fracture Gradient System Cross Section: IL1742 NCTL: 168~4.5-5 1'29/01 K Heinieil~ Model: CST/NS Seismic Line IL 1742 (depth) 3000,0 ?OO0,0 CDP lnterwl = 110 ~'t Figure 5 PN~LLaPS PETROLEU~v$ COM?A~'aY Project: Nigliq Method: Trend Curve Pore Pressure and Fracture Gradient System Cross Section: IL1742 NCTL: 168~4.5-s 1/29/01 K Heinlein Model: OST/NS Seismic Line IL 1742 (time) s N CDP lntervat = t 10 fl Figure 6 P~4ILLIPS PETROLEU~ COMPANY Project: Nigliq Method: Trend CurveI Pore Pressure aad Fracture Gradient System Cross Section: XL 1252 NCTL: 168-4.5 1/29/01 K Heinlein Model: CST/NS Seismic Line XL 1252 (depth) CI)I~ latcr~,at = / It} ft Figure 7 PHILLIPS PETROLEU~a COBCPAN¥ Proiect: Nigliq Method: Trend Curve Pore Pressure and Fracture Gradient S~'stem Cross Section: XL1252 NCTL: 168-4.5-s 1/29/01 K Heiniein Model: OST/NS Seismic Line XL 1252 (time) CDP ~n~ervat = 110 f~ Figure 8 PN~LL~PS PETROLEUM COMPANY Project: Nigliq Pore Pressure and Frscture Grsdient System Well: Nigliq 1 1/29/01 K Heinleir~ NCTL: 168-4.5-~ Nigliq 1 (surface): Velocity from IL1749 at XL1244 3808 Figure 9 PHiLLiPS PETROLEU[~¢~ CO~¢PANY Pore Pressure end Fracture Gradient System 1/29/01 K Hein~ein Proiect: Nigliq Well: Nigliq 1 NCTL: 168-4,5-s Nigliq 1 (td): Velocity from IL1742 at XL1252 ?_ 4800 6000 Figure 10 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION APPR DATE ~ ,~. £NGINEERING COMPANY /~/,'t'//z~g WELLNAME~//,~"/¢/ PROGRAM:exp [/' dev : -u. ' .--- -.=..j ~ INIT CLASS ~'-"X'~'L-C/~,)/.'-.~.. ~:;~, '- O/~ 5 GEOL AREA 1. Permit fee attached ....................... 2. Lease number appropdate.~ ................. 3. Unique well name and number .................. 4. Well located in a defined pool ............... . ..... 5. Well !ocated proper distance from drilling unit boundary':.~.. 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... DATE ._ . 14. Conductor string provided ................... 15. Surface casing protects all known USDWs... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations ....... .... 24. Ddlling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation ................ 26. DOPE press rating apPropriate; test to ._~L.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. reddl serv wellbore sag ann. disposal para req ~/:~'~% UNIT# ~%//-? ON/OFF SHORE ~ ' 'N - ' ~'~. _ . -' GEOLOGY , 30. Permit can be issued wlo hydrogen sulfide meas.?es ..... ~N 31. Data presented on potential overpressure zones'~. ...... C-~,.PN AP~R DATE . 33. Seabed cond~bon su~ey (d off-shore) ............. ~, ~6 J 34: Conta~ name/phone for weekly progress repods [explorato~ only] ANNUN~N UI~FU~aO. VVltn proper cemem~ng recoras, tins plan . (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or ~use drilling waste... ' to sudace; (C) wdl not ~mpmr mechamcal mtegn~ of the well used for d~sposal; (D) will not damage producing formation or impair recove~ from a pool;and ' ' (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. ~EOL~:/ ENGINEERING: Ul~nular COMMISSION: c:\msoffice\wordian\diana\checklist (rev. 111011/00) Z .-.I :!:
