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" # # $%& '#( ))* + , - ))*. -+ " $%& ))* +, ))*. -+ " $%& ))* +, ))*. -+ " $%& ))* +, ))*. -+ " $%& ))* +, ))*. -+ " $%& ))* +, ))*. -+ " $%& ))* +, ))*. -+ " $%& ))* +, ))*. -+ /0/ 0 0 0 101 -0-234 $! 5 0678$ 606 0&0.94&$ 0$$ , 04 / : -0-234 $ 5 !0! $" !"#$ " #%&$' ""; %",<+-188 $ ; %",<2% ; %",$2 :$; %", 8$ 2 ! .+=>?)2@$A /,4)))>)*$B: ++2 ?'? 6 C+)*.$4"$"4 3B:5 () 63., 4?'5 $A35> > Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 204-006 Type Inj N Tubing 0 3010 2925 2900 Type Test P Packer TVD 7498 BBL Pump 0.1 IA 0 Interval O Test psi 3000 BBL Return 0.1 OA 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: ConocoPhillips NPRA Exploration/Bear Tooth Unit Scout #1 Wavied By Brian Bixby. BLM rep on location. Quinn Sawyer Aaron Applehans 02/27/22 Notes:MIT-T For P&A. BLM Rep on location durinig cement tag and test. (Quinn Sawyer) Notes: Notes: Notes: Scout #1 Form 10-426 (Revised 01/2017)Scout #1 10-426 (1) ! 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'8"')'18 %84.0) 18(4> "#$#%$&#'()$##$## ?,88-.8J J =44)8 &#'$##* " =J/ D$ 6%18 0(11> '99'8'' -%9'H :*5 7 $$+ =0(41>:*0(41>;* ;$9 + , 81> '(-.> ! -. 8%(8- # -9'8'8 ./ 0 /01.&2+1.2+ 0 1 ./3 By Samantha Carlisle at 1:10 pm, Jul 01, 2021 321-326 Tyson Wiese Digitally signed by Tyson Wiese Date: 2021.07.01 12:45:57 -08'00' SFD 7/2/2021 VTL 8/4/21 AA-081857 X DSR-7/1/21 X DLB 07/01/2021 AOGCC inspection is required after cutoff and before any remedial cementing. 10-407 X X dts 8/5/2021 JLC 8/5/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.05 12:30:23 -08'00' RBDMS HEW 8/6/2021 !!" # $ %& '(&&) && ) && % ( *+%,#*$ -./ %'*$".. -!..0 1 2 *1& ( 3 -2,11 &(& 1 &) 2,1(& ( ) 2 ) -45/ 2.-+01 )6789 & ( 2# )1 1( 1 ) %&& & )2 ,& & %:& 1 )1&& ) & && ))%: & 2 11 8 )&& ; ) 2 ') 8 8)) & !. /"./!+ ))0 !. ."<<+02 $ % & % ( 2 % & 2 ') 8 8)) & !. /"./!+ ))0 !. ."<<+02 , ))= %&. ,11 & &(& 1 &) 2, Note: DLB >?5%&$@%&% *$ !"# $% & &' () * ( + & !"#) ,- ' ) ' ( ( '.& / (0+ ! "#$%%% ! 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Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:SCOUT 1 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: EXPLORATION WELL (tight hole) 4/23/2013 SCOUT 1 osborl Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 25.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 24.9 Set Depth (ftKB) 2,436.0 Set Depth (TVD) … 2,436.0 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 24.8 Set Depth (ftKB) 7,661.0 Set Depth (TVD) … 7,660.0 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,481.9 Set Depth (ftKB) 8,050.0 Set Depth (TVD) … Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,481.9 7,481.2 3.19 PBR TIEBACK POLISH BORE TIE BACK RECEPTACLE 5.500 7,498.2 7,497.5 3.14 PACKER ZXP LINER TOP PACKER w/HOLD DOWNS - HRD PROFILE 4.960 7,507.8 7,507.0 3.13 HANGER FLEX LOCK II HYDRAULIC LINER HANGER 5.510 7,517.2 7,516.4 3.13 XO BUSHING CROSSOVER BUSHING 3.930 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.7 Set Depth (ft… 7,510.0 Set Depth (TVD) (… 7,509.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.7 24.7 0.00 HANGER FMC GEN V TUBING HANGER & PUP JT 3.500 1,007.6 1,007.6 0.31 NIPPLE CAMCO DS NIPPEL w/2.875" NO GO PROFILE 2.875 7,454.5 7,453.8 3.30 NIPPLE HES XN NIPPLE w/2.75" PROFILE 2.750 7,495.0 7,494.3 3.14 LOCATOR BAKER 5.76 "LINER TOP LOCATOR 3.950 7,495.7 7,494.9 3.14 SEAL ASSY BAKER 5" BULLETT PBR SEAL ASSEMBLY 3.937 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.1 2,525.1 0.32 CAMCO KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 3/27/2004 2 7,316.9 7,316.5 3.46 CAMCO KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 3/27/2004 3 7,406.4 7,405.8 3.49 CAMCO KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 3/27/2004 Notes: General & Safety End Date Annotation 4/7/2013 NOTE: SET VR PLUGS ON IA & OA, BPV INSTALLED, POST MITT 3/27/2004 NOTE: WELL SUSPENDED ***NO PERFORATIONS***, Freeze protect annulus w/Diesel SCOUT 1, 6/30/2021 9:08:14 AM Vertical schematic (actual) LINER; 7,481.9-8,050.0 PRODUCTION; 24.8-7,661.0 GAS LIFT; 7,406.4 GAS LIFT; 7,316.9 GAS LIFT; 2,525.1 SURFACE; 24.9-2,436.0 NIPPLE; 1,007.6 CONDUCTOR; 25.0-108.0 WNS EXPLOR KB-Grd (ft) Rig Release Date 3/28/2004 SCOUT 1 ... TD Act Btm (ftKB) 8,050.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032047900 Wellbore Status EXPLOR Max Angle & MD Incl (°) 3.52 MD (ftKB) 7,399.77 WELLNAME WELLBORESCOUT 1 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mr. Shon Robinson Alaska Wells Manager PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons Dear Mr. Robinson, By letter dated November 23, 2020, CPAI proposed well plug and abandonment (P&A) programs for the 2021 and 2022 ice road seasons. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A programs for the wells listed below for the 2021 and 2022 ice road seasons with the P&A work to be completed by May 31, 2021 and May 31, 2022 respectively. May 31, 2021 Lookout 1 (PTD 201-003) KRU 1M-17 (PTD 201-230) Kuparuk 28241-1 (PTD 181-035) May 31, 2022 Scout 1 (PTD 204-006) Cassin 1 (PTD 212-182) Cassin 6 (PTD 212-196) Wells KRU 1M-17 and Kuparuk 28241-1 each require the submission and approval of an Application for Sundry Approvals for suspension renewal in January 2021. Approval of an Application for Sundry Approvals will be required for plugging and abandonment operations for each well. Approval is also granted for the deferral of the Scout 1 suspended well inspection to May 31, 2022. If you have any questions please contact Victoria Loepp at (907)793-1247 or at victoria.loepp@alaska.gov. Sincerely, Jeremy M. Price Chair, Commissioner cc Victoria Loepp, AOGCC JMPi Dear Commissioner Price, Due to low oil prices, budget constraints, and a need to minimize nonessential remote work considering spiking COVID-19 cases statewide, Conocophillips Alaska, Inc. is revising our winter 2021 ice road scope of work. Our initial plan was to execute the following P&A’s: x Lookout 1 x Scout 1 x Cassin 1 x Cassin 6 As has been discussed with AOGCC staff, we now propose to perform the following P&A’s instead, staying closer to infrastructure, in 2021: x Lookout 1 x 1M-17 x Well 28243-1 (for Exxon) With that change, we expect to perform the following P&A’s in 2022: x Scout 1 x Cassin 1 x Cassin 6 The Scout 1 well is overdue for its 5-year suspended well inspection under 20 AAC 25.110(e) because of last year’s early ice road exit due to measures taken to project against the COVID-19 pandemic. We do not believe that deferral of inspection until 2022 would present a safety or environmental risk. For the reasons described above, we seek modification of the inspection deadline for this well to May 31, 2022, as allowed under 20 AAC 25.110(n). Thank you for your consideration, Sincerely, Shon Robinson Manager, AK Wells Shon Robinson Alaska Wells Manager 700 G Street, ATO (99501) P. O. Box 100360 Anchorage, AK 99510-0360 Phone (907)-265-6306 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Friday, March 20, 2020 11:02 AM To: Senden, R. Tyler; Loepp, Victoria T (CED) Cc: Regg, James B (DOA) Oim.regg@alaska.gov) Subject: RE: Scout 1 (PTD 204-006) and Lookout 1 (PTD 201-003) Inspection=_ Ty, The AOGCC will allow CPAI to forego the planned 2020 winter inspections of Scout 1 and Lookout 1 as requested below. As we discussed earlier the COV 19 virus is impacting winter ice activity and these two wells can be inspected (including taking pressures) next ice season. Additionally, verify that the well signs are legible per our conversation. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commis ^ion (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 i or (Guv schwartz@alaska aovl. From: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Sent: Thursday, March 19, 2020 12:46 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Scout 1 and Lookout 1 Guy / Victoria, With COVID-19 pandemic measures being taken at the State and local levels we are being forced to ramp down our exploration drilling and all ice road activities, including the proposed Scout 1 and Lookout 1 well inspections. With that in mind, we'd like to ask for an additional year to complete these inspections, which if the wells pass, would enable us to obtain the extension needed for a long term suspension. If approved, we'd plan to have the inspections completed by April 30, 2021. Please don't hesitate to contact me if you have any additional questions. Thanks, Ty Senden Director, Integrity, Interventions, Well Testing and Workovers Conocophillips Alaska, Inc. ATO -1396 907-265-1544(o) 907-982-3996(C) r.tVIer.senden@cop.com THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: NPRA Exploration Field, Scout #1 Permit to Drill Number: 204-006 Sundry Number: 319-313 Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9'y -c Jessie L. Chmielowski Commissioner DATED this k day of September, 2019. RBDMS 9"'SEP 0 9 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS RECOVER JUN 2 8Zp DTS ? C�� p AOG ' 1. Type of Request: Abandon ❑ Plug Perforations ❑ `Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Ext of Suso ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conoco Phillips, Alaska, Inc. Exploratory Q Development ❑ 204-006 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 100360, Anchorage, AK 99510-0360 50-103-20479-00—ab /0 Wil, 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Scout #1 9. Property Designation (Lease Number):ld/Pool(s): 10. Fie AA081857 ' NPRA Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8050' • 8049' ' 7953' 7952' 3050 Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 16" 108' 108' Surface 2408' 9.625" 2436' 2436' 5750 3090 Intermediate 7633' 7" 7661' 7661' Production 7240 5410 Liner 1569' 4.5" 18050. 8049' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 3.5" L-80 7510' Packers and SSSV Type: No SSSV Packers antl SSSV MD (ft) and TVD (ft): No SSSV PBR Seal asy @ 7496' 7496' MD 12. Attachments: Proposal Summary El Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/26/2019 OIL ❑ WINJ ❑ WDSPL ❑ ❑ ' Suspended 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chip Alvord Contact Name: Aaron Donat Authorized Title: Drilling Manager Contact Email: Aaron. Donat ConocoPhilli S.com ,As. nr•f1 61Z(' (21 \ � Contact Phone: 907-265-1089 Authorized Signature: S �+ec Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I G 311 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ 9 tY ❑ Location Clearance Other:// ' / H/G4fl I Post Initial Injection MIT Req'd? Yes ❑ No ❑ A� '' // Spacing Exception Required? Yes ❑ No g Subsequent Form Required: r{ON(.- RBDMS�' SEP 0 9 2019 APPROVED BY Approved by: I l,r� COMMISSIONER THE COMMISSION Date: l&/jn lXi J -c r� Q e1 d�1 Z�//y and Form 10-403 Revised 4/20 Approvetl application i I r date of a royal. SG is in Form and PP Attachments in Duplicate Conoco Phillips Alaska, Inc. ConocoPhillips Box 100360 Alaska 99510-0360 June 26, 2019 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of suspension status 10-403 Sundry Surface Location: Target Location: Bottom Hole Location: Scout #1 (Exploratory Test) 571' FSL, 232' FWL, Sec 20, T11N-RIE X=257,982.3 & Y=5,958,608.07 ASP4 NAD27 571' FSL, 232' FWL, Sec 20, T11N-R1E 571' FSL, 232' FWL, Sec 20, T11N-RIE Dear Commissioner: P �✓ nµi /U,y Gr uC��K�ia u u� ConocoPhillips Alaska, Inc. hereby submits a request for renewal of suspension status for the Scout #1 wellbore per 20 AAC 25.110. The well was visually inspected on 6/21/19 and the results submitted with a 10-404 sundry. Attached is a wellbore schematic noting the condition of the wellbore. Please note the following: • The wellbore is not perforated • Kill weight Fluid in the tubing and the tubing by 7" annulus to 1500',+/-MD/TVD with diesel . from 1500' MD/ND to surface.-*—,W5e- �.• .;f -as! -csf n= k„I f, Ee • Freeze protect diesel in the 7"x9-5/8" annulus to 1950' +/- MD/TVD • Cement to surface on the 9-5/8" casing / /9 • BPV installed in the tubing hanger. CPAI requests renewal of the suspension because the well is being held for purposes of future testing to assess reservoir productivity in support of ongoing appraisal activity and future development within the Bear Tooth Unit. Sincerely, Aaron Donat Senior Drilling Engineer ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 22, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry for Scout 1 (PTD 204-006) Commissioner Chmielowski, Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. well Scout 1 (PTD 204-006). The following documents are attached: - 10404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well continues to be held for future development of the area. Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Scout 1 Field/Pool: Exploration Permit # (PTD): 204-006 API Number: 50-103-20479-00-00 Operator: ConocoPhillips Alaska Inc. Date Suspended: 3/28/2004 Surface Location: 571' FSL. 232' FWL Section: 20 Township: 11N Range: 01E Nearest active pad or road: Meridian: Umiat Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean tundra Pad or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: N/A Photographs taken (# and area. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition r Wellhead/tree/valve description, condition: small incision - dry and Rat Hole: N/A Wellhouse or protective barriers Well identification sign: Si( Tubing Pressure (or casing if no Annulus pressures: No Wellhead Photos taken (# and d Work Required: Should install new sign Operator Rep (name and signature) AOGCC Inspector: Adam Earl Inspection Date: 6/21/2019 Time of arrival: Site access method: Tree & wellhead wrapped in herculite Looked outer Jan Byrne & Brandon Claudel Other Observers: N/A AOGCC Notice Date: 6/10/2019 Time of Departure: 10:30 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ✓ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abantlon Plug Perforations Fracture SBmulaa Pull Tubin g Operations shutdown Performed: Suspend Q Perforate ❑ Other Stimulate ❑ Alter Casing Change Approved Program ❑ Plug for Redrill ❑ perforate Nev, pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: 2. Operator ❑ Name 4. Well Class Before Work: 5. Permit to Dnll Numher: ConocoPhillips Alaska, Inc. Development ❑ Exploratory I] 204-006 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O.Box 100360, Anchorage, Alaska 99570 7. Property Designation (Lease Number): 50-103-20479-00 8. Well Name and Number: AA081857 SCOUT 1 9. Logs (List logs and submit electronic and printed data per 20AAC25.077 10. Field/Pool(s): 11. Present Well Condition Summary: Wildcat/EXplorat:ory Total Depth measured 8050 feet Plugs 9 measured None feet true vertical 8049 feat Junk measured None feet Effective Depth measured 7953 feet Packer true vertical 7952 measured None feet feet true vertical None feet Casing Length Size Conductor 83 MID TVD Buret Collapse 16" Surface 2411 9-5/8" 08 108 1640 630 2436 Production 7636 T' 2436 5750 3090 7667 I Liner 56872406-314" 7661 6050 8049 8430 5410 7500 Perforation depth Measured depth None feet True Vertical depth None feet Tubing (size, grade, measured and We vertical depth) 3.5" L-80 7510 MD 7494 ND Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: N/q Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bhl Prior to well operation: N/A Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Subsequent to operation: N/A N/A N/A 14. Atare Attachments 25.070,2&071,&2 zie) N/A WA N/A Daily Report of Well Operations ❑' Copies of Logs and Surveys Run 15. Well C/assaftervrork: Exploratory Development ❑ Service ❑ Stretigraphic [j❑ Printed and Electronic Fracture Stimulation Date ❑ 16. Well Satus after work: Oil ❑ Gas r7 WDSPL 17. 1 hereby certify that the foregoing is true and to GSTOR❑ WINJ El WAG C]GINJ ❑ SUS SPLUG ❑ correct the best of my knowledge. Sundry Number or N/A if C: mpt: N/A Authorized Name: Sara Carlisle Contact Name: Sara Cadisle/Rachel Kautz Authorized Title: Well Integrity and Compliance Specialist Contact Email: N25490co oco hllios Com Authorized Signature: � '' Date: Or/� p�'.Ipr- Contact Phone: 659-7126 Form 10-404 Revised 4/2017 Submit Original Only 1 13/6/04IG.D.IC.Z.I TB I ISSUED PER K03125ACS I I I I I Iy u. NOTES: 1. BASIS OF COORDINATES: ALPINE MONUMENT MON 19 AND LOUNSBURY AND ASSOCIATES MONUMENT "03-10-01". 2. COORDINATES ARE NAD 27, ALASKA STATE PLANE ZONE 4, 3. ELEVATIONS ARE REFERENCED TO BRITISH PETROLEUM MEAN SEA LEVEL DATUM (BPMSL). 4. DISTANCES ARE TRUE. ALL DISTANCES AND ELEVATIONS ARE IN ENGLISH FEET. 5. DATE OF SURVEY 3/05/04 KLiu kpik/LCMF A mbRidar9 at o7egvik MnptatCwVm t(m , Alpine Office(907)670-4739` Anchorage, Alaska 907 273-1830` Alpine Survey Office 232' S � f\\ \� i SCOUT #1 \ 00 O �\ or �3 > j C::) w w \ v N?O,OD'OD , A R SEC. 20, T. 11 N. R. 1 E., U,M. SEC, 29, T. 11 N., R. 1 E, U.M. HARRISON &1Y ra. PROJECT Vicinity Map Scout#1 LOCATED WITHIN PROTRACTED SECTION 20, T. 11 N., R. 1 E. UMIAT MERIDIAN, ALASKA 571' FSL 232' FWL OND ELEV.=100.8' BPMSL ICE PAD ELEV,=103.4' BPMBL NAD 27 Datum- / E BOND N 70'17.15.000" 35 \C/ N 151'57'33.012" ASPC ZN4 (Y) 6,958,808.07 M 257,982.30 \N SCALEI"=200' = ,�OF A��1j� r49 LTM * ...................... �• • • ,Brcdley W. Devine j LS -8412 _� � r SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 5, 2004. W/ ALPINE MODULE:AP00 UNIT:]AP ConocoPhillips SCOUT #1 �� Inc. EXPLORATORY WELL CONDUCTOR ASBUILT LOCATION CADD FlLE NO. DRAMNG N0: CE-APOO-1009 PART: 1 OF 1 REV: SCOUT 1 PTD 204-006 ©ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska. i ten. �"».+• ' ;M_ ..._.. '„^ i;,�. _ - - i I 4 SCOUT 1 PTD 204-006 ©ConocoPhillipsAlaska, I/ I This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska. tit'} 'y� �� `�� A ��, 4�+1 �� 4�l �: 1,�� P .5� 'f� �i°J'�trF ilN �� F p too n ei) 7" x 9-5/8" annulus was freeze protected with diesel to 1064' MD/TVD Scout #1 WELL SCHEMATIC Final Suspension Schematic 3-1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' MD 3-1/2" 9.3# L-80 8rd-mod Tbg to Surface with 2.91" special drift from surf to DS nipple @ 1007' MD 3-1/2" Camco'DS' nipple w/ 2.875" No -Go Prof. @ 1007' MD Surface csg. 9-5/8" 40# L-80 BTC @ 2436' M D/TVD with cmt circ to surface 3-1/2" x 1" Camco'KBUG' mandrel with dummy at @ 2525' 10.3 ppg kill weight brine with 1500' of diesel freeze protect in tbg and tbg x 7' annulus Top of 7" cmt est at 6661' 3-1/2" x 1" Cam co'KBUG' mandrel with dummy @ 7316' 3-1/2" x 1" Camco'KBUG' mandrel with dummy @ 7406' 3-1/2" Halliburton XN nipple w/ 2.75" no-go @7,454' MD 4-'/i' 1 BT pin x 3-1/2" 8rd mod box crossover @ 7493' 4-1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MD Top -set csg. 7" 26# L-80 BTC @ 7,661' MD No Perforations, 10.3 ppg brine in liner Production Liner 4-1/2" 12.6# L-801BT from 7,481' to 8,050' MD, cmt circ to top of liner • TD = 8050' MD/8049' TVD TAB 4/11/04 ConoCOpillllip5 Post Office Box 100360 Anchorage, Alaska 99510-0360 8/29/2019 Commissioner Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Commissioner Chmielowski, �I It has been requested that ConocoPhillips Alaska Inc. perform supplementary suspended well inspections to verify Tubing, IA, and OA pressures to complete the renewal of suspended well status for the following wells. The intent is to perform the inspections during the 2020 winter season. Lookout 1 (PTD#: 201-003, API#: 50-103-20359-00) Scout 1 (PTD#: 204-006, API#: 50-103-20479-00) Attached are the following: • Supplementary Well Inspection Plar • Current Suspended Well Schematic If you have any questions or require further information, please contact me at (907)-265-6342 Sincerely, vv�" Hanna Sylte Wells Engineer CPAI Drilling and Wells Conocoi hiiiip5 Post Office Box 100360 Anchorage, Alaska 99510-0360 Supplemental Well Inspection Plan: Primary Equipment Required: • Rolligon Transportation • Boom Truck • 2 Portable Heaters BPV Lubricator • VR plug Lubricator • Small Bleed Tank jr,- Operations rfOperations Summary: 1. Ensure all permits and required approvals are in place. 2. Schedule rolligon transportation, boom truck, and support equipment for late March/early April (or when Rolligon is available). 3. Remove ravens wrap and setup tree covering to retain heat. 4. Position portable heaters to thaw IA and OA valves, as well as the tree cap. 5. RU pressure gauges with bleeds to ensure there is no trapped pressure behind casing valves or between valves on the tree. 6. RU VR plug lubricator to the OA casing valve and pull the VR plug 7. Monitor lubricator pressure gauge for any indications of OA pressure. 8. Perform 30 min no flow test. Record Results. 9. Re -Install OA casing valve VR plug. 10. RU VR plug lubricator to the IA casing valve and pull the VR plug 11. Monitor lubricator pressure gauge for any indications of IA pressure. 12. Perform 30 min no flow test. Record Results. 13. Re -Install IA casing valve VR plug. 14. RU BPV lubricator to the tree cap. Pull BPV. 15. Monitor lubricator pressure gauge for any indications of Tubing pressure. 16. Perform 30 min no flow test. Record Results. 17. Re -Install BPV. ` 18. RDMO. (o �f. ConoCI3 1illIp5 Post Office Box 100360 Anchorage, Alaska 99510-0360 Scout 1 Suspended Well Schematic: i' %9 &a' aalnr'43 Was fr"We pmlecled Wrlh d.+cel to 1044' MDnVD Scout #1 WELL SCHEMATIC Final Suspension Schematic 34/2" FMC Gen V Tubing Hanger with BPV 16" 6264 (r@ 108' MD 3-1/2'9.3# 1-80 8rd-mod Tbg to Surface with 2,91" special drift from surf to DS nipple Q 1007' MD 3-112' Cannco'D5' nipple wl 2 876" No Go Prof (j) 1007' MD Surface cal. 9-5f8" 400 L-80 BTC to 2436' t,4DnVD with c6N circ to surface 3-1/2" x 1" Camco'KBUG' mandrel with dummy at ® 2525' 10.3 ppg kill weight brine with 1600' of diesel freeze protect in ibg and tbg x 7' annulus Top of 7' cmt est at 6661' 3-1f2" x V Cameo 'KBUG' mandrel with dummy @ 7316' 3-112' x 1" Camco'KBUG' mandrel with dummy @ 7406' 7-112" Halliburton XN nipple wl 2.75' no-go @7,454' MD 4-Y," IBT pit x 3-YV 8rd mod box crossover Q 7493' 112' Baker bultat seal assembly w1 15 fl stroke @ 7,51tr MD I op bet csg. 7'26# L-80 BTC ® 7.661' MD No Perforations, 10.3 ppg brine in liner Production Liner 4-112" 12.6# L-80 IBT from 7,481'to 8,050' MD, cml circ to top of finer TO = 8050' MDl8049' TVD Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Scout 1 Field/Pool: Exploration Permit # (PTD): 204-006 API Number: 50-103-20479-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 3/28/2004 Surface Location: 571' FSL. 232' FWL Section: 20 Township: 11N Range: 01E Nearest active pad or road: Meridian: Umiat Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Pad or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Watertfluids on pad: Discoloration, Sheens on Samples taken: N/A Access road condition: N/A Photographs taken (# and description): Three aerial photos of well and surrounding area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition i Wellhead/tree/valve description, condition: Tree & wellhead wrapped in herculite Looked through small incision - dry and clean tree. Rat Hole: Wellhouse or pro Well identificatior Tubing Pressure Annulus pressure Wellhead Photos Work Required: Should install new sign Operator Rep (name and signature): Jan Byrne & Brandon Claudel AOGCC Inspector: Adam Earl Other Observers: N/A Inspection Date: 6/21/2019 AOGCC Notice Date: 6/10/2019 Time of arrival: 10:25 AM Time of Departure: 10:30 AM Site access method: Helicopter ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August l lin, 2019 Inspection Supervisor Alaska Oil and Gas Conservation Commission 333 West lin Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection Deficiency Report for Scout 1 (PTD 204-006) Inspection Supervisor. AUG 1 � ?019 0G; -',.b Enclosed please find the deficiency report documentation for ConocoPhillips Alaska, Inc. well Scout 1 (PTD 204-006). A new identification sign was installed on August 10`n 2019. The following documents are attached: - Deficiency report - Email correspondence - Photograph Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, 2M41'� C04;,�& Sara Carlisle Well Integrity and Compliance Specialist ConocoPhillips Alaska, Inc. State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Scout #1 Date: 7/9/2019 PTD: 2040060 Operator: CPAI Type Inspection: Suspend Operator Rep: Sara Carlisle Inspector: Adam Earl Position: Well Integrity and Compliance Specialist Op.Phone: 907-659-7126 Correct by (date): $/1/2019 Op. Email n2549 conocophillips.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Well sign not legible; must be replaced per 20 AAC 25.040 (observed 6/21/19 during Suspended Well inspection) g/SO/2019 (Requested Extension) Attachments: Photo of replacement sign attached. Signatures: Operator Rep 6f%Ltcm I1b, AOGCC Inspection Supv. 'After signing, a copy of his form is to be left w1l'he operator. / Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 7/2019 Well Integrity Compliance Specialist CPF1 & 2 From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Tuesday, July 30, 2019 3:36 PM To: Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: [EXTERNAL] Suspended Well Inspections - Lookout #1 and Scout #1 Thank you for the call this afternoon advising if the delay. We are ok with coordinating installation of the well signs on Lookout #1 and Scout #1 with the planned suspended well inspections in August. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, July 30, 2019 3:20 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: RE: [EXTERNAL]Suspended Well Inspections - Lookout #1 and Scout #1 Jim, As per our conversation earlier today there was an issue with the sign manufacturer in Anchorage which caused a delay in creating the well identification signs for Lookout #1 and Scout #1. The signs are making their way to Alpine now. CPAI remaining exploration suspended well inspections are scheduled tentatively for August 91h and 10th and CPAI intends to install the well identification signs at that time. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Cawa�hNtlps From: Regg, James B (CED) <iim.regt alaska.gOv> Sent: Wednesday, July 10, 2019 2:57 PM To: Well Integrity Compliance Specialist CPF1 & 2 <n1617(ZDconocophillips com> Cc: Earl, Adam G (CED) <adam.earlPalaska.aov> Subject: [EXTERNAL]Suspended Well Inspections - Lookout #1 and Scout #1 Attached are Deficiency Reports for the well signs at Lookout #1 and Scout #1. Please install proper well signs and return the signed report to AOGCC with the Date Corrected noted on the report — include photos of the new signs. Note the 8/1/19 "Correct by (date)" supersedes what us included in the "Follow-up Instructions" at the bottom of the form. Call if you have any questions. Jim Regg Supervisor, Inspections AOGCC 333 W.7Th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or llm.reARPalaska.eoV. �\\\% 2®� t« z � \�� yc »r . .-. \ .: . z ��\« >t��y«:©�- .%,m<� :� «>a�« `««�� \��\\�� 7W�\:•� � 2\� j .z� \�°«�ƒ<s»�>�/ y«/��®��2. ��\�/\� w:.y »,. \� � ©� \ SccrxPl I Vrb 2r1400(co Regg, James B (CED) From: Regg, James B (CED) ( j Sent: Wednesday, July 10, 2019 2:57 PM �IIG c To: NSK Well Integrity Supv CPF1 and 2 Cc: Earl, Adam G (CED) Subject: Suspended Well Inspections - Lookout #1 and Scout #1 Attachments: Deficiency Lookout -1 well sign 7-9-19.pdf, Deficiency Scout -1 well sign 7-9-19.pdf Attached are Deficiency Reports for the well signs at Lookout #1 and Scout #1. Please install proper well signs and return the signed report to AOGCC with the Date Corrected noted on the report — include photos of the new signs. Note the 8/1/19 "Correct by (date)" supersedes what us included in the "Follow-up Instructions" at the bottom of the form. Call if you have any questions. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or orn.reggRalaska.eov. State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Scout #1 Date: 7/9/2019 PTD: 2040060 Operator: CPAI Type Inspection: Suspend Operator Rep: Jan Byrne Inspector: Adam Earl Position: Op. Phone: 907-659-7224 Correct by (date): 6/1/2019 Op. Email: n1617@conocophillips.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Well sign not legible; must be replaced per 20 AAC 25.040 (observed 6/21/19 during Suspended Well inspection) Attachments: none Operator Rep Signatures: AOGCC Inspection Supv. *After signing, a copy oi1his form is to be left wi the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied byjustification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 7/2019 Suspended Well Inspection Review Report InspectNo: susAGE190623105136 Date Inspected: 6/21/2019 Inspector: Adam Earl Type of Inspection: Subsequent Well Name: SCOUT 1 Date AOGCC Notified: 6/17/2019 ' Permit Number: 2040060 Operator: ConocoPhillips Alaska, Inc. Suspension Approval: Sundry # 304-123 Operator Rep: Jan Byrne Suspension Date: 3/28/2004 Wellbore Diagram Avail? ❑� Location Verified? d❑ Photos Taken? ❑O If Verified, How? LAT / LONG Offshore? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑� OA: VR Plug(s) Installed? O Wellhead Condition Wrapped , dry and clean Condition of Cellar Full wraping was cut to look inside, Clean ice , nothing that I noticed abnormal Surrounding Surface Condition Clean tundra Comments well sign was faded and needs replaced Supervisor Comments Last check of well pressures to confirm internal mechanical integrity was 4/7/2013 �VUwS FS 4Att+d Tuesday, July 9, 2019 Suspended Well Inspection — Scout #1 (PTD 2040060) Photos by AOGCC Inspector A. Earl 6/21/2019 2019-0621_Suspend_Scout-l_photos_ae.docx �1X 11 Rc {j, '1�� •',��1 � ��; � ��)�1, �. sl�. 't7� �:�1'A '� 4-9 NTD I T t'a •'� ,. Well sign i 2019-0621_Suspend _Scout-l_photos_ae.docx • STATE OF ALASKA ALis_. A OIL AND GAS CONSERVATION COMI..._SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown E Performed. Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend Well Inspect r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-006 3.Address: 6.API Number: Stratigraphic r Service I- P. O. Box 100360,Anchorage,Alaska 99510 50-103-20479-00 7.Property Designation(Lease Number): 8.Well Name and Number: AA081857 SCOUT 1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Wildcat Exploration 11.Present Well Condition Summary: Total Depth measured 8050 feet Plugs(measured) None true vertical 8049 feet Junk(measured) None Effective Depth measured 7953 feet Packer(measured) 7496 true vertical 7952 feet (true vertical) 7495 Casing Length Size MD ND Burst Collapse CONDUCTOR 83 16 108 108 1640 630 SURFACE 2411 9.625 2436 2436 5750 3090 PRODUCTION 7636 7 7661 7661 7240 5410 LINER 568 6.75 8050 8049 8430 7500 Perforation depth: Measured depth: None SCANNED AUG 2 7 2015 RECEIVED True Vertical Depth: None JUL 2 9 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7495 MD, 7494 TVD AOGCC Packers&SSSV(type,MD,and ND) SEAL ASSY-BAKER 5"BULLETT PBR SEAL ASSEMBLY @ 7496 MD and 7495 TVD NIPPLE-CAMCO DS NIPPEL w/2.875"NO GO PROFILE @ 1008 MD and 1008 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA _ NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Strati graphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland/Martin Walters Email N1878@cop.com Printed Name MJ J Loveland Title Well Integrity Project Supervisor Signature one:659-7043 Date i77�� I r - RBDMSJ# A..!•, 2 2015 / 5./.7-/ — Ale 674, Form 10-404 Revised 5/2015 Submit Original Only lorrx ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 26, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Scout 1 (PTD 204-006) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. well Scout 1 (PTD 204-006). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well continues to be held for future development of the area. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, ---1177712/-eitAyLe) MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Scout 1 Field/Pool: Exploration Permit#(PTD): 204-006 Sundry 304-123 API Number: 50-103-20479-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 3/28/2004 Surface Location: 571' FSL, 232' FWL Section: 20 Township: 11N Range: 01E Nearest active pad or road: Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Tundra Pad or location surface: Clean tundra Location cleanup needed: none Pits condition: none Surrounding area condition: Clean tundra Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: NA Samples taken: None Access road condition: Helicopter Photographs taken (#and description): Aerial of well and surrounding area Condition of_Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Clean tree, Valves functioned, IA gage was broken and replaced. Cellar description, condition, fluids: Dry cellar made from corregated steel Rat Hole: NA Wellhouse or protective barriers: Bird Barrier and celllar Well identification sign: Wooden Sign Tubing Pressure (or casing if no tubing): Tubing pressure not accessible Annulus pressures: IA= 0 psi, OA= 0 psi • Wellhead Photos taken (#and description): several of tree, bird cover and OA gage and replaced IA gage Work Required: None- replaced IA gage and repaired bird barrier. Operator Rep (name and signature): MJ Loveland, Jim Holley, Matt Miller AOGCC Inspector: Waived (Matt Herrera Other Observers: Dave McKnight Inspection Date: 7/25/20.15 AOGCC Notice Date: 7/16/15 & 7/23/15 Time of arrival: 1010 Time of Departure: 1030 Site access method: Helicopter . • Scout #1 WELL SCHEMATIC Final Suspension Schematic 3-112" FMC Gen V Tubing Hanger with BPV 16" 62.6#@ 108'MD 1'x 9.518'annulus was freeze protected with] ith 3-112"9.3#L-80 8rd mod Tbg to Surface with diesel to 1064'MDl1VD 2,91"special drift from surf to DS nipple @ 1007'MD Ili F 112" Camco'DS'nipple w/2.875"No-Go Prof. @ 1007' MD urface csg. 9-5/8"40#L-80 BTC @ 2436' MD/TVD with cmt circ to surface IP 3-1/2"x 1"Camco'KBUG'mandrel with dummy at @ 2525' ��—___ 10.3 ppg kill weight brine with 1600'of diesel freeze protect in tbg and tbg x 7'annulus Top of T cmt est at 6661' • 3-1/2"x 1"Camco 'KBUG'mandrel with dummy© 7316' 1101 3-1/2"x 1"Camco'KBUG'mandrel with dummy @ 7406' MI 3-1/2" Halliburton XN nipple w/2,75" no-go @7,454'MD \ 4-W IBT pin x 3-W 8rd mod box crossover(fit 7493' 4-1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MD Top-set csg. 7"26#1-80 BTC @ 7,681'MD No Perforations, 10.3 ppg brine in liner Production Liner 4-1/2" 12.6# L-80 IBT from 7,481'to 8,050'MD,cmt circ to top of liner TD= 8050'MD/8049'TVD REV DATE BY CK APP DESCRIPTION REV. DATE _ BY _ LK APP DESCRIP110N _ 1 3/6/04 G.D. C.Z. TB ISSUED PER K03125ACS NOTES: HARRISON BAY 1. BASIS OF COORDINATES: ALPINE MONUMENT MON 19 AND LOUNSBURY AND "►-, ASSOCIATES MONUMENT"03-10-01". 11 A 2. COORDINATES ARE NAD 27, ALASKA STATE 41' Al , l , - PLANE ZONE 4. PROJECT l .3 ' 3. ELEVATIONS ARE REFERENCED TO BRITISH SITE . PETROLEUM MEAN SEA LEVEL DATUM (BPMSL). I ALPINE 4. DISTANCES ARE TRUE. ALL DISTANCES till:Spark4 FACILITY AND ELEVATIONS ARE IN ENGLISH FEET. couti M o LI 5. DATE OF SURVEY 3/05/04 ^""n '' '� ' $ •� Kuukpik/LCMFCarbon 1 A sub�dierpot iAcpeq lkfflupiatCorporatron '1 A. NUIQSUT , Alpine Office {907) 670-4739 Anchorage, Alaska (907) 273-1830 / JJ Alpine Survey Office Vicinity Map / 232' Scout #1 c \\ LOCATED WITHIN PROTRACTED E. \GE(31"?.----5013 o\)\ \\ \ UMIAT MERSECTION IDIANL1ALASKA 1 E 571' FSL 232' FWL SQ) \sI GND ELEV.=100.8' BPMSL c- ICE PAD ELEV.=103.4' BPMSL �U= s \ \ / NAD 27 Datum pp N 70'17'15.000' \ ,- \IC \GE Rei W 151'57'33.012" \o. \ / 3% . -- \ ASPC ZN4 ..f",, , \ \ , (Y) 5,958,608.07 �0 0a SCOUT #1 ( 257$x2.30 \ 2 C�\ �\ R\ i�j��CCSi VS,_ SCALE 1"=200' OF G / /C .....7 o\ � ! 0*: 49TM I" •.* w o'\ _ SOU i 'OB�E i . 1,1-/c)'0° 'j • Brad ley W. Devine z Z ',:. L5-8412 •4 .11 N iii LL, SURVEYOR'S CERTIFICATE SEC. 20, T. 11 N., R. 1 E., U.M. SEC. 29, 11 11 N., R. 1 E, U.M, I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 5, 2004. IIPPV ALPINE MODULE:APO° UNIT: AP ConocoPhillips SCOUT #1 EXPLORATORY WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO; PART:CE—AP00-1009 1 OF 1 REV; 1 0 • U >, V 0 (0 — -o O O as c_c c Q — cn o o Cf) 0- _o QOM _ = ocnca - HCD -0 J 0 OO Q OO O O C c Q = co N O ou) QU � -co2a O I— o Of SCO' - 1 PTD 204-006 ©ConocoPhillips Alaska, Inc t , This photo is copyrighted by ConocoPhillips Alaska, Inc. and 1 1 cannot be released or published without express written consent of ,,.,. .„....1-, ConocoPhillips Alaska s / ' i //lt i jtit A - 1 4000000- i w .....__ ______,,,,,,,,,,, , w... , . .,„,_ „ \ ,.,„ fp.....,, , , wk....0.....rob ....... / ,... , . ..,. _ F 400000.-- s'i:(11,.: , .-, - -t - , 00 4 * , . • (t 114,1)Fl11 .1iid, f>14'14 m 442'..i7 F§t; 4141 FII L. ' ?' 1 '� . t S 4 L S ^�kp I . � • b., it ,w 1. ,,:.s 'tt .,,f, ,. , i 6 4 ilk ,'..'"".'. '-'-',, ''''::,, .,,,„,., -,, ',,c, ,., .,.,, 4‘, . r` w, , ....: ..,._____, \__,, , r il (L) ..' ' ,,Av " 1 'A,:,,-.;:t,' t ` i ll • ,r ! ; O ,, �. O N r fr ri '. _ as F r .0) Q C- L / ' i. . . D °•a{ O -'1","...:, i) ,.: -i 'Q ° •k , b $-" ' Ai, 0• N (13 ID 4--, (n 0 O O co F o co o CO Oo � .� oV; Q CI) 0 1E •c � o O I— o (I) U O c 2 O L 344 tit 1 lab 4 44A ' Kau ri r II 4tw IA ,r,,.,. 4iwtier„..* - iii. 4,44 �•� t4 *00* i O10, sa lif ,, ,1 / 7 / , ., _ t 1 /, / \ -, .A0,64/1010,1110,4021.140440.1,17,‘,14 � � 4 rW.......iiffiltir &IV y kir, , 7 ,,, ,,,.....N.,0 '''' - _ � �% � -� �0$ t;•" ••111i� * i t t1 ,OOPA% tONY/jj1p lli‘i114 Pt* i,, h .:. TIII . i *N ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUN 29 2019 As _ 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing �U L Performed: Suspend I Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Operations shutdown Plug for Redrill 1__I Perforate New Pool ❑ Repair Well ❑ Re-enter Sus WeII P ❑ Other: Change Appro ed rogram ❑ S 2. Operator Production 7636 7„ u5 4. Name: ConoatPhillips Alaska, Inc. Well Class Before Work: 5. Permit to Drill Number: Development ❑ 3. Address: Exploratory r P ry ❑ 204-006 feet Stratigraphic ❑ Service ❑ 6. API Number: 8049 P.O.Box 100360, Anchorage, Alaska 99510 N/A 'simulation or cement squeeze summary: 7. Property Designation (Lease Number): 50-103-20479-00 8. Well Name and Number: AA081857 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): SCOUT 1 10. Field/Pool(sy 11. Present Well Condition Summary: Wildcat/Ex loratO Total Depth measured 8050 feet Plugs true vertical 8049 feet measured None Junk feet measured None feet . ...-��. rvoo feet true vertical 7952 feet sing Length Size None feet Conductor 83 161, TVD Surface 2411 9-5/8" 108 Production 7636 7„ 1640 Liner 568 6-3/4" 2436 foration depth Measured depth None feet True Vertical depth None feet ing (size, grade, measured and true vertical depth) 8049 kers and SSSV (type, measured and true vertical depth) N/A 'simulation or cement squeeze summary: N/A vats treated (measured): N/A tment descriptions including volumes used and final pressure N/A Packer measured None feet true vertical None feet MD TVD Burst 108 108 1640 2436 2436 5750 7661 7661 7240 8050 8049 8430 3.5" L-80 7510 MD Collapse 630 3090 5410 7500 7494 TVD Prior to well oon: N/q "" nni9 nessun: I ubmg Pressure N/A N/A N/A N/A Subsequent to oon: N/A N/A N/A N/A Itachments (requ:f!!r .070, 25.o71, a 25.280 N/A 15. Well Class after work: Report of Well ❑' Exploratory Development❑ Service s of Logs and S ❑ Stratigraphic ❑16. WeII Status aftework: Oil ❑ Gas❑ WDSPL❑d and Electroniclation Data ❑ GSTOR ❑ WINJ ❑ WAG hereby certify that the foregoing is true and correct to the best of my knowledge. ❑Sundry Number or N/A if C. �empt: SPLUG ❑ N/A ized Name: Sara Carlisle Contact Name: Sara Carlisle/Rachel Kautz ized Title: Well Integrity and Compliance Specialist Contact Email: N2549AMnocoohillips com bed Signature: \ %Aa TIMI nCt Date / f� .b' 1 O oL 'I 1 Q Contact Phone: 659-7126 � 18-1y Form 10-404 Revised 4/2017 RBDMSL'C 'jUN 2 8 P019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 22, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue, Suite 100 Anchorage, AK 99501 JUN 2 8 2019 AOGCC Re: Suspended Well Inspection 10-404 Sundry for Scout 1 (PTD 204-006) Commissioner Chmielowski, Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. well Scout I (PTD 204-006). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan Photographs The well continues to be held for future development of the area. Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. R Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Scout 1 Field/Pool: Exploration Permit # (PTD): 204-006 API Number: 50-103-20479-00-00 Operator:ConocOPhllll s Alaska Inc Date Suspended: 3/28/2004 Surface Location: 571' FSL. 232' FWL Section: 20 Township: 11NRange: 01E Nearest active pad or road: Meridian: Umiat Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean tundra rad or location surface: Clean Tundra Location cleanup needed: None Pits condition: None Surrounding area condition: Clean tundra Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: N/A Samples taken: N/A Access road condition: N/A Photographs taken (# and description): Three aerial photos of well and surrounding area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: through small incision - dry and clean trap Rat Hole: N/A Wellhouse or protective barriers Well identification sign: Sic Tubing Pressure (or casing if no Annulus pressures: No Wellhead Photos taken W and d Operator Rep (name and signature): AOGCC Inspector: Adam Earl Inspection Date: 6/21/2019 Time of arrival: Site access method: Tree & wellhead wrapped in herculite Looked Jan Byrne & Brandon Claudel Other Observers: N/A AOGCC Notice Date: 6/10/2019 Time of Departure: 10:30 AM V x J 5+s' annu'us was rree7e protectel With di=set to 1034' W1Dr V0 Scout #'f WELL. SCHEMATIC Final Suspension Schematic 3-1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' MD 3-1/2'9.3# L-80 8rd-mod Tbg to Surface with 2.91" ;penial drift from surf to DS nipple @ 1007' PAD 3-1/2" Can1C0'DS' nipple wl 2.875" No -Go Prot. @ 1007' MU Surface cs9. 9 5/8" 401# L-80 BTC @ 2436' MD71VD with cmt circ to surface 3-112" x 1" Camco 'KBUG' mandrel with durnnly at @ 2525' 10.3 ppg kill weight brine with 1600' of diesel freeze protect in tbg and tbg x 7' annulus Top of 7" cmt est at 6661' 3.1/2" x 1" Camco 'KBUG' mandrel with dummy @ 7316' I.10' x T' Camco 'KBUG' mandrel will, drnnmy @ 740 3 -ill" lialliburton XN nipple'.,// 2.15" no-gc @7,454' MD 4-1;' IBT pin x ;{-yr' 81c1 noxi hox crosso%,er @ 7403' 4-112" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MD Ibp set csg. 7'26# L-80 BTC @ 7,661'MD No Perforations. 10.3 ppg brine in liner Prcduction Liner 4.1/2" 12.641 L-80 IBT from 7,481' to 8,050' PAD, cmt circ to top of Ilner TO = 8050' MD/8049' TVD G.D. I C. Z. I TB I ISSUED PER K03125ACS NOTES: 1. BASIS OF COORDINATES: ALPINE MONUMENT MON 19 AND LOUNSBURY AND ASSOCIATES MONUMENT "03-10-01". 2. COORDINATES ARE NAD 27, ALASKA STATE PLANE ZONE 4. 3. ELEVATIONS ARE REFERENCED TO BRITISH PETROLEUM MEAN SEA LEVEL DATUM (BPMSL). 4. DISTANCES ARE TRUE. ALL DISTANCES AND ELEVATIONS ARE IN ENGLISH FEET. 5. DATE OF SURVEY 3/05/04 Kuukpik/LCMF A-Wiflaryaf Mp_j.WfQyiatCmpa tjoa Alpine Office(907)670-4739 _ n Anchorage, Alaska (907 273-1830 Alpine Survey Office 232' CE P Pi 500 01 \ \ i C \ ZOD SCOUT #1 Q _ lop vo\n' o u W o_ i _ 500 \ / 10'00 OD E z z N 0 0 Ali 0 � N N N SEC. 20, T. 11 N., R. 1 E., U,M, SEC. 29, T. 11 N., R, 1 E, U.M. Conoco -Phillips Alaska, inc. NO. DRAWING N0: _I HARRISON BAY (V 0 L PROJECT SITE / Slpark4F 6 Vicinity Map ALPINE Scout#1 LOCATED WITHIN PROTRACTED SECTION 20, T. 11 N., R. 1 E. UMIAT MERIDIAN, ALASKA 571' FSI. 232' FWL GND ELEV_=100.8' BPMSL ICE PAD ELEV.=103.4' BPMSL / NAD 27 Datum /ROAD N 70'17'15.000" 3 \C� / N 151.57'33.012" ASPICZN4 i (Y) 5,968,808.07 (11) 257,982.30 SCALE 1"=200' � 49 TH //•, •,Bradley W. Devine •••�' LS-9412AO' ,� AAwl w �+� SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AIA PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENT! A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 5, 2004. MODULE:AP00 UNIT: AP SCOUT #1 EXPLORATORY WELL CONDUCTOR ASBUILT LOCATION ' f 1 OF 1 I REV: 1 SCOUT 1 PTD 204-006 ©ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska. t SCOUT 1 PTD 204-006 ©ConocoPhillips Alaska, Inc. -, This -photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska. ---_ : I ` s _. yy•- - 44 j SCOUT 1 PTD 204-006 ConocoPhil'i s Alaska, I - [This 'photo is copyrighted by ConocoPhillips 'This Alaska, Inc. and cannot be released or Alaska, published u ublished without express written consent of Cc of ConocoPh il lips !Alaska. STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMIIIION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other �-, Casing Integrity Alter Casing r Pull Tubing r Stimulate - Frac 1 Waiver r Time Extension r , Test Change Approved Program rOperat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: V 4. Well Class Before Work: / 5. Permit to Drill Number: ✓ ConocoPhillips Alaska, Inc. Development r Exploratory 17 204 -006 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50 103 - 20479 - 00 7. Property Designation (Lease Number): V 8. Well Name and Number: ✓ AKAA81857 Scout 1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none NPRA / Exploration 11. Present Well Condition Summary: Total Depth measured 8050 feet Plugs (measured) none true vertical 8049 feet Junk (measured) none Effective Depth measured 7953 feet Packer (measured) 7498' true vertical 7952 feet (true vertical) 7498' Casing Length Size MD TVD Burst Collapse Conductor 108' 16" 108' 108' Surface 2408' 9.625" 2436' 2436' Intermediate 7633' 7" 7661' 7661' Liner 569' 4.5 8050' 8049' C '. Perforation depth: Measured depth: none SCANNED jut, 10 2.013. ,,,, . True Vertical Depth: none AC ./ 1 1.2 1 . 1 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7510 MD, 7510 TVD Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PACKER @ 7498' MD and 7498' TVD NIPPLE - CAMCO DS NIPPLE @ 1008' MD and 1008' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tom Brassfield @ 265 -6377 Email Tom.J.Brassfield Printed Name Tom rassfield Title Staff Drilling Engineer l / 7 Signature /t Phone: 265-6377 Date / .)–! ! J r --Y ,1 RBDMS MAY - 9 2013 Form 10 -404 Revised , 0/2012 Submit Original Only . NAK • SCOUT 1 COnocOf cam hilhipS " ' Well Attributes Max Angle & MD TD Alaska. Wellbore API /UWI Field Name Well Status !noi (°) MD (ftKB) Act Btm (ftKB) 501032047900 NATIONAL PETROLEUM RESERVE EXPLOR 3.52 7,399.77 8,050.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well come. -sc t, rt4rzot a 6 :2511 AM - SSSV: NIPPLE Last WO: 3/28/2004 Schematic - 4 Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: EXPLORATION WELL (tight hole) osborl 4/23/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.060 25.0 108.0 108.0 65.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd a I SURFACE 9 5/8 8.835 24.9 2,436.0 2,436.0 40.00 L - 80 BTC + Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd RANGER, 25 i PRODUCTION 7 6.276 24.8 7,661.0 7,660.0 26.00 L -80 BTCM • . Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd LINER 41/2 3.958 7,481.9 8,050.0 12.60 L -80 IBT Liner Details Top Depth (TVD) Top Inc! Nonni... Top (ftKB) (ftKB) ( °) item Description Comment ID (in) 7,481.9 7,481.2 3.15 PBR TIEBACK POLISH BORE TIE BACK RECEPTACLE R 5.500 CONDUCTOR, - 7 74097.5 3.73 PACKE ZXP LINER TOP PACKER w/HOLD DOWNS} HRD PROFILE 4.960 zs - toe 7,507. 8 7, 3.66 HANGER FLEX LOCK II HYDRAULIC LINER HANGER 5.510 NIPPLE, 1,006 j 7,517.2 7,516.5 3.59 XO BUSHING CROSSOVER BUSHING 3.930 uS.�r Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, p TUBING 31/2 2.992 24.7 7,510.0 7,509.3 9.30 L - 80 EUE8rdMOD 25 -2,436 Completion Details Top Depth (TVD) Top Inc! Nonni... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 24.7 24.7 - 0.12 HANGER FMC GEN V TUBING HANGER & PUP JT 3.500 GAS LIFT, 2,525 1,007.6 1,007.6 0.31 NIPPLE CAMCO DS NIPPEL w/2.875" NO GO PROFILE 2.875 I 7,454.5 7,453.8 3.16 NIPPLE HES XN NIPPLE w /2.75" PROFILE 2.750 7,495.0 7,494.3 3.75 LOCATOR BAKER 5.76 "LINER TOP LOCATOR 3.950 7,495.7 7,495.0 3.74 SEAL ASSY BAKER 5" BULLETT PBR SEAL ASSEMBLY 3.937 Notes: General & Safety End Date Annotation 3/27/2004 NOTE: WELL SUSPENDED "'NO PERFORATIONS***, Freeze protect annulus w/Diesel I 4/7/2013 NOTE: SET VR PLUGS ON IA & OA, BPV INSTALLED, POST MITT GAS LIFT, x, NINO 7,3[7 ° GAS LIFT, c 7,406 NIPPLE, 7,455 L LOCATOR, 7,495 SEAL ASSY, I t 7,496 t PRODUCTION, 25-7.661 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) ( °) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 2,525.1 2,525.1 0.32 CAMCO KBUG -M 1 GAS LIFT DMY BK -5 0.000 0.0 3/27/2004 2 7,316.9 7,316.5 3.46 CAMCO KBUG -M ' 1 GAS LIFT DMY BK -5 0.000 0.0 3/27/2004 3 7,406.4 7,405.8 3.19 CAMCO KBUG -M 1 GAS LIFT DMY BK -5 0.000 0.0 3/27/2004 LINER, 7,462 - 6,050 . TD, 6,050 • • Scout #1 ConocoPhillips Alaska Inc. MITT report Sundry 313 -010 Permit to Drill 204 -006 Well Status: API 50- 103 - 20479 -00 Scout #1 was drilled /completed in March of 2004. The well was never Property Designation perforated or tested but placed in a suspended status. The 3 -1/2" tubing is AA081857 loaded with 10.3 ppg kill weight brine with a 1500' + /- diesel cap for freeze NPRA Exploration protection. The 3 -1/2" by 7" annulus is loaded with kill weight fluid from top of liner @ 7481' MD to 1500' MD with a diesel cap on top. The 9 -5/8" x 7" annulus is freeze protected to 1064' +/- MD. Bottom hole pressure in the Jurassic is estimated to be a 9.4 ppg Equivalent Mud Weight. The well will be left in a suspended status for a future test. The BLM has requested a wellbore pressure check and a MITT on the IA and tubing. Outline: 1. Pull any VR plugs & BPV (The handover form and FMC records indicate no VR plugs were installed). Verify well pressures on OA/IA/Tbg 2. Notify Anchorage- who will discuss with BLM. 3. Pressure test the IA & tubing to 1500 psi with Diesel. Chart for 30 minutes. 4. Bleed IA & Tubing to zero. 5. Replace BPV 6. Install VR plugs on the IA & OA. 7. Replace cover and secure location. Location • Scout #1 PTD # 204 -006 API # 50- 103 - 20479 -00 SWSW, Sec 20, T11 N, R1 E Lease # AKAA81857 • SWSW, Sec 20, T11 N, R1 E Current Status: Scout #1 was drilled /completed in March of 2004. The well was never perforated or tested but placed in a suspended status. The 3 -1/2" tubing is loaded with 10.3 ppg kill weight brine with a 1500' + /- diesel cap for freeze protection. The 3 -1/2" by 7" annulus is loaded with kill weight fluid from top of liner @ 7481' MD to 1500' MD with a diesel cap on top. The 9 -5/8" x 7" annulus is freeze protected to 1064' +/- MD. Bottom hole pressure in the Jurassic is estimated to be a 9.4 ppg Equivalent Mud Weight. • 4-4 -13 Removed herculite wrap from wellhead. Build scaffolding around wellhead for access to wellhead. Wrapped wellhead and set up heater. • 4 -5 -13 Moved in boom crane, installed lubricator on top of wellhead. Checked pressures on wellhead/ valves. 0 pressure on tubing, 0 pressure on IA and 0 pressure on OA. Pulled BPV. No VR plugs. • • • 4-6 -13 Written notification 9 iven to BLM for witnessing MITT. • 4 -7 -13 MIRU Little Red pump truck. Pressure test the IA to 1620 psi, held and charted for 60 min. Pressure test the tubing to 1620 psi, held and charted for 30 min. Bleed down and RDMO. Charts and pressures witnessed by Justin Miller (BLM). • 4 -8 -13 - Replaced BPV, 0 pressure. Installed VR plugs in OA & IA, pressure on both = O. • Remove scaffolding, replaced cover and secured well. • • I . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: "nm.reon(rta+asygo. v ADGCC.Inspectors alaska.00v pt:oebe chris_wallao alaska.ccv OPERATOR: FIELD /UNIT /PAD: SCrot✓r 1 DATE: j AfLi, L. A,'•i ,, OPERATOR REP; AOOCC REP: � — Packer Depth Pretest initial 15 Min. 30 Min. 45 Min. 60 Min. Wen _SCOUT 1 Type 1n1. W ND I Tubing 0 , 1 VP) h 1t,1S Interval P.T D., - ype test 1 P Test Psil Casing, 0 0 0 0 P/F f Notes: MtT•T 0.5 bb L3 OA 1t0 110 110 IIIo 1 1 well SCOUT 1 I ype Inj» ND I Tubing 0 '0 '100 1 z a o j 31s. 3 is' , I W tervali P.T.D. ; Type test Test .; 1500 Casing s 4. ,,t1I� 1 $Z5 i1 I(. ' U4e P/FI r Notes: y- • IA 1 1 • i S71lt3 OA :1 B LJ l s V Wet + Type In`. ND Tubing rtervai P.T.D. - ype test! Test psi Casing 1 P/F, Notes: OA 1 1 Wed MN ' .eln,. ND Tubin• —_— l..tenrai P.T.D.I - ype test SE1511111EllEttl ME= Pr= Notes: OA Wet ' T • : In` ND 11111111 _111.11111.1111-- Interval PT,D. 111 1 11 111111M11111111111MMIIIMMIIIIIIIIMMEI NMI PIF Notes: OA 1 I TYPE INJ Codes TY TEST Codes INTERVAL Codes D = Drd nq Waste V. _ Annulus Morl:1oririg 1 = InA21 Tcst C. = Gas P = Standard Pressure Test 4 = Four Year Gyps I = Industrial Wastewater R = lntemal Radioactive Tracer Survey V = Required oy Vane N = No: tnrect.ng A =' emperature Anomaly Survey 0 = Otter tiescrioe it rotas) W = We D = DiFerenhal Temperature Test Form 10 -426 (Revised 11 '2012) r1.T Fcrm 11- 01.2o.2>es P . �.. e. .,_..., .- . ...............W,,. , _..._ . -. ....._ WSR Historical - FILE COPY Job: Dismantlement 1 Report Date: 417/20/3 I it t� - - - - _ SCO 1 ilr it: Ai:S LL IN " EGRiTY DHD ! - 3 [doiuser, Roger - CPAI, Field Supervisor ©HD: ` 5 5010320479 'NATIONAL PETROLEUM RESERVE Mkt Typo Original K IRT Elevation (IQ !Well Status. _ - Le _ i Ziiiiinia — E Exploration jEXPLOR ;SCOUT 1 ,.---..__._... Tom- -. _�,__..... X98:= ,, . .... _:% .. . .. !Pr: W e lk aoceAffected , .- S4at,D Erutl"}ale I3&�aaatiary ,DtabTy{ie 4/7!201306:0 0 ./7/2013 17.X10 Mechanical tegrity :.. _ }SCOUT 1 Prinlarry Job yi i rpieet Description —__. ... .., 'Carsria3cnb0.+g - f�Fsa „' .,..- � I4delM4+f�rb�l1D �__ Dismantlement '� Scout 1 PLEA SCOUT 1 1 1 0346732 10346732 _.. . _ u.: R Accept Date rig Release O i tas.-, . :iki N ilaiNo 4/7/2013 06:00 • •.'7x"201311 :00 tilt:a-Type ELL INTEGRITY ;AES D110 r "Tale C” 1i=hoiae1Nork Ptavne _ - Pager Mouser Roger CPAI, Field Sripaivisor DH0 'fold Sup®iviaor DI ID CPAI 659' -7022 ` - 0131 "121 i • - SC0:"x rortasti:iq • nto imotitsr,,zar Doted if fc>b 3s_perfortned during: L►rfiilri Jjieriiticsrtis ::.,,, ` Comment 1 L9A1p.Y'.OP :ERA N3. .._.µ, . �., - . _� ":: >�-::.::s- :::;a�: = � = : . �_ �. - ,; °•`W��s::;:x.;',�• a.: .._ _......... im0 " ' - Tot a l hours Rte) Repoli smart Data Report Erse Date 'Stales at Reporlirra7 �l ' 4/7/201306 :00 4/7/201318:00 - 12.40 rai Recnar3cs Initial TNO2= 0+30+ 11113 Fugal T4/03a 01010100 1:1,r>x fis� ti slap ly ,..e P g hers; "sts P 0r+rtsars if* isctts.- .; • �:'<: . • ; . .:. �� '':; = , :�: " Last 24tH summar MlT -T PASSED TO 1670 Mi. Mr -U P7 SSEIT TO 1675 PSI. -__ data . hs'rs artci atiser -is affect c n ° -` s __...._.. _.__ _ -- • ,i. -_-. - _... ,_ .. yRtrrather • ,;_- ".,... . : . _._. . -. .. _. _:�- :Elk-': te - - .. _ .A; -- " .._ . , . .._ — is _ . -_ __ " . . - .. . - use w : a ' .-.. .. -. •___.» • •�- ,£3'v`•• .. • 'i .« .' ,'_ p r)�St#Yk Wok ...?5�. t Y �... 4 : 4 i r - ... ;TtEEt li •.I S C�!113 L7i$3?78ci AES 353 1?£s36 p5 PI - ; 65i x t !4 _': :: " 993 s:. :, :: :•- f tYtiSa• "' ..] - N,+:�.f TiGil,:y � ' .. x-: ;_ �� - _ _ : ... - - . • n < 105 :u4 09 :00 .4A' 3. ; ikA\i 'I «aC TO SCOUT 1 O I , ".. _._.. „s., ••Passed Os: &4�: �:tx3. �.o�. ::�� " rr;T -. t�"s.� i_ tip;: �li��• �: was��a: i�' 1sr5 psd:: si�l�l1alo9 . ::�trl1o��ArasT4 - SC �,xr;.a:_ .. .3' i - :T /0 1017 9 44. :, " : :: : :, :. :`_--- :.,; -:;r : - Pu�m�d.0;5L�rfs, d t. s7ov m ; T,,= top[es�ure�upta; <1S70,p�i {I_ Ott3f._,. '.,:> - � k•,T i T +�' _ :� 1 ' **Q 1.7 1 _ !"i:9 y��, ��`�` , TfUC7� 4 64 i�+na.: w.Y 625 155 :;.�.: < >.; m T - ti''. - - - - -- :i _ . L+DI V rc s� ,Y. i " 37 . 1 .35� - - _ .. - C?#:375t1332W 1 - 9 .� 8 tv - pl# . - /IIQ =W W.71 15:£501 18 :.. 3.00i 12.00 ilRAV 1 SCOUT 1 TO KOC SCOOT' 1 www.peloton.corn Page 1/1 Report Printed: 4/712€113 • � � \ \ I %%i s THE STATE Alaska Oil and Gas °f1 1L1 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op Anchorage, Alaska 99501 -3572 S P ALA Main: 907.279.1433 F EB 2 � Z013 Fax: 907.276.7542 Chip Alvord N Drilling Manager ConocoPhillips Alasks, Inc. _ �� P.O. Box 100360 Q. Anchorage, AK 99510 Re: Exploratory Field, Exploratory Pool, Scout #1 Sundry Number: 313 -010 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7 Cathy P. oerster Chair DATED this �fj of of January, 2013. Encl. 0 STATE OF • ALASKA OIL AND GAS CONSERVATION COMMISSION D APPLICATION FOR SUNDRY APPROVALS JAN 14 2013 ' 20 AAC 25.280 1. Type of Request: Abandon Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Chprygram El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ nsion ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Exploratory p Development ❑ 204 -006 • 3. Address: Stratigraphic El Service ID 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50- 103 - 20479 -00. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No in Scout #1 9. Property Designation (Lease Number): 10. Field /Pool(s): AA081857 • NPRA Exploration . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8050' • 8049' • 7953' 7952' Casing Length Size MD ND Burst Collapse Structural Conductor 108' 16" 108' 108' Surface 2408' 9.625" 2436' 2436' Intermediate 7633' 7" 7661' 7661' Production Liner 569' 4.5" 8050' 8049' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 3.5" L -80 7510' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Seal Assy © 7510'/No SSSV • Seal Assy @ 7510' MD/7510' ND 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory r • Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 2/1/2013 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned • p Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield @ 265 -6377 Email tom. 1.brassfieldaconocophillips.com Printed Name Chip Alvord Title Drilling Manager Signature X] (L Phone 265-6120 Date ( (Izi IL.(3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\� O Plug Integrity i BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 12 Sa" d " - ^ l Zo - A , l Other: �` -; -(47 .f m.10 `� ill. S AA. c- g4 I � � am, -,�. �-� ; ff �e. i C.9 r 1a. A l>�u -H �E•a ►° Ge_•ri- �, j per Zo ketc- z5 ti 2-6) Spacing Exception Required? Yes ❑ No 11 Subsequent Form Required: /c _407 £1.01 8 if N Y f SVVQBt ,, + RBDMS JAN 2 8 7 < - APPROVED BY Approved by: / ' L-- COMMISSIONER THE COMMISSION Date: / — / 8..... jj Submit Form and Form 10 -403 evised 10/2012) OR 1aGcttitQJs , tr 12 months from the date of approval. ac ;ts in Dplicate ( J • 0 RECEIVED JAN 14 2013 ConocoPhillips AOGCC Box 100360 Alaska 99510 -0360 January 14, 2013 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry approval to P&A: Scout #1 (Exploratory Test) Surface Location: 571' FSL, 232' FWL, Sec 20, T11N -R1E X =257,982.3 & Y= 5,958,608.07 ASP4 NAD27 Target Location: 571' FSL, 232' FWL, Sec 20, T11N -R1E Bottom Hole Location: 571' FSL, 232' FWL, Sec 20, T11N -R1E Dear Commissioners: ConocoPhillips Alaska, Inc. would like to apply for a Sundry to permanently plug and abandon the Scout 1 #1 wellbore, located in the National Petroleum Reserve - Alaska. Scout #1 was drilled and completed in V9' d March, 2004. This P &A is contingent upon the success of the Cassin #1 well this Winter season. In the suc cess case, the Scout #1 wellbore would remain in a suspended status and be tested at a later date. The attached Sundry form 10 -403 and back -up information describes the P &A procedure for the existing wellbore and has been forwarded to BLM personnel for review. If you have any questions or require any further information, please contact me at 265 -6377 or Chip Alvord at 265 -6120. Si cerel , o� ssfie d Staff Drilling Engin cc: CONFIDENTIAL — Scout #1 Well File Chip Alvord ATO -1570 • • Scout #1 P &A Procedures CONFIDENTIAL TJB 01/11/2013 Well Status: Scout #1 was drilled /completed in March of 2004. The well was never perforated or tested but placed in a suspended status. The 3 -1/2" tubing is loaded with 10.3 ppg kill weight brine with a 1500' + /- diesel cap for freeze protection. The 3 -1/2" by 7" annulus is loaded with kill weight fluid from top of liner @ 7481' MD to 1500' MD with a diesel cap on top. The 9 -5/8" x 7" annulus is freeze protected to 1064' +/- MD. Bottom hole pressure in the Jurassic is estimated to be a 9.4 ppg Equivalent Mud Weight.•The well will be plugged and abandoned as outlined below. Outline: 1. Pull any VR plugs & BPV. 2. Pressure test the IA & tubing to 1500 psi. 3. Pull the dummy GLV from the mandrel at 7406' MD and displace tubing & IA diesel well with 10.3 ppg KWF. 4. Circulate approx 700' of cement above the GLM (tbg & annulus) at 7406' MD. 5. Tag TOC & PT cement plug. 6. Bullhead 2000' of AS1 cement into the 9 -5/8" x 7" annulus 7. Pull the dummy GLV from the mandrel at 2525' MD and cement tubing and IA to surface. 8. Excavate wellhead. Cut off 4' below GL and weld on cover plate. Backfill. Procedure: 1. Notify BLM /AOGCC 48 hours in advance of all pressure testing and well suspension operations. Hold pre job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Wrap the wellhead and set -up heater. Pull the BPV. Check and pull any VR plugs from the IA & OA casing heads. Check pressures on the wellhead /valves and advise Anchorage staff of any anomalies. Pressure test the IA & tubing to 1500 psi. 3. RU slickline and pull dummy GLV from the mandrel at 7406' MD. 4. Have Hot Oil truck RU and ready to load the wellbore with 10.3 ppg NaCL /NaBr kill weight fluid. 5. Open the 3 -1/2" x 7" annulus and circulate 40 bbls of 10.3 ppg NaCI /NaBr kill weight brine down the tubing taking returns thru the annulus to tanks displacing the freeze protect diesel from the annulus and confirming circulation. Close the 3- 1/2"x 7" annulus valve. RU on the IA and displace tubing freeze protect diesel until KWF is seen (approx. 53 bbl). SI IA. Place the tubing and annulus into s , communication to allow equalization. Check surface pressures. Maintain a � �a' pressure log i.e. every 5 or 10 bbls while pumping. Confirm that the well is static. C 6. RU cement crew. Mix approx. 25 bbls (2874' of tubing volume) usable cement oS (Class G with additives as per below specs. Open 3 -1/2 "x 7" annulus valve and a(O displace TOC down tubing to approx. 6706' MD with approx. 58 bbls of KWF through open mandrel at 7406' MD. This will place approx. 700' + of cement in the IA and tubing above the GLM @ 7406' MD. 7. SI IA valve. TJB 01/11/2013 • • 3 -1/2" tbg volume = 0.00870 bpf 3 -1/2" x 7" annulus volume = 0.0264 bpf 3 W'Tbg plus tbg X 7 "annulus volume 0.0351 bpf 1C ? 9 -5/8" 40 ppf x 7" annulus volume = 0.02 [bpf 7" 26 ppf csg = 0.0382 bpf Class G + 0.2% BWOC D046 + 1.0 % BWOC D202 + 0.8% BWOC D400 + 8.0% BWOC D154 + 1.5 % BWOC D174 + 0.4% BWOC D198 Wt: 15.8 ppg Yield: 1.16 cuft/sk Working Time: Estimated @ 5 hrs +/- (inclusive of 1 hour surface time) 8. Rig up slickline unit and RIH to tag top of cement plug inside tubing @ 6706' MD approx. to verify placement. Pressure test tubing and IA to 1500 psi..Chart for 30 minutes - record and report results. AOGCC /BLM may want to witness tag of cement and pressure test. .� f$ 4 - 9. RU cementing crew to pump down the 9 -5/8" x 7" annulus. Pump 60 bbls of water to flush annulus and verify injectivity- note rate and pressures. (Annulus freeze protected to approx. 1064' MD with 30 bbls diesel). Downsqueeze 56 bbls of AS1 cement into the annulus. Annular volume @ 2000' x 0.0282 bpf = 56 bbls eV" 10. RU slickline and pull dummy GLV from the mandrel at 2525' MD. Open 3 -1/2 "x 7" annulus to establish circulation down the tubing up the annulus. SI. 11. RU cementing crew. Open 3 -1/2 "x 7" annulus. Circulate AS1 cement (approx. z,Cd4) 89.0 bbls) down the tubing up the casing /tubing annulus to surface. SI and wait ` 056 • ,, *,�V 30 minutes. Confirm the 3 -1 /2 "x 7" annulus stays full- SI. NOTE: Notify AOGCC /BLM Inspectors before setting surface plug(s). 12. Clear lines and shut down pumps. Rig down cementing unit and clean up. 13. Cut off wellhead and all casing strings at 4 +/= feet below original ground level. Verify that cement is back to surface in all strings. Add cement as required. Send casing head with stub to Materials for repair / re- dressing. Photo document. 14. Weld 1/4" thick cover plate (16" in diameter) over all casing strings with the following information bead welded into the top (Drill 1/8" weep hole in cover plate). Photo document. ConocoPhillips Scout #1 PTD # 204 -006 API # 50- 103 - 20479 -00 SWSW, Sec 20, T11 N, R1 E Lease # AKAA81857 iz • _ 11/2013 • 15. Remove cellar. Back fill cellar with gravel /fill as needed. Back fill remaining hole to ground level with gravel /fill. Clear and scrape the ice pad location as needed and demob all materials and equipment. Close out with the appropriate agencies. TJB 01/11/2013 • • • Scout #1 WELL SCHEMATIC Final Suspension Schematic 3 -1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' MD 7" x 9 -5/8" annulus was freeze protected with 3 -1/2" 9.3# L -80 8rd -mod Tbg to Surface with diesel to 1064' MD /TVD 2.91" special drift from surf to DS nipple @ 1007' MD % 3 -1/2" Camco 'DS' nipple w/ 2.875" No -Go Prof. @ 1007' MD Surface csg. 9-5/8" 40# L -80 BTC @ 2436' MD/TVD with cmt circ to surface 3 -1/2" x 1" Camco 'KBUG' mandrel with dummy at @ 2525' 10.3 ppg kill weight brine with 1500' of diesel freeze A- 6c- protect in tbg and tbg x 7' annulus ti Top of 7" cmt est at 6661' 3 -1/2" x 1" Camco 'KBUG' mandrel with dummy © 7316' 3 -1/2" x 1" Camco 'KBUG' mandrel with dummy © 7406' 3 -1/2" Halliburton XN nipple w/ 2.75" no -go @7,454' MD 4 -'/2" IBT pin x 3 -W 8rd mod box crossover © 7493' 4 -1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MD PPF Top -set csg. 7" 26# L -80 BTC @ 7,661' MD No Perforations, 10.3 ppg brine in liner Production Liner 4 -1/2" 12.6# L -80 IBT from 7,481' to 8,050' MD, cmt circ to top of liner TD = 8050' MD/8049' TVD • • ~ t,:. ~.. ~ .. ~- ~ ~--=~ s ~s s-=pz 8..,~ s ~'~ ~ ~ ~~ ; ~ F~"~ ` ~r, ~~ ~ ~ ~~ ~ r~-~ ~~ ~' y~~'~ ~ ~ ~n~~ ~ S~°~.~ ~ ~Y ~ ~ ~- k ~ ~~ ~ ~~ ~~ _ ; ~ ~ ~ ~ ~ ~ b ~ "~" ~ ~ ~ ~ ~ ~` ~= ~ ~~ ~ SEAN PARNELL, GOVERNOR ~.~ ~' ~~ ~~ ~_ ~ ~~ ~ ~. ~ ~ ~ ~~ ~~ ~~~ ~~ ~~~ ~,~ ~ ~-7~ ~IL ~~ lit~-7 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOr1T CODII~iIS5I0i~I ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 > FAX (907) 276-7542 Mr. Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: NPRA Exploration, Scout# 1 Sundry Number: 309-311 Dear Mr. Alvord: ,. _ ~ n (o ~~ ~ . ti t .~"'Y j.~ - ~9IE~}4~~ _ ., , .~ ., " r _ _ €~ l t~ .i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court un_!ess rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Cha.ir / f DATED this ? t day of September, 2009 Encl. • ~ ~ • ~onocoF~illips Box100360 Alaska 99510-0360 September 3, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of suspension status 10-403 Sundry Surface Location: Target Location: Bottom Hole Location: Dear Commissioner: • " '~ ~ ' ~::~` ~ ~ ~4;~,t; ~ ~ s r.',ta.:r _ __ .~ E,_ , ,,.,~.. ~ d~~ ~~ ~ Scout #1(Exploratory Test) 571' FSL, 232' FV1IL, Sec 20, T11N-R1E • X=257,982.3 & Y=5,958,608.07 ASP4 NAD27 571' FSL, 232' FWL, Sec 20, T11N-R1E 571' FSL, 232' FWL, Sec 20, T11N-R1E ConocoPhillips Alaska, Inc. hereby submits a request for renewal of suspension status for the Scout #1 wellbore per 20 AAC 25.110. The well was visually inspected on . 8/19/09 and the results submitted with a 10-404 sundry. Attached is a wellbore schematic noting the condition of the wellbore. Please note the following: • The wellbore is not perforated ' • Kill weight fluid in the tubing and the tubing by 7" annulus to 1500' ~ MD/TVD with diesel from 1500' MD/ND to surface. • Freeze protect diesel in the 7"x9-5/8" annulus. • Cement to surface on the 9-5/8" casing • BPV installed in the tubing hanger. . CPAI requests renewal of the suspension because the well is being held for purposes • of testing to assess reservoir productivity, prior to expiration of the e~ended lease term (August 31, 2019). At this point in time, CPAI plans to test the well prior to ~ June 30, 2012 to fulfill the Initial Development Obligations for the Bear Tooth Unit. • • cc: CONFIDENTIAL - Scout #1 Well File Chip Alvord ATO-1570 Leslie Senden ATO-1390 C~ ~ , .r. ~~, STATE OF ALASKA ~ ~~~~ , :.'. ~~ ~ ` ~ ` ' ," ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~~~ '~` .. -_ `~ ~ ~ `~ ~ 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ~ Perforate ^ Waiver ~ Other ~ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ~ Time E~Rension ~ e~Aension of Change approved program ^ Pull Tubing ~ Perforate New Pool ^ suspension Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^~ ~ 204-006 - 3. Address: Stratigraphic ~ Service ~ 6. API Numbe~: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20479-00 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Spacing Exception Requires? Y2S NO ^d Scout #1 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL AA081857 RKB 28', GL 50' NPRA Exploration , 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8050' • 8049' - 7953' 7952' Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 16" 108' 108' SURFACE 2408' 9.625" 2436' 2436' INTERMEDIATE 7633' 7" 7661' 7661' LI N ER 569' 4. 5" 8050' 8049' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" L-80 7510' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Ope~ations Program ^ BOP Sketch ~ Exploratory Q' Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operati~ Sepkember 10, 2009 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ~ GINJ ~ WINJ ^ WDSPL ~ Commission Representative: suspended ^~ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield (~,? 265-6377 Printed Na hl Alvord Title: Drilling Manager Signat y~ ~ Phone 265-6120 Date Commissian Use Only Sundry Number: Conditions of approval: N ify Commission so that a representative may witness ~_ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Rcc~s'c~~.Y.~.~ O~Svg~nc,~Ot~p,~p~V~. ~~~5 G`QY~OVQ\ VG.~\(.J ~~CV ~1~~~ 1~ ~ Subsequent Form Required: r0 n~ ~~ ~~~ 5~1~~ ~~;~~!„~~,~ ~~~,~ ~rG k~ ~~~~~~ APPROVED BY ~j / / ~ Approved by: OMMISSIONER THE COMMISSION Z ~ Date: ~ l t 1q.9~'t ~~'~-~G, ~' ~~ ~ ~ SCOUt #'I WELL SCHEMATIC 7" x 9-5/8" annulus was freeze protected with diesel to 1064' MD/TVD ~ 3-1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' MD 3-1/2" 9.3# L-80 8rd-mod Tbg to Surface with 2.91" special drift from surf to DS nipple @ 1007' MD 3-1/2" Camco 'DS' nipple w/ 2.875" No-Go Prof. @ 1007' MD Surface csg. 9-5/8" 40# L-80 BTC @ 2436' MD/TVD with cmt circ to surface 3-1/2" x 1" Camco'KBUG' mandrel with dummy at @ 2525' 10.3 ppg kill weight brine with 1500' of diesel freeze protect in tbg and tbg x 7' annulus Top of 7" cmt est at 6661' 3-1/2" x 1" Camco'KBUG' mandrel with dummy @ 7316' 3-1/2" x 1" Camco'KBUG' mandrel with dummy @ 7406' 3-1/2" Halliburton XN nipple w/ 2.75" no-go @7,454' MD 4-'/2' IBT pin x 3-'/2" 8rd mod box crossover @ 7493' 4-1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MD Top-set csg. 7" 26# L-80 BTC @ 7,661' MD No Perforations, 10.3 ppg brine in liner Production Liner 4-1/2" 12.6# L-80 IBT from 7,481' to 8,050' MD, cmt circ to top of liner TD = 8050' MD/8049' TVD Final Suspension Schematic • ~ Ramirez, Darlene V (DOA) ~~~' ~6 From: Foerster, Catherine P (DOA) ~ent: Sunday, September 20, 2009 1:55 PM To: Ramirez, Darlene V (DOA) Subject: Re: 309-311 Approve Sent from my iPhone On Sep 18, 2009, at 10:29 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209091808550.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091808550.pdf > > > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091808550.pdf> ~~t~~~.~~; ~v~`~! ~ ~ ~,~~~ i llUl; tSOayYage :-= ~; • ~~ ~C ~,S.i~(I,_~r~s~aea,c~P~. ~~~e~~s . ~~~~ ~r~ S~sQ~~~~ ra~C i ui r~ ~ ~~-aO~, 3l~_0,~ (a) If allowed under 20 AAC 25,10_5, an operator may apply to the commission under this section to approve the suspension of a well or to renew the approval of the suspension of a well. The operator must state the reasons the well should be suspended, and not completed or abandoned, and must demonstrate to the commission's satisfaction that (1) the well f~~~,~r ~ s.;ia.. ,~ ~;.;,, (A) is mechanically sound; ~ , . ,.. ~ ~ (B) will not allow the migration of fluids; (C) will not damage freshwater or producing or potentially producing formations; (D) will not impair the recovery of oil or gas; (E) is secure, safe, and not a threat to public health; and (F) is in compliance with all provisions of AS_31.05, this chapter, and any order, stipulation, or permit issued by the commission; (2) the well ~(A) has future utility as an exploratory, development, or service well; ~g~~~p~c~rn'F.v Q~~'~~ ~-~ ~5,, ~~. 3~ ~ao ~ "~ (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. (b) An Application for Sundry Approvals (Form 10-403) must be approved by the commission before operations to suspend a well commence, except that oral approval may be requested under 20 AAC 2_5._5__07~b~ . In addition to meeting the requirements of (a) of this section, the application must include the following: ~(1) wellbore diagrams illustrating the current and proposed mechanical configurations of the well; (2) information on abnormally geo-pressured or depleted strata; (3) a description of the proposed work plan, including how the integrity of existing and proposed plugs will be demonstrated. (c) Unless the commission otherwise requires or approves a variance under 20 AAC 25.112(i) , any well suspended under this section must be plugged in accordance with 20 AAC 25._l_12, except that the requirements of 20 AAC 2_ 5,1__12~d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and Lat._./!__.._.._. 1..,~:.. ..~..+.. ..1. ...,/ti.n.,±n/~ ~:.+«..i.v., nnv.7.•r~-~4-Fr~•~~~~ntnv ~nrt~o o4nfn ~~r nc/~•R~_hin/f Qiz~ i~nn4 ~ DOC BodyPage • • rage L ot ~ i (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface. (d) The operator of a suspended well shall maintain the integrity and safety of the well and surrounding location and clear the location in accordance with 20 AAC 25.170~a~ (2) or (b) or with 20 AAC 2_5_.172 ~c~ (2) or (d), as applicable. ~1~~-c~~ (e) For a well suspended before January 1, 2009, the o erator shall ins ect the well site before Septem er , 010. For a well initially suspended on or after January 1, 2009, the operator shall inspect the well site within 12 months after the date of suspension. For a well suspended under this section, subsequent inspections shall be conducted within 24 months before September 30 of every calendar year ending in 0 or 5, except that a suspended well is not required to undergo a subsequent inspection under this subsection if the initial inspection under this subsection occurred within the prior 24-month period. For all inspections under this section, the operator shall provide the commission notice at least 10 days before the inspection and the opportunity for commission inspectors to accompany the operator on the inspection tour. If convenient for the commission, shorter notice periods may be accepted. (~ Within 30 days after any well-site inspection required under this section, including (e), (h), and (i) of this section, the operator shall file a Report of Sundry Well Operations~orm 10-404). The report must include ~~~N;~~ ~1~3 -p~ (1) a description of the condition of the wellhead and surface location, including any discoloration, fluid or sheen visible on the ground or in any nearby water; ~ (2) a plat showing the location of the suspended well and any wells within a one-quarter-mile radius of the wellbore; ~ (3) well pressure readings, if practicable; hp ~SS~~ ~c~C'j\~S ~cs.~ ~ (4) photographs clearly showing the condition of the wellhead and surrounding location; and V' (5) an update of all information and documentation required in (b) of this section. (g) A suspension or renewal of a suspension approved on or after January 1, 2009 is valid for 10 years from the date of approval. (h) Renewal of an existing suspension may be requested by the submission of an Application for Sundry Approvals (Form 10-403) meeting all requirements of (b) of this section. A renewal is not effective until approved by the commission. If a complete renewal application is submitted at least 60 days before the expiration of an existing suspension, the existing suspension will continue until the commission acts on the application. Within 24 months before the submission of a request for suspension renewal, a well-site inspection must be completed. c~ ~J~ a~:~~ cJ ~ N 3"~~ (i) For wells suspended before January l, 2009, an Application for Sundry Approvals (Form 10-403) reauestin~ a suspension renewal under (h) of this section must be submitted (1) no later than December 31, 2010 for all wells suspended before January 1, 2006; and (2) no later than December ~~ ~ni c f..r ,ii .~,An~ ~„~„P„~Pr1 nn ~r after Januarv l. 2006 ,,. .. .. , , .. „ , • .-~- -'--~_~__: L._ir oi~ii~nnn DOC BodyPage rage ~ oi m~ ~ • (j) The operator shall immediately notify the commission and propose appropriate action if the operator learns that there is a reasonable risk that a suspended well is (1) mechanically unsound; (2) allowing the migration of fluids; (3) causing damage to freshwater or producing or potentially producing formations; (4) impairing the recovery of oil or gas; (5) a threat to public health or not secure or safe; or (6) not in compliance with all provisions of AS 31_. _O5, this chapter, and any order, stipulation, or permit issued by the commission. (k) within five working days after notifying the commission under (j) of this section, the operator shall file a report and all relevant information and documentation regarding the well, including all information and documentation that may be required by the commission. (~ If the operator learns that any information required under this section is no longer complete or accurate, the operator shall, within 30 days, notify the commission in writing, provide updated information, and propose appropriate action. (m) At any time, the commission may request that an operator provide, within 10 days after the date of request, any information concerning whether suspension remains appropriate for a well. If the operator does not comply with the information request or if the commission determines that information is insufficient to support allowing the well to remain suspended, the commission may take action under 20 AAC 25.540, including (1) revoking the well's suspended status, effective as of the date determined by the commission, and (2) prescribing actions the operator must take, which may include plugging and abandonment of the well; if action is ordered, including plugging and abandonment under this chapter, a separate notice and hearing is not required notwithstanding any other provision of this chapter, including 20 AAC 25.1_Q5. (n) Upon written request of the operator, the commission may modify a deadline in this section upon a showing of good cause. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am 11/19/2008, Register 188 Authority: AS 3l_OS. _030 AS 31_.05.040 AS 31.05.095 ~~ ~:~ Z~,~ ~~. ~~e~.~ ~I~~gi~r~ e°e~~Erer~e~-~s . • , . , n • ~''-''------ ---`~----i_i_u_.//.__..._. t,.,.7,. ,.a,.+,. ,.L.,,./,.,.; 1.;,,/f' Qi~i i~nno ra~e i ui ~ • Maunder, Thomas E (DOA) From: Brassfield, Tom J [TOM.J.Brassfield@conocophillips.com) Sent: Wednesday, September 16, 2009 7:21 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip Subject: RE: Suspended Well Extensions for CPAI Attachments: 4Spark 1A.jpg ~ Tom, tir,re'v~ ~ttempted to address the~~ issuES in t~e ~03I40~'s submitfed or~ tt~~ six NP~A w~l1s inspect~d this year i.e.: ~~'~f's instalfed VR plugs installed on the annulus valves Tu~ing tail plugs isolating th~ infervals of intEr~st ~ressure i ests $CiR1 ~tir~ight fiuids i~3 ttte tubit3g ~ 9A's Free~~ ~roY~etion at sur~~ce ~~tim«ted cern~nt f~ps Good cement returns on the surface casing jobs ~F~t~i h~,s bEen ti'~ry ~ro active for the l~st ifiree }+e~rs in p~rforrning visu~9 insp~;ctions Qn flur r~rnot~ loca#ions. We hav~ seen no inaication of any "safiety" issues associated with the six ~vells submit2ed. !t is npt very practical to pull the VR plugs to check ~nnulus pressures- see attach~d Spark 1A phota as an example. Regards, Tam From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govJ Sent: Tuesday, September 15, 2009 2:56 PM To: Alvord, Chip; Brassfield, Tom J; Kanady, Randall B Cc: Aubert, Winton G(DOA); Regg, James B(DOA); Colombie, Jody J(DOA); Schwartz, Guy L(DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: Suspended Well Extensions for CPAI Chip, Tom and Randy Sorry yvu all got missed on the original send. Please share with others in the CPAI organization as needed. Tom t~aunder, PE AO~CC From: Schwartz, Guy L (DOA) Sent: Tuesday, September 15, 2009 2:33 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Aubert, Winton G(DOA); Maunder, Thomas E(DOA); Regg, James B(DOA); Colombie, Jody J(DOA) Subject: Suspended Well Extensions for CPAI 9/16/2009 rCt~'G G Vl G ~ • MJ/Perry, 6n regards to "remote pad" suspended well extensions; two is~ues came up ira our engineering revievd of tfie recent weDls submi#ted (Scout 1 and Puviaq 1) and would like addressed in future 403 Sundry applications and the 4fl4 report documentation. 1) At least one annulus pressure should be taken ta verify tfiat the wreil stili has integrity. This may mean bringing a calibrated gauge to the remoie site and instaliing it 4emporariiy to get pressures. Commonly, a{I gauges are taken off a~d flanges bu1!-plugged for safety and environmentat reasons. The regulations currently say #o "get pressures if practical " and that is rather open ended. 2) Remote vdell-sites need to have a written plan for future u6lity to qualify f~r an e~ctension of the suspended status. 20 AAC 25.910 (a) (2) states three possibilities for qualifying for the extension. Written detail for one of these quafifications should be included in the aonlic~tion far sundrv. (Scouf f clearly has a future utility as it wil! be flou~ fested For the suspended welts on "Active pads" the report should be very similar. As above, getting annulus pressures if at all practical is a necessity. A formal written plan for future utility is not ~s critical as it meets one of the listed criteria by default. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 9/16/2009 ,e . ~o~rnnu~J fiom pa~:r I UNITS exploratory work ~ciihin the uni~ areas. It's a ea~d deal all around. said Gree Noble. achng chief of [3L!vl Alaska's enei= cy and minerals branch. "Unrts are supposed ro be beneficial to both parties." he said. "The lecsees eet more time ~o explore their leaces and the go~'emment ge[s a commitment that fur- ther exploration will occuc` While many leases ~vere unitrzed. .onoco i ipc an partners na nr ~o un Pioneer Natural Resources let eo 43 other leases co~~erine about SOOA~O e~~osc aa~es. company spokeswoman Natalie Lowman tolA Petroleum Ne~es on Sept 2. The sun~endered leases didn't ft the company's strareeic plans based on their potential (or developmenc, she said. Whnt's inore. rnany ~a~ere in the very remo~e northwest section of the NPR-A. far to the west of exisun_ producuon inGa- struc[m'e at the Alpine field. "We're reallv focused on Chukchi explornuon rieh~ no~+," Lowman added. ConocoPhillips had more chan S506 mil- lion in winnine bids in a Chukchi Sca off- Shore leace .:ile in Fehiuarv ?f)(1R. Tlie [3L~4's Noble cienzd nvo Auc~. 25 leuers creaung a new Bear Tooth uni~ and expandine the existine Greater Mooses Tooth uniL E3o~h nre in the northeast corner of the NPR-A. wes~ of the Col~~ille Ri~~er and the Inupiat Eskimo rillace of Nwqsw. ConocoPhillips applied for the Bear Tooth unit onAuc. I9. It takes in all m~pan of 23 leases coverine 105.6~5 a~res. all fede~al land. NoMe's letter says natoral gas has been discovered in the unit area. but no oil. It identifies the Cretaceous sandstone as the New Bear Tooth unit 6ear roe:h ~tvuc NGtiA/~G~ RLSCVVt P.Lu L~I~CP.tCY M^DSfS TODtH k~t SIQA lN~-'`~/ I____-. NvRR o~L g Sas u ts Alpine f~cltl. primary inrge~ and the upper .luracsic sund- crone as the secondary tareel. Under the unii aEreement. ConocoPhillips musi drill n~~ ell to the pn- marv tareet in ~~~hat~s de.icntued as Gnit Aiea A. The company t~Lu muct ~es~ Ihe Scout 1 we to the secon nry ~areei m ieu of drillinc a wcll (or Unit Area Ci. The sus- Lended Scoui I mell, ~rhich sVic on the northem boundarv of Ihe Greater Mooses Tooth unn. e~as sDU m arc ~ ,s ~fk'.._ ~ ~ TLe surrrnderctl leascs didn'i (i1 (he compnny'.t su~ategic pla~it bnsed oiv Ihcir poten[ic~l fm~ develoyment, she snid. What:~ more, many i+~erc in Ihc vcry remole norihti~~esi sec(ion a( Ihe NPR-A. (ar ~o ~he wes~ o(existing production infrnsh urture nl Iltr "linits nre supposed !o Uc Ueneficinl to Uodi pnrties. The lessees get mare time tu explore dieir lenses nnd die government gels t+ connnihnent dint (in [her exylorntiou ~vill ocuu " -Greg Nable, aAing ehie! ol BLM Akska's energy and miaerals branch choice u~ithin the eapansion area." Noble's lener says. Failure ~o spud the ~~~ell hy [he dendline will invalida~e the unit expanslon. the let- ~er says. _ ~ NPR-A produdion wming ~ ConocoYhillips has b ~~ active driller i~ che NYR- ~ sized crac~ of Noizh Slop ~~:-_:_ _ Vresident Wai~en G. Hardi ~fhe a,~reemeni ui~~r~ (bnocoFhillips a 192' for its oil and gac pol ~ Most of the exploraeion lune L 2012, dcadhne ~o carry oui the ies. have been confined tc c ri ing and tesiinE. ~7 ~~ r, C~~~ , ~„~_~ northeast corner, closest t Greater Mooses Tooth expanded P'r~er"e`. '°°~` a"~ ~'~°~E the cenmal Norch Slope oil Nohle .d..o eran~ed an eapansion of the 9ill. NPR-A is consid Gre.ver Mooccs Tooth unit. originnlly ~~,here development dictate formed in lanunry 200R. tion be either veiy large ConocoPhillips asked for ~he expao- close to infrastrucWre. sion on July 29, Nnble's approval lener The NPR-A's latect w says. beean in 1999. Since dien. The expansion adds four more leasec ro has sun~endered leases on the unit. inerensing its s2e from 147A56 ~ccasions. The compam e acres to 164.014 acres. All the acreage is es in 2007 und 41 lea federul land, bin 40:?3R ucres or about a Lowman said. quaAer of the unii has been selected for gi~t the compam is ma future subsurfece conveyance to Aretic first produc~ion from the Slope Reeional Coip., the lerter says. ~ z with its CD-5 Alpine In eschunee fm~ the expansion. development. ~chich ic in ConocoPihilhps mus~ spud an esploration phace. The production p ~vell ~y the t iir quaner o_ ~. e a'e roughly midH•ay hetween t v.'i I target t e upper uressic sandstone ~o the east and the Greater and "u~ill be located a~ Ihe Unit Operator's een the most A, an Indiana- e land former ng set as~de in ential. , and discover- ' ~ the reseive s o the exis'~inE ssine plants of fields. ered a frcmtier s an accumula- or reuSOnaMly ave of leasing ConocoNhillips at Icact nao ave up 43 leas- ses last year. rchme irncard NPR-A in la~e West satellite ~he pennittine ad ~rould sii he Alpine field Mooses Toolh umt to the v.est • Conoco bags Bear Tooth Firm heeps some expiiing NPR-A Ieases; one new unit, one expansinn By WESIFY LOY For Prhol~um Nrox aced wiN a Iooming expiretion date on dozens of federal leases. ConocoPhillips worked out a dcal with the Bureau of Land Manngement to form a new cxploration unit called Bear Tooth and expand an existing wit in the National Petrolcum Reservc-Alaska. Rolling an individual lease inln a unit has the effect of extendine its orizinal 10-vear tc~n~ thus allowing ConowPhillips to hang onto acrpge it othc~vise wnu c ave osl a[ en o ugust. In exchnngc or Krannng the company's unit reyuests, the BLM extrscted promises from ConceoPhillips to conduct mo`e drilliog and olher scc UIRIS page 18 $GAY TODt~'~ Wut C0~ - Gr-eater +n ~.. f~y.'i~S.Mr Npt%pwRl FCtvottN7K~ • I'I-"f~~]I~~.~'\II~C'J~~ • WEEKOFSEPTEMBER6,2D09 ~~ t~-~b~ Lines of Business on the Slope • Polyurethane/Polyurea Coatings • Asbestos & Lead Abatement • Oil Spill Response • Construction Management ~--- ~. ~~. ~y o~ B~istol Bay Native ~-°'Y- ~ • fl:li<i.~l.l-li~~IlJI~\'JS ' WEFKOI~AUGUST23,2009 19 ~ cmninurd (mm pege 17 LEASES eral government began leasing land in the pch~oleum reserve more than a decade ago. drilling a tolal of 2U wells, and paiticipab ing in Iwo others. In 2007 ConocoPhillips began dropping leases in NPR-A. culling ~+fiat it descnbed as acreage too fnr from infrastrucmre to be economic to develop m areas where well results u~ere too small to be commercial. Rut ConocoPhillips wntinued to picA up other acreage in NPR-A. Its drilling in 2008 aod 2009 w~as cioser to in(rasnucmre. In 2008. ConocoPhillips and its (re- quent NPR-A partner Anadarko Peholeum, frnmed the firs~ federal unit in NPR-A. Cireater Mooses Tooth. A(tei ConocoPhillips and Anadarko's Alpine West (CD-5) satellite in the CoI~~ille River unit hac been developed Colville and Mooscs Tooth operator ConocoPhillips has snid development of CD-G und CD-7 NPR- A satellires would likely folloev. both of which ure in the MoosesTooth unii. Alpine West production is expected to cnme online at the end of 2012. -KAV CASHMAN ~ ~ ao~a~ a~oa-u~3- ~W ~~ V .~u~ti-ocyc; ~fil=~ „r~[~ VY~i~I6~ e take from two io three months. MMS said. joint bid with that Aind of uncen2i " e leases set to eYpire Aug. 31 w ks ~~ uat 27 compames partici- said dunng a teleconferen ' mediately ~ ee ee ~~ated in Sale 2 ~ d with 53 in lest following $ale 21 ~ your tendency is. mnel~tts ComcoPhil ~ mtlxnattlr ~ ~~ ~ ~ ~ts ruNng ear's Western Gulf of Mexico e '1 can o to the lense sale b oin S Y ~ Y S txM ~le:vrd o(Ihe Na~iaral Petrdeuat Resi.'n'pAlas~a ate set ufort, and ` 207. for example. ~ u robabiy sa.~~ some increa.e in tnayrirern~Au~3L Interior Chris Oynes. MMS' assoaate d~ r the amo~nt o, ompnny) bids. or NCidltt ihc U.S. Burc'.w of 1.aoU MaoagenteW, otx ourt with for offshore energy, indica t"under- even the strength of the bi ... of CUNAAN~IIII{A WID fqtly W lLI~1111C1d UI 8~IfOpO~I HF {:OI-- SS of its curre~t'~ stemmin ~ uncertainry over that undercurreni' jpny subrnitled odia lMs nrx~W to BI.~W on We Cxpitu~ plan "~o . the titi~ ~ i~ely wac a major factor in The 5115.46 milGon in apparent high ]tttl$0. DLM It3S oo[ }R[ COmpleted iti tCSpMSC t01~ pb encrton- ' e. bids submitted in Western Gulf Sale 210 ~ ~~a~~ ~ ~ ~~ ~~-mm~ c ener^ ~y~'~ ~~en~. ~ ei~~ hsn~d to make the agrze- BIM yM~i.a~awi Slomn VFiLsai mW Prtrokum Ne+ws ~ menn b~ ..._, ,,,i.....n~~~~ fnrinidzi~c,~- z irns.r cnit n~ 2n, ~lu~ C1rc~u~Philli~c. ha~ txo optinns tnr a ia~ ?10 `°" :ompany SellfAffi/sRB 17 ting that iave suf- ~ ~i/' ~ .. ~ . ... __-•' '_ _ .~_ a_ i .o.........i ..1.0.. n .... ... ........ __t details ............... .. ~ ~ . ~~ _~J _. C()II[IIILIP(~ ~IY)!11 ~axP ~ ConocoPhillips has been the mosc LEASES active explorer in NPR A since [he federal governmcnt began renewal on each of the 79 leases~. Apply " Jeasing land in tl~e petrolBUnt which under "lease without a discovery. I'eserve mOr'e fhan a decade ago, carries a price tag of 5100 per acre, or ' " drilling a to[al o( 21 wells, and lease with discovery; in apply as a which case the S 100 fee we~ld be participating in two others. uaived. "There are other nominal adminisnntive tees attached in both situ- Hunter A was dnlled in 2p02, some a[ions:' Wilson said. 28 miles southwest of Nuiysut. The expiring leases. purchased in Ihe Pettolwm News was unable to discover (irst NE NPR-A lease sale in 1999, the status of the well. include the Trailblazer wells drilled by Noatak. drilled by ConocoPhillips in 6P (ConocoPhillipc N~as a parnizr and ~~~~ ~n pannership with Pioneer Nahiral later, with Anadarko. acquired the lea,- Resources. was deemed "non-commer- es). and the followinc w~ells. drilled by ~~al'~ in May 2007. in part because of its ConocoPhillips~. C~~~~t distance fi~om existing oilfield infra- • Puvia l o A~ q strucNre in the Colville River unit, ~ A` ~/ • H unter A w~here ConocoPhillips is looking at pro- . r;~,~~~~ ~ ~~ J cessing rts eastem NPR-A discoveries. ~•$cout I SJ~A ~ Scout l. which sits on the boundary The Puviaq well~ drilled by of the Mooses Tooth unit. was drilled in ConocoPhitlipc in the winter of 2003. is 2004. within 10 miles of discoveries ~hat near the IApikpuA River, which is almost ~'ere made in 2000 and 200L The well 80 miles fi~om the e~illage of NuiqsuL The wildcat. in which Anad•arko was a H•as suspendecl and the results werc not released. ~A =~ ~~~ partner. tooA two seasons to drill and Trailblazer A-01 well was plugged lesL w~itli an ice pad put in one year and and abandoned; 1'radblazer H-01 was drilline and testing done Ihe next. suspended.~~A .5~,~„~ Rolligons were used to reach the well SWying eloser to in(rastrucWre sfte versus buildino a~ ~ce roaa. The results of the Pwiaq well have ConocoPhillips has been the inosl not been released. The well is in opere- active explorer in NPR-A since the fed- tional suspension. see LEASES pa~r 19 u • ~ ,, t ~ ~~.ti ~,Y, ~ ~-. ~...~ ~. ,~ ~~ 1 ~~->~ ~ E~. ~ <.~ , w, ~ • • ConocoPhillips Box100360 Alaska 99510-0360 September 3, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Well Inspection 10-404 Sundry Surface Location: Target Location: Bottom Hole Location: Dear Commissioner: ~~-`"pp~ ~~ Scout #1 (Exploratory Test) 571' FSL, 232' FWL, Sec 20, T11N-R1E X=257,982.3 & Y=5,958,608.07 ASP4 NAD27 571' FSL, 232' FV1IL, Sec 20, T11N-R1E 571' FSL, 232' FVVL, Sec 20, T11N-R1E ConocoPhillips Alaska, Inc. hereby submits a status update for the field inspection of the Scout #1 location performed on 8/19/09 as required by 20 AAC 25.110. Please find attached the following documents: • Remote Well inspection Checklist - this inspection was a visual inspection and no pressure readings were taken. • The "as-built" plat • Photographs • A wellbore diagram • The 10-404 Sundry The request for renewal of suspension status will be filed with a 10-403 Sundry. ~' Tom Brassfield Senior Drilling E ineer • cc: CONFIDENTIAL - Scout #1 Well File Chip Alvord ATO-1570 Leslie Senden ATO-1390 • ~, - ~ ~ ~ ~°..-lFc~~~' _. '' ~ ~ ~ t ~ ~a~ ~ f`t ..~ ~ ~~ ~ ~ , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ "~ ' ' ~ ~ ~' ~ ~~` ~ ~ `' ~ ~~~~ ~~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ StlmUlat2 ~ Othef ~ remote site inspection Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Ina nefc:~o~~nc.nt ^ ExpEoratory ^~ 204006/ ~ 3. Address: Stratigraphic ^ Service ^ 6. API Numbef: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20479-00 w~ 7. KB Elevation (ft): 9. We!] Name and Number: RKB 28', GL 50' SCOUt #1 ~ 8. Property Designation: 10. FieldlPool{s}: ADL AA081857 NPRA Exploration 11. Present Well Condition Summary: Total Depth measured 8050' feet true vertical 8049' feet Piugs (measured; Effective Depth measured 7953' feet Junk (measured) true vertical 7952` feet Casing Length Size MD ND Burst Cotlapse Structural CONDUCTOR 108' 16'" 108' 108' SURFACE 24Q8` 9.625" 2436' 2436' INTERMEDIATE 7~~3' 7" 7661' 7661' LINER ~~a~' 4,5" 8050' 8049' Pertoration depth: Measured depth: none true vertical depth: none Tubing (size, grade, and measured depth) 3,5'~ , L-80 , 7514' Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 Development ^ Service ^ Daily Report of Well Operations _ 16. Well Status after work: sr~s~~n~3e~ ^~ CQ Ga~ WAG~ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tom Brassfield ~ 265-6377 Printed N me Chip Alvord Title Drilling Manager j Signatu Phone: 265-6120 Date y'/~ /~ 9 Pre ared b Sharo~Allsu -Drake 263-0612 ~ Form 10-404 Revise 04l2006 ~~~af ~~~~ ~~P ~,~, ?QO~ ~(.'~ Submit } ri ' al Onrly=,`" N/~iY~ .~ ~~ r~, ~ ~-~ ~ _ __ __• __ _.__ .__ Remote Well Inspection Checklist Well Name ~ Suspended '~` Abandoned ~ Coordinates: ~Q ~ i2$ ~ r '~ ~~~ ~~o ~ Date: Yes No N/A 1. Area surrounding Wellhead • Impounded Water ^ ~. ^ • Sheen present on ground water 0 ~ ~ 2. Cellar Area • Fluid in cellar ^ ~ ^ • Sheen present ^ ^ ~,' • Fluid level in cellar is..higher ~ lower ~ the same as 0 the level of the ground water outside the cellar. •~ /~1 h Q ~ j / /z ~„i ~~~ ~~~~ f a~. 3. Wellhead and tree • Presently leaking ^ ~ ^ • Evidence of prior leaks ~ ~ ~ 4. Bird Cover • Complete and secure ~ ^ ~ • Evidence of fluids on inside of cover ^ ~ ^ Description of Tr~ee and Wellhead: ~( i e. valve handles. Gages, r~eee~ile valves,~nurnber of Descrintion of Findin¢s: . Printed Name: ~ ~~ ~~yL~ttyt Signature Original to : Sharon Allsup-Drake ATO 1533 ~ ~ REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 3/23/04 CZ BD TB ISSUED PER K03125ACS N otes ~ . HARRISON BAY 1. BASIS OF COORDINATES: ALPINE MONUMENT MON 19 AND LOUNSBURY AND a e ASSOCIATES MONUMENT "03-10-01". 2. COORDINATES ARE NAD27, ALASKA STATE PLANE ZONE 4. PRO.~E T ~ 3. ELEVATIONS ARE REFERENCED TO BRITISH SITE PETROLEUM MEAN SEA LEVEL DATUM (BPMSL). ALPINE 4. DISTANCES ARE TRUE. ALL DISTANCES Spark4 FACILITY AND ELEVATIONS ARE IN ENGLISH FEET. ~ t ~ ~ ° ~ 5 DATE OF SURVEY 3/12/04 ° . ~ K u u k p i k/ LC M F I Carbon 1 < NUIQSUT A sabsidiaryofUkpeagvik~upiatCorporation ~ Alpine Office (907) 670-4739 Anchorage, Alaska (907) 273-1830 ~ Al i S Offi ~ urvey p ne ce Vicinity Map ~ `~ ~`~ ,~ ,~ Scout #1 m• m LOCATED WITHIN PROTRACTED - ' N SECTION 20, T. 11 N., R. 1 E. C~ C~ UMIAT MERIDIAN, ALASKA ~-~ ~-~ ICE PAD NAD 27 Datum -' -' LI M I TS -' ~ N70°17~15.000" W151°57'33.012" z Z / ASPC ZN4 / ~~ (Y) 5,958,608.07 / ° \ (X) 257,982.30 ~ ~ N 571'FSL 232'F1NL ~ o o~~~ 60 \ GND ELEV=100.8' BPMSL E ' o o_\ ICE PAD LEV=103.9 BPMSL \ / 200 ~ON /OA ~cESSi \ ~ ~ 5' ~cj o R~~ 1 ~Mi ~ ~ ~ a ee -N P% °R~P ~p, ~0~ R~G `~P~~ ~ ~ SCALE 1"=200' O ~ U` \ MP / ~ ~p. O. ~ / , ~v ~~O \ /, Z S 0 / ' Q E 0 O \ /N~ p 0~ Diesel Storage Tank #141 ~ AP1653 In-Service 1/04 (1) Rectangular pouble Walled 21,000 Gallon Diesel Tank SEC. 20, T.11 N., R.1 E, U.M. SEC. 29, T.11 N., R.1 E, U.M. ALPINE MODULE:AP00 UNIT: AP ConocoPhilli s SCOUT #1 RIG CAMP p AS-BUILT LOCATION Alaska, Inc. ALPINE, ALASKA CADD FILE N0. 03-12-08-1 Ri Cam DRAWING N0: CE-AP00- 1002 PART: ~ oF ~ REV: ~ ., ~ • ~ Scout #1 WELL SCHEMATIC Final Suspension Schematic 3-1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' M D 7" x 9-5/8" annulus was freeze protected with diesel to 1064' MD/TVD 3-1/2" 9.3# L-80 8rd-mod Tbg to Surface with 2.91" special drift from surf to DS nipple @ 1007' MD 3-1/2" Camco'DS' nipple w/ 2.875" No-Go Prof. @ 1007' MD Surface csg. 9-5/8" 40# L-80 BTC @ 2436' MD/ND with cmt circ to surface 3-1/2" x 1" Camco'KBUG' mandrel with dummy at @ 2525' 10.3 ppg kill weight brine with 1500' of diesel freeze protect in tbg and tbg x 7' annulus Top of 7" cmt est at 6661' 3-1/2" x 1" Camco'KBUG' mandrel with dummy @ 7316' 3-1/2" x 1" Camco'KBUG' mandrel with dummy @ 7406' 3-1/2" Halliburton XN nipple w/ 2.75" no-go @7,454' MD 4-'/z' IBT pin x 3-'/2' 8rd mod box crossover @ 7493' 4-1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MD Top-set csg. 7" 26# L-80 BTC @ 7,661' MD Perforations, 10.3 ppg brine in liner Production Liner 4-1/2" 12.6# L-80 IBT ~m 7,481' to 8,050' MD, cmt circ to top of liner TD = 8050' MD/8049' ND t~.. ., 4out=1 ~ ~ c• ~.~~i.~aFlullips Alasl•a. hic Tlus phato ic ~v pprigLt L+y Con.w.~I'lullips Al~sk.~. Inc aud c:wnot L+z released or ~~~Flished H•itLout tl~e raprrKS couaeut nf i ouucoFlullips Al~sl:a. Inc +"" ~ p^ ° ~x ~~ ~ ' s ~ "~ ~, ~^ r ~r e a~~ i^ ~`:~ .r~:: . . ~, , .... . . . .~. ~a .. ~ _. . . , ~ , /•i ~ ~ scnuT-~ ~~~ :_ ::~~ ~~«i~s~~,~~K~ ~ API 5tl i(l:i 1U419 ~Q a7'IFSL 2~Z f~l.~~~~ct ~ ~~...~ ~.~ 1l1~t A1~ u~i f~`D 1~4-~~J~' . ~~ ~ ,. ~ ~, ~ ,~~~; , ~, - ~ _, ~ - ~ . ~e .~~~ , , ~ ~~ ~ ~ _ _~ _ .~. ~. _ ,~~.,~E, ~ ~ ~C~ilt ~ 1 ~ ~ ~~rLacaPhilli~s ~.l ask a, Ir~~c. : ~~ ~:This phafia is ~~~~right b~ ~arlacaFhillips A1 ~k a, Iryc. ~:: ~ a~nd c a~ntlat be rele z~~ d ar ~ubli~~ ~ v~rith,~ut t~,e ~x~r~ss gs ~~c~r~~r~t af C~n,a~aFhilli~~ ~1 ~sk ~ IrLC . ~ ~' ~~. ~ ~ ~. . ,.;. ~~ ~~~~~~~~ - - ~ ~~ ~ Scout ~~1 ~ T : ~ 4 vy 1 ~ • - -~._ e:~=;~. _ -• ~ 03/01/2008 DO NOT P LAC E • ,~. . ,. _'•. ~. .,: , ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_InsertslMicrofilm_Marker. doc J.ð flp..../ ^~ \) y DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2040060 MD 8050 / UIC N Well Name/No. SCOUT 1 (' Completion Status TVD 8049 / Completion Date 3/28/2004 Operator CONOCOPHILLlPS ALASKA INC SUSP /' Current Status SUSP Sp~ ~~~ 'i API No. 50-103-20479-00-00 REQUIRED INFORMATION Mud Log Yes Directional Survey ~ 1~ ~.~--~--_._"--"~~-~------ Samples No ~----- DATA INFORMATION Types Electric or Other Logs Run: GR, Res, Neut, Dens, Dipole Sonic, CMR, MDT, VSP Well Log Information: Log/ Data Type ~;t Log I Log ED Rpt Electr Digital Dataset Med/Frmt Number Name C Asc 12497 (Directional Survey Directional Survey Induction/Resistivity Induction/Resistivity 12497... Induction/Resistivity C Lis I í ED C Pds Log ED C Pds Log I I ED C Pds Log Pds Rpt Sample 127!59-V0nic 12759~ Sonic 1276Vormation Tester 1276J"Formation Tester 12761 "Magnetic Resonance 12761 /Magnetic Resonance Report: Final Well R Log Log Scale Media (data taken from Logs Portion of Master Well Data Maint Run No Interval OH 1 Start Stop CH Received 5/24/2004 0 0 5/24/2004 100 8000 Open 5124/2004 2436 8000 Open 5/24/2004 2431 7980 Open 5/24/2004 0 0 8/3/2004 6500 8020 8/30/2004 6500 8020 8/30/2004 7686 7710 8130/2004 7686 7710 8/30/2004 7668 7840 8/30/2004 7668 7840 8/30/2004 0 0 11123/2004 ~ rv~ Blu Blu Blu Blu Blu Well CoreslSamples Information: Name Cuttings Interval Start Stop 108 8050 Sent Sample Set Received Number Comments 3/30/2004 1139 ,./ Core chips . Comments ROP/DGRlEWR DGR/CTN/SLD LDWG LWD CoreLabs Core Analysis Report w/CD DIPOLE SONIC IMAGER, LOWER DIPOLEI P & S DIPOLE SONIC IMAGER, LOWER DIPOLEI P & S MOLDULAR FORMATION, DYNAMICS TESTER MOLDULAR FORMATION, I DYNAMICS TESTER COMBINABLE MAGNETIC RESONANCE IMAGER COMBINABLE MAGNETIC RESONANCE IMAGER Epoch End of Well Report w/CD -:tI. f J . -~ Permit to Drill 2040060 MD 8050 TVD 8049 ADDITIONAL INFORMATION Well Cored? ~ / N Chips Received? ~, N Analysis ~ 1 N Received? DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Well NamelNo. SCOUT 1 Operator CONOCOPHILLIPS ALASKA INC Completion Date 3/28/2004 Completion Status SUSP Current Status SUSP Daily History Received? 6)/N ~ìN Formation Tops API No. 50-103-20479-00-00 UIC N -.------ -~-~--'" Comments: Compliance Reviewed By: ------- . \ ,; , ~ Date: ;(<1 ~ ~~~ . . . y Cono·coPhillips . c20 c¡- OO~ FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Howard Okland State of Alaska-AOGCC 333 W. ih Ave, Suite 100 Anchorage, Alaska ~ I: ;0 º Qo » m ~~ c::: GJ (") ~ð' (I m cc::! n - œ~ N < c::.:> «::=¡o m .t:::>- I~ CJ TRANSMITTAL CONFIDENTIAL DA TA RE: Scout 1 Permit: 204-006 DATE: 8/25/2004 Transmitted: Scout 1, NPRA, Alaska 501032047900 CDROM diQital well data _ Schlumberger LDWG Formatted Open hole edit, DSI and CMR data, and PDS files 6500-8020'md; 3/24/2004; Job 10687770 _ Schlumberger Processed DSI DLlS, and PDS files data 6500-8020'md; 3/24/2004; Job 10687770 _ Schlumberger Field MDT DLlS, Field notes and PDS files; 7710-7686 'md; 3/24/2004; Job 10687770 LOQ prints (1 each) _ Schlumberger Dipole Shear Imager Lower Dipole P&S 3/24/2004 _ Schlumberger Combinable Magnetic Resonance Imager 3/24/2004 _ Schlumberger Modular Formation Dynamics Tester 3/24/2004 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date "On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached data for the Scout 1 Well, Drilling Permit No.204-006 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(roand 2. 0 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality perim. ~fliflla J. ,c. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future." r\ t:. V 1::1 V CPAI LEGAL 2/4/2004 AUG 3 02004 Date: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 Sandra.D. Lemke@ConocoPhillips.com · e ConocJ'Phillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Howard Okland State of Alaska-AOGCC 333 W. ih Ave, Suite 100 Anchorage, Alaska RE: Scout 1 Permit: 204-006 DATE: 5/21/2004 Transmitted: Scout 1, NPRA, Alaska 501032047900 Diaital data _-Sperry Sun LDWG LWD log data; Image views and Directional Survey 3/23/2004 ~() !>Ul/)s.:I/... I.À l( q 7 Report Binder ~fralliburton Sperry Sun- Directional survey report - hardcopy A.' &) fW')~ Hardcopv Loa data - 1 print each ---Î...ROPIDGR/EWR, 2"&5" MD ~IIOO'\) ~GR/CTN/SLD/ 2"&5" MD j2¡~P""') Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records, To all data recipients: All data is confidential until State of Alaska designated AOGCC release date Data marked proprietary is indefinitely confidential and is available only to owners and partners "On behalf of itself and other owners, ConocoPhillips Alaska, Inc, submits the attached data for the Scout 1 Well, Drilling Permit No.204-006 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future." CPAI LEGAL 2/4/2004 CC: Greg Wilson, CPAI Geologist -W DtL; RECEIVED MAY 242004 Receipt: Date: Alaska Oil & Gas Cons. Commission Anchorage Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 Sand ra. D. Lemke@Conocophillips.com Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 ),~ ~l - ab~ e e Paul Mazzolini Exploration DrillingTeam Leader Drilling & Wells Conoc;Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 April 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Scout #1 (204-006) Dear Commissioner: On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recently suspended exploration well Scout #1, Drilling Permit No. 204-006 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, ~Lr1~~ P. Mazzolini Exploration Team Leader CPAI Drilling RECEIVED APR 22 2004 Alaska Oil & Gas Cons. Commission Anchorage PM/skad ORIGINAL tit STATE OF ALASKA _ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas D Plugged D Abandoned D Suspended 0 WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development D Exploratory 0 GINJ D WINJ D WDSPL D No. of Completions Other - Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ./ ConocoPhillips Alaska, Inc. or Aband.: March 28, 2004 204-006 / 304-123 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 / 50-103-20479-00 March 8, 2004 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: ¡ Scout #1 Surface: 571' FSL, 232' FWL, Sec. 20, T11 N, R01 E, UM March 23, 2004 At Top Productive 8. KB Elevation (It): 15. FieldlPool(s): Horizon: 601' FSL, 251' FWL, Sec. 20, T11 N, R01 E, UM RKB 28' above GL /1 03.4' AMSL Total Depth: 9. Plug Back Depth (MD + TVD): NPRA Exploration 611' FSL, 267' FWL, Sec. 20, T11 N, R01 E, UM 7953' MD /7952' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 257982 / 5958608/ ( 8050' MD / 8049' TVD ( AA081857 y- Zone-4 TPI: x- 258002 y- 5958638 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 258019 / y- 5958647' Zone-4 no SSSV ALK 5202 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 800' MD 21. Logs Run: GRlRes/NeutlDens, Dipole Sonic, CMR, MDT, VSP 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 108' 24" 45 bbls AS I 9.625" 40# L-80 Surface 2436' 12.25" 222 sx AS III Lite, 163 sx LiteCrete 7" 26# L-80 Surface 7661' 8.5" 187 sx Class G 4.5" 12.6# L-80 7481' 8050' 6.125" 99 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7510' none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NIA 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) nla none Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). RECEIVED Submit core chips; if none, state "none". ~~-¿R!f~d ~'~ APR 2 2 2004 ! V~'·"'d D.'\Tf. L.z..8: 0 í TO BE SENT UNDER SEPARATE COVER Alaska Oil & Gas Cons. Commission ~. ¡ 1.0 ~<~ 1 Anchorage --'.A C)L~ WI Form 10-407 Revised 2/2003 CONTINUED ON REV RSE SI RI!ØIs:sf21 Submit in duplicate ') J. ,/ ORIG1NÃ~ All a 3 i'" \,~ Y 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None". Scout 1 K-3 SEQ 97 SEQ 95 SEQ 93 SEQ 92 UJU/Alpine Sands 2635' 3150' 3496' 3652' 4610' 7658' 2635' 3150' 3496' 3652' 4610' 7657' NIA RECEIVED APR 2 2 2004 Alaska Oil & Gas Cons, Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Dirèctional Survey, Sqhérnatii::, As-Built 31. I hereby certify that the foregoing is true and correct to the:best of my knowledge. Contact: Tim Billingsley @ 265-6531 Printed Na~ P. Mazzolini. ~ Signature ~ r1~ Title: Phone Drillino Team Leader Date 04-1 Z7-/2.004- Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Altemating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORrGfNA'L e e svy619 Survey Ref: Halliburton Sperry-Sun North Slope Alaska ConocoPhillips Exp Scout # 1 - Scout #1 Job No. AKMW2899231, Surveyed: 23 March, 2004 Survey Report 22 April, 2004 Your Ref: API 501032047900 Surface Coordinates: 5958608.07 N, 257982.30 E (70017' 14.9995" N, 151057' 33.0126" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 131.40ft above Mean Sea Level "\I-SUn tiIFAVIC&S A Halliburton Co.mpany Halliburton Sperry-Sun Survey Report for Scout # 1 - Scout #1 Your Ref: API 501032047900 Job No. AKMW2899231, Surveyed: 23 March, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/10Oft) 0.00 0.000 0.000 -131.40 0.00 0,00 N O.OOE 5958608.07 N 257982.30 E 0.00 MWD Magnetic 195,24 0.000 0.000 63.84 195,24 O.OON O.OOE 5958608.07 N 257982.30 E 0.000 0.00 280.43 0,060 311.030 149,03 280.43 0.03 N 0.03W 5958608.10 N 257982.27 E 0.070 0.03 376.18 0.200 21 .350 244.78 376,18 0.22 N 0.01 W 5958608.29 N 257982.30 E 0.197 0.22 e 465.79 0.250 321 .080 334.39 465.79 0.52N 0.08W 5958608.59 N 257982.24 E 0.257 0,52 557.08 0.250 319.670 425.68 557,08 0.82N 0.33W 5958608.90 N 257982.00 E 0.007 0.82 649.50 0.310 15.310 518.10 649.50 1.22 N 0.40 W 5958609.30 N 257981.94 E 0.289 1.22 741.67 0.170 12.850 610.27 741.67 1.59 N 0.30W 5958609.67 N 257982.05 E 0.152 1.59 831.16 0.280 323.060 699.76 831.16 1.90 N 0.40W 5958609.98 N 257981.96 E 0.239 1.90 922.55 0.280 323.870 791 .14 922.54 2.25 N 0.67W 5958610.34 N 257981.71 E 0.004 2.25 1015.74 0.310 358.610 884.33 1015.73 2.69N 0.81 W 5958610.78 N 257981.58 E 0.191 2.69 1108.46 0.140 350.600 977.05 1108.45 3.05N 0.83W 5958611.15 N 257981.57 E 0.186 3.05 1200.63 0.250 306.410 1069,22 1200.62 3.28N 1.01 W 5958611.38 N 257981.39 E 0.194 3.28 1294.13 0.280 354.840 1162.72 1294.12 3.63N 1.20W 5958611.74 N 257981.22 E 0.234 3.63 1385.43 0.310 299.970 1254.02 1385.42 3.98 N 1.43W 5958612.09 N 257981,00 E 0.299 3.98 1479.10 0,310 333.180 1347.69 1479.09 4.33N 1.76W 5958612.45 N 257980.68 E 0.189 4.33 1572.31 0,310 331.070 1440.90 1572.30 4.78N 2.00W 5958612.91 N 257980.45 E 0,012 4.78 1665.03 0,310 330.960 1533.62 1665.02 5.21 N 2.24W 5958613.35 N 257980.23 E 0,001 5.21 1757.36 0.170 324.470 1625.95 1757.35 5.54N 2.44 W 5958613.69 N 257980.04 E 0.154 5.54 1850.22 0.060 333,430 1718.81 1850.21 5.70 N 2.55W 5958613.85 N 257979,94 E 0.120 5.70 1942.41 0.250 267.490 1811.00 1942.40 5.73 N 2.77W 5958613.89 N 257979.72 E 0.252 5.73 e 2036.47 0.280 287,000 1905.05 2036.45 5.79N 3.19W 5958613.96 N 257979,29 E 0.101 5.79 2129.27 0.250 275.800 1997.85 2129.25 5.88 N 3.61 W 5958614.06 N 257978.88 E 0.064 5.88 2221.98 0.360 324.450 2090.56 2221.96 6.14 N 3.98W 5958614.33 N 257978.52 E 0.292 6.14 2314.50 0,310 334.240 2183.08 2314.48 6.60N 4.26W 5958614.80 N 257978.25 E 0.082 6.60 2373.43 0,250 311.540 2242,01 2373.41 6.83N 4.43 W 5958615.04 N 257978.10 E 0.212 6.83 2536.60 0.330 308.880 2405.18 2536.58 7.36N 5,06W 5958615.59 N 257977.48 E 0,050 7.36 2630.05 0.700 323.690 2498.62 2630.02 7.99N 5.60W 5958616.23 N 257976.96 E 0.418 7.99 2721.98 0.630 305.910 2590.55 2721.95 8.74 N 6.35W 5958617.01 N 257976.24 E 0.236 8.74 2816.20 0.560 331.720 2684.76 2816.16 9.45 N 6.98W 5958617.74 N 257975.62 E 0.291 9.45 22 April, 2004 - 8:02 Page2of5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Scout # 1 - Scout #1 Your Ref: API 501032047900 Job No. AKMW2899231, Surveyed: 23 March, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2909.02 0.440 311.240 2777.58 2908.98 10.08 N 7.47W 5958618.39 N 257975.16 E 0.230 10.08 3002.10 0.380 315.160 2870.66 3002.06 10.53 N 7.95W 5958618.85 N 257974.69 E 0.071 10.53 3095.43 0.450 308.080 2963.98 3095.38 10.98 N 8.46W 5958619.32 N 257974.20 E 0.093 10.98 3188.65 0.530 333.380 3057.20 3188.60 11 .59 N 8.94W 5958619.94 N 257973.74 E 0.245 11.59 e 3282.46 0.500 343.090 3151.01 3282.41 12.37 N 9,26W 5958620.73 N 257973.45 E 0.098 12.37 3375.51 0,660 0.180 3244.05 3375,45 13.30 N 9.37W 5958621.66 N 257973.36 E 0.251 13.30 3468,33 0.670 358.530 3336.87 3468.27 14.37 N 9.38W 5958622.74 N 257973.38 E 0.023 14.37 3563,03 0.250 123.630 3431.56 3562,96 14.81 N 9.23W 5958623.17 N 257973.56 E 0.886 14.81 3656.29 0.250 165.090 3524.82 3656.22 14.50 N 9.00W 5958622.85 N 257973.77 E 0.190 14.50 3749.93 0.220 182.070 3618.46 3749.86 14.12 N 8.96W 5958622.48 N 257973.80 E 0.081 14.12 3843.42 0.220 206.480 3711.95 3843.35 13.78 N 9.04W 5958622.14 N 257973.70 E 0.099 13.78 3936.55 0.380 162.960 3805.08 3936.48 13.33 N 9.03W 5958621.68 N 257973.70 E 0.287 13.33 4030.01 0.470 156.680 3898.54 4029.94 12.68 N 8.79 W 5958621.03 N 257973.92 E 0.108 12.68 4121.97 0.370 146.550 3990.50 4121,90 12.09 N 8.48 W 5958620.42 N 257974,21 E 0.135 12.09 4215.62 0.310 229.300 4084.14 4215.54 11.67 N 8.50W 5958620.01 N 257974.18 E 0.482 11.67 4309.13 0.310 230.650 4177.65 4309.05 11 .34 N 8.89W 5958619.69 N 257973.78 E 0.008 11,34 4402.24 0.500 242.390 4270.76 4402.16 11 .00 N 9.45 W 5958619.36 N 257973.21 E 0.222 11,00 4495.70 0.450 236.660 4364.22 4495.62 10.61 N 10.11W 5958619.00 N 257972.53 E 0.074 10.61 4589.28 0.830 241.340 4457.79 4589.19 10.08 N 11 .02 W 5958618.50 N 257971.61 E 0.410 10.08 4683.22 0.390 161.130 4551,73 4683.13 9.45 N 11.51 W 5958617.89 N 257971.10 E 0.910 9.45 4776.41 0.760 134.470 4644.91 4776.31 8.72 N 10.97W 5958617.13 N 257971 .62 E 0.480 8.72 e 4870.27 0.510 138.240 4738.77 4870.17 7.97 N 10.24 W 5958616.36 N 257972.32 E 0.270 7.97 4963.93 0.330 155.110 4832.42 4963.82 7.41 N 9.85W 5958615.80 N 257972.69 E 0.231 7.41 5055.95 0.090 145.830 4924.44 5055.84 7.11 N 9.70W 5958615.49 N 257972.83 E 0.263 7.11 5149.79 0.120 154.150 5018,28 5149.68 6.96 N 9.62W 5958615.34 N 257972.91 E 0.036 6.96 5243.34 0.250 170.780 5111.83 5243.23 6.67 N 9.54W 5958615.05 N 257972.98 E 0.149 6.67 5336.91 0.200 192.810 5205.40 5336.80 6.31 N 9.54W 5958614.69 N 257972.96 E 0.106 6.31 5430.33 0.140 266.230 5298,82 5430.22 6.15 N 9.69W 5958614.53 N 257972.81 E 0.224 6.15 5523.48 0.250 203.630 5391.97 5523.37 5.95 N 9.89W 5958614.34 N 257972.61 E 0.240 5.95 5616.69 0.260 238.810 5485.18 5616.58 5.66 N 10.15W 5958614.05 N 257972.34 E 0.166 5,66 22 April, 2004 - 8:02 Page30f5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Scout # 1 - Scout #1 Your Ref: API 501032047900 Job No. AKMW2899231, Surveyed: 23 March, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (01100ft) 5711.03 0.310 253.820 5579.52 5710.92 5.48 N 10.58 W 5958613.88 N 257971.90 E 0.095 5.48 5804.92 0.310 261.590 5673.41 5804.81 5.37 N 11.07 W 5958613.79 N 257971.40 E 0.045 5.37 5898.21 0.350 218.390 5766.70 5898.10 5.11 N 11.50 W 5958613.54 N 257970.97 E 0.263 5.11 5991.29 0.060 184.610 5859.78 5991.18 4,84N 11 .68 W 5958613.28 N 257970.78 E 0.324 4.84 e 6084.61 0.190 81.780 5953.10 6084.50 4.81 N 11.53W 5958613.25 N 257970.93 E 0.227 4.81 6177.44 0.090 170.590 6045.93 6177.33 4.76 N 11 .37 W 5958613.19 N 257971.09 E 0.225 4.76 6271.07 0.120 23.590 6139.56 6270.96 4.78N 11 .32 W 5958613.21 N 257971.14 E 0.215 4.78 6364.14 0.280 46.140 6232.62 6364.02 5.02 N 11.11 W 5958613.45 N 257971 .35 E 0.188 5.02 6457.43 0.380 12.390 6325.91 6457.31 5.48N 10.88 W 5958613.90 N 257971 .60 E 0.230 5.48 6551.45 0.740 19.650 6419.93 6551 .33 6.36N 10.61 W 5958614.77 N 257971 .90 E 0.390 6.36 6644.52 0.740 33.390 6512.99 6644.39 7.43 N 10.08 W 5958615,82 N 257972.46 E 0.190 7.43 6831.09 1.020 43.160 6699.54 6830.94 9,64N 8.28W 5958617.98 N 257974.33 E 0.170 9.64 6924.02 1.050 50.780 6792.45 6923.85 10.79 N 7.06W 5958619.08 N 257975.60 E 0.151 10.79 7017.73 1.190 57,240 6886.15 7017.55 11 .86 N 5.57W 5958620.10 N 257977.11 E 0.201 11.86 7071.49 1.220 54.350 6939.89 7071 .29 12.49 N 4.64W 5958620.70 N 257978,07 E 0.126 12.49 7118.74 1.470 51.070 6987.13 7118.53 13.17 N 3.76W 5958621.35 N 257978.97 E 0,553 13.17 7213,22 2.770 50.440 7081.54 7212.94 15.38 N 1.05W 5958623.48 N 257981.74 E 1,376 15.38 7306.63 3.450 50,350 7174.82 7306.22 18.61 N 2.85 E 5958626.58 N 257985.75 E 0.728 18.61 7399.77 3,520 52.930 7267.78 7399,18 22.12 N 7.29E 5958629.95 N 257990.30 E 0.184 22.12 7494.42 3.140 54.880 7362.27 7493.67 25.37 N 11.73 E 5958633.05 N 257994.84 E 0.419 25.37 7588.41 3.090 56.590 7456.13 7587.53 28.24 N 15.95 E 5958635.78 N 257999.15 E 0.112 28.24 e 7626.74 2.820 58.180 7494.40 7625.80 29.31 N 17.61 E 5958636.80 N 258000.85 E 0.736 29.31 7696.17 2.980 58.780 7563.75 7695.15 31.14N 20.61 E 5958638.54 N 258003.90 E 0.235 31.14 7790.09 3,070 56.660 7657.53 7788.93 33.79 N 24.80 E 5958641.05 N 258008.17 E 0.153 33.79 7884.00 2.800 56.830 7751.32 7882.72 36.43 N 28.82 E 5958643.55 N 258012.27 E 0.288 36.43 7975.86 2.540 63.150 7843.08 7974.48 38.58 N 32.51 E 5958645.58 N 258016.03 E 0.427 38.58 . 8050,00 2.540 63.150 7917.15 8048.55 40.06 N 35.44 E 5958646.97 N 258019.01 E 0.000 40.06 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB=128.8' above MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8050.00ft., 22 April, 2004 - 8:02 Page 4 of5 DrillQuest 3.03.06.002 North Slope Alaska Halliburton Sperry-Sun Survey Report for Scout # 1 - Scout #1 Your Ref: API 501032047900 Job No. AKMW2899231, Surveyed: 23 March, 2004 The Bottom Hole Displacement is 53.49ft., in the Direction of 41.499° (True). The Along Hole Displacement is 91,91ft. The Total Accumulated Dogleg is 18.117° The Measured Tortuosity is 0.267°/1 OOft. The Directional Difficulty Index is 2.8. Comments Measured Depth (ft) Station Coordinates rvD Northin9s Eastin9s (ft) (ft) (ft) Comment 8050.00 8048.55 40.06 N 35.44 E Projected Survey Survey tool ørOQram for Scout # 1 - Scout #1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 8050.00 8048.55 MWD Magnetic Relative Depth Error: True Inclination Error: Drillstring Magnetisation: 2.00 Misalignment Error: 0.20 Compass Ref. Error: 0.75 Drift Error: ConocoPhillips Exp e 0.15 1.50 0.00 e 22 April, 2004 - 8:02 DrillQuest 3.03.06.002 Page50f5 ¡_...,LED PER K03125ACS NOTES: 1. BASIS OF COORDINATES: ALPINE MONUMENT MON 19 AND LOUNSBURY AND ASSOCIATES MONUMENT "03-10-01". 2. COORDINATES ARE NAD 27, ALASKA STATE PLANE ZONE 4. 3. ELEVATIONS ARE REFERENCED TO BRITISH PETROLEUM MEAN SEA LEVEL DATUM (BPMSL). 4. DISTANCES ARE TRUE. ALL DISTANCES AND ELEVATIONS ARE IN ENGLISH FEET. 5. DATE OF SURVEY 3/05/04 KUUkPik/LCMF@ A 11I11II""" ø/1lipN1'lk IIIlIpIatCGlpCINtlø.ø \ , Alpine Office (907) 670-47J9 Anchorage, Alaska (907) 2.73-1830 Alpine Survey Offloe 232' ...-'\ ...- - -'\ \ --- (" \ û~;;. ~} l\\ \ j~~~ //~:~ ~ \ ( - \~. \ ~ \~~ SCOUT #1 \ ° ?,.oQ ~ \- , \ 0~""'''''' ö\~\ ~\G~ø . °3 \ \...---- ~ .~ => :; LS'\ \ ...- :-:::> 0 ___ --: ILl L.J' 0_ \ ...- SOD - ___ ....--; 0"£ (]I ~ ~ ~ ___ N10'OO 0 :::l o 0 ..- .... ~ ¡-: mO ... N ú c.:i W Lú VI II) SEc. 20, T. 11 N" R. t E.. U.tJ. SEC, 2.9, T. 11 N., R. t E, U.M. Conoc6PhiUips Alaska. Inc. CADD FILE NO, DRA\\1NG NO; HARRISON BAY Vicinity Map .....- ...- ~o~ -6 ø:.___ .....-~ ---...- .....- ç \~_ SCALE 1"=200' ~ Scout #1 LOCATED WITHIN PROTRACTED SECTION 20, T. 11 N_. R. 1 E. UWAT MERIDIAN, ALASKA 671' FSL 232' FWL ,/ GND ELEV.=100.6' BPMSL ICE PAD ELEV.=103.4' BPYSL NAD 27 Datum N 70-17'15.000" W 151·57'S3.D12" ASPC ZN4 (Y) 6.968,606.07./ (X) 257, a82.S0 / ~~~~ ~ OFA ~~....*".~~~'¡ It}. " .-.Iý 1\ 1*:-49 TH ".* f····················· . ~,. It..,..,.... It.. ... It.." 'I ". Bradley W. Devine.' it 'fl.t.::. LS-8+12 .·.,1 'ti~~:··i~.V '\~~1SfIK~ ~ ''-'-'''-'-'''--- SURVEYOR'S CERTIFICATE ALPINE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN TtiE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURV£Y DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 5, 2004. MODULE: APOO UNIT: AP SCOUT #1 EXPLORATORY WELL CONDUCTOR ASBUIL T LOCATION PART: CE -APOO-1 009 REV; 1 1 DF 1 e e Scout #1 API #50-103-20479-00 Permit #204-006 Daily Drilling Summary 3/1-4/04 Prepare Doyon rig 141 for move from Meltwater 2P pad to Scout #1 location. Phase 2 weather delayed rig move. 3/5/04 Move Doyon 141 camp to Scout location. 3/6/04 Move Doyon Rig 141 to Scout location. 3/7/04 Accept Doyon Rig 141 on Scout #1 location at 07:00 hrs. NU and function test diverter with AOGCC witness. Drilled out cement from 16' conductor. 3/8/04 Spud Scout #1 at 13:30 on 3/8/04. Drill 12-1/4" hole from surface to 700'. 3/9/04 Drill 12-1/4" hole from 700' to 2100' . 3/10/04 Drill 12-1/4" hole to surfacécasing point at 2444'. Short trip to 965', Rlli to 2444', could not circulate, hole' packed off. Pumped out of hole at minimum rate with no returns, LD MWD. RIH with washing from 320' to 920', re- establish full returns and circulate out large amounts of golf ball sized cuttings. Wash and ream from 920' to 2160' with large amount of cuttings to surface. 3/11/04 Circ three sweeps with diminishing amount of cuttings to surface. POOH with no problem. Ran 9-5/8" L-80, 40#, BTC casing to 2437' with no problem. Reciprocate with full returns while pumping 175 bbl of 10.7 ppg Arctic Set Lite lead slurry and 72 bbls of 12.0 ppg LiteCrete tail slurry. Displace with mud and bump plug, 50 bbls of 10.7 ppg cement to surface. ND diverter. 3/12/04 NU BOPE, test same with BLM witness. PU 4" drill pipe, MU 8-112" BHA. 3/13/04 Pressure test 9-5/8" casing to 2500 psi, drill out cement and float equipment, drill 20' of new formation to 2464'. Perform FIT to 14.6 ppg EMW, no leak- off. Drill 8-1/2" hole from 2464' to 3536'. 3/14/04 Pull wiper trip from 3536' to casing shoe at 2437'. RIH with no problems. Drill from 3536' to 4563'. Pull wiper trip to shoe with some packing off. 3/15/04 Drill from 4563' to 5779', wiper trip to 4380'. 3/16/04 Trip back to bottom at 5779' with no problems. Drill from 5779' to 7110'. e e 3/17/04 Drill from 711 0' to 7140', trip for BHA change (remove motor and place GR tool close to bit to pick casing/core point): Drill from 7140' to 7434'. 3/18/04 Drill from 7434' to 7661', short wiper trip to 6784', POOH. Run 7" 26#, L-80 BTC casing to 3800' , poor returns. Pull out of hole with casing. 3/19/04 Pull out of open hole with casing to above 9-5/8" shoe at 2396'. Regain full circulation. Wash and stage casing back in open hole. 3/20/04 Stage in hole with 7" casing to 7661' TD with no losses. Cement 7" casing with 38.7 bbl of 15.8 ppg cement, displace with 11.3 ppg mud, bump plug. Full returns and reciprocation during cement job. ND BOPs. 3/21/04 Set slips, NU and test BOPs. RIH with 6-1/8" cleanout assy. Test casing to 3500 psi. Drill out cement track and l' of formation to 7662'. POOH with 6- 1/8" bit. 3/22/04 Performed injectivity test on 7" x 9-5/8" annulus at 444 psi or 14.8 ppg EMW with 11.3 ppg mud in annulus down to 2436' TVD. RIH 6-1/8" core bit and 4- 3/4" x 2-5/8" core barreL Change over to 9.8 ppg coring fluid. Core from 7662' to 7752', POOH andrecover 90' of core. 3/23/04 RIH with 6-1/8" drilling BHA. Drill from 7752' to 8050' TD. POOH. Run' Schlumberger Dipole Sonic log on E-line. 3/24/04 Run CMR log on E-line. Run MDT log via drill pipe conveyed. 3/25/04 Run VSP log on E-line. RD Schlumberger. RIH with 6-1/8" clean out assy to 8050'. POOH. 3/26/04 Run 4-1/2" 12.6#, L-80 liner to 8050'. Pump 21.1 bbls of 15.8 ppg cement, Y displace with 10.3 ppg brine followed by mud (good returns throughout job, reciporacted liner during job. Bump plug, set hanger and liner top packer. Reverse circulate out 3 bbls of cement from on top of liner. Change over well to 10.3 ppg brine. POOH with drill pipe and liner running tool. 3/27/04 Run 3-1/2" 9.3# L-80, EUE 8rd mod tubing completion, land tubing seals in '" liner top seal bore. Test tbg to 3500 psi, test tbg x 7" annulus to 3500 psi. Bleed tbg pressure and shear out RP valve at 2525' with 3000 psi annulus pressure. ND BOPE, NU and test tree to 5000 psi, freeze protect tbg x 7" annulus with 55 bbls diesel, U-tube diesel into tbg. 3/28/04 RU slickline, run gauge ring to 7451', pull shear valve at 2525' and replace with dummy valve. Set BPV and release rig at 08:00 3/28/04. Begin moving rig to ) 1E-119. Scout~ WELL SCHEMATIC e 3-1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' MO 3-1/2" 9.3# L-80 8rd-mod Tbg to Surface with 2.91" special drift from surf to OS nipple @ 1007' MO 3-1/2" Cameo 'DS' nipple w/ 2.875" No-Go Prof. @ 1007' MO Surface csg. 9-5/8" 40# L-80 BTC @ 2436' MOrrVO with cmt circ to surface 3-1/2" X 1" Cameo 'KBUG' mandrel with dummy at @ 2525' 10.3 ppg kill weight brine Top of 7" cmt est at 6661' 3-1/2" x 1" Cameo 'KBUG' mandrel with dummy @ 7316' 3-1/2" X 1" Cameo 'KBUG' mandrel with dummy @ 7406' 3-1/2" Halliburton XN nipple w/2.75" no-go @7,454' MO 4-%" IBT pin x 3-%" 8rd mod box crossover @ 7493' 4-1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MO Top-set csg. 7" 26# L-80 BTC @ 7,661' MO No Perforations, 10.3 ppg brine in liner Production Liner 4-1/2" 12.6# L-80 IBT from 7,481' to 8,050' MO, cmt circ to top of liner TO = 8050' MO/8049' TVO TAB 4/12/04 e e Paul Mazzolini Exploration DrillingTeam Leader Drilling & Wells ~ . Conoc~hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 April 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval on Scout #1 (204-006) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the operations to suspend the exploration well Scout #1. ConocoPhillips Alaska, Inc. requests permission to leave Scout #1 suspended to allow for the possibility of testing the well in the future. Scout #1 has not been perforated and the 4-1/2" liner, 3-1/2" tubing and the 7" annulus have all passed pressur~Jª-ª~ to 3500 gsi. There is currently a -ª-~\l in the tree and kill weight fluid in the tubing and the tubing x 7" annulus. - - -- . If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, ?~fV/wL- P. Mazzolini Exploration Team Leader CP AI Drilling PM/skad RECEIVED APR 142004 Alaska Oil & Gas Cons. Commission Anchorage OR'G1NAL e e ,Í'-I{f'l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Suspend 0 Repair well D Pull Tubing D 1, Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99501 7. KB Elevation (ft): 28' RKB & GL 50' 8. Property Designation: ALK 52021 ADL AA081857 11. Total Depth MD (ft): 8050' Casing Structural Conductor Surface Total Depth TVD (ft): Effective Depth MD (ft): 8049' 8050' Length Size 108' 2408' 7633' Intermediate Production Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: 569' Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D Perforate D Stimulate D Exploratory 0 Service D Variance D Annular Dispos.D Time Extension D Other D Re-enter Suspended Well 5. Permit to Drill Number: ./ 204-006 6. API Number: V 50-103-20479-00 9. Well Name and Number: Scout #1 10. Field/Pools(s): NPRA EXDloration PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 8049' MD rvD Burst 108' 2436' 7661' 8049' Perforation Depth TVD (ft): N/A Packers and SSSV MD (ft): Tubing Size: 3.5" 16" 108' 9.625" 2436' 7" 7661' 4.5" 8050' none 12, Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 4/14/2004 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name P. Mazzolini Signature ~ .. 11 VYI rt---r¿ "/DX7' /). . 13. Well Class after proposed work: Exploratory 0 Development D 15. Well Status after proposed work: Oil D GasD WAG D GINJ D Title Drilling Team Leader Phone 263-4603 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug IntegrityD BOP Test D Mechanical Integrity Test D Other: Contact Location Clearance ~ ~;.\"o\..., t.~~~C~'\) '''. ." ~ '\"""\'V\.\t. Y 'dCO ~ ~:::2ìj~ a ~ ~~~,~ ~::~:R \,./" v '--'" Form 1 0-403 Revised 2/2003 ORIGINAL Collapse Tubing Grade: L-80 Tubing MD (ft): 7510' none Service D Plugged D WINJ D Abandoned D WDSPL D Tim Billincslev @ 265-6531 Date 04114-/~oo4 Sundry Number: 3c</./c73 RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons. Commission BY ORDER OF Anchorage # /1 /~ / THE COMMISSION Date: Ifj¡¿/ ~ APR í 9 f2004 RBDMS BfL SUBMIT IN DUPLICATE escout #1 e · WELL SCHEMATIC As of 4/11/04 and Proposed Suspension 3-1/2" FMC Gen V Tubing Hanger with BPV 16" 62.6# @ 108' MO 3-1/2" 9.3# L-80 8rd-mod Tbg to Surface with 2.91" special drift from surf to OS nipple @ 1007' MO 3-1/2" Cameo 'DS' nipple w/2.875" No-Go Prof. @ 1007' MO Surface csg. 9-5/8" 40# L-80 BTC @ 2436' MOfTVO with cmt circ to surface 3-1/2" X 1" Cameo 'KBUG' mandrel with dummy at @ 2525' 10.3 ppg kill weight brine with 1500' of diesel freeze protect in tbg and tbg x 7' annulus Top of 7" cmt est at 6661' 3-1/2" x 1" Cameo 'KBUG' mandrel with dummy @ 7316' 3-1/2" X 1" Cameo 'KBUG' mandrel with dummy @ 7406' 3-1/2" Halliburton XN nipple w/2.75" no-go @7,454' MO 4-V2" IBT pin x 3-%" 8rd mod box crossover @ 7493' 4-1/2" Baker bullet seal assembly w/ 15 Ft. stroke @ 7,510' MO Top-set csg. 7" 26# L-80 BTC @ 7,661' MO No Perforations, 10.3 ppg brine in liner Production Liner 4-1/2" 12.6# L-80 IBT from 7,481' to 8,050' MO, cmt circ to top of liner TO = 8050' MO/8049' TVO TAB 4/11/04 . ~ ConocoPhillips Alaska, Inc. . Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 TO: AOGCC 333 WEST 7TH ANCHORAGE, AK. 99510 DATE: APRIL 13, 2004 AIRBILL: Airland 5271836 AFT#: CPBV04-04-13-34 CHARGE CODE: N.AK.EXPL. OPERATOR: ConocoPhillips Alaska, Inc. SAMPLE TYPE: DRY CUTTINGS NUMBER OF BOXES: 25 NAME: SCOUT #1 PLACER #1 SAMPLES SENT: PLACER #2 ONE COMPLETE SET OF DRY CUTTING FROM PLACER #1. PLACER #2 AND SCOUT #1 AS RECEIVED FROM THE RIG. ~~C1-~l'1 PLACER #1 100'-7761' :¡:!-/(37 #- 1138 fF-f( 3q ~a'-{-{:)J) PLACER #2 J.ð"'-O~(" SCOUT #1 0'-9118.7' 450'-8050' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: RECEIVED BY, )LJ ð JJj ConocoPhillips Alaska Inc. BAYVIEW GEOLOGIC FACILITY 619 E. Ship Creek Ave. ANCHORAGE, AK. 99510-0360 ATTN: D. L. przywojski ABV-100 DATE: J") ~~ J.JK-'f Cc: A. ANDREOU CPAI G. WILSON CPAI f.'~ 2b tV ~b~ 1 e e . Scout #1 API #50-103-20479-00 pennit #204-006 Weekly Drilling Operations Report 3/1-3/7/04 Wait on weather to move Doyon Rig 141 from Meltwater to Scout #1 location. Move camp and rig to Scout location on 3/5 to 3/6/04. NU and function test diverter, witnessed by Chuck Scheve with AOGCC. Drill out cement in 16" conductor. MU 12-1/4" drilling BHA, mix and circulate spud mud. 3/8-14/04 Spud Scout #1 at 13:30 on 3/8/04. Drill 12-114" hole from surface to surface casing point at 2444'. Short trip to 965', RIH to 2444', could not circulate, hole packed off. Pumped out of hole at minimum rate with no returns, LD MWD. RIH, washing from 320' to 920', re-establish full returns and circulate out large amounts cuttings. Wash and ream from 920' to 2444' with large amount of cuttings to surface. Circ three sweeps with diminishing amount of cuttings to surface. POOH with no problem. Ran 9- 5/8" L-80, 40#, BTC casing to 2437' with no problem. Reciprocate with full returns while pumping 175 bbl of 10.7 ppg Arctic Set Lite lead slurry and 72 bbls of 12.0 ppg LiteCrete tail slurry. Displace with mud and bump plug, 50 bbls of 10.7 ppg cement to surface. ND diverter. NU BOPE, test same. NU BOPE, test same with BLM witness. RllI with 8-1/2" BHA. Pressure test 9-5/8" casing to 2500 psi, drill out cement and 20' of new formation to 2464'. Perform FIT to 14.6 ppg EMW, no leakoff. Drill 8- 1/2" hole from 2464' to 3536'. Pull wiper trip from 3536' to casing shoe at 2437'. RIH with no problems. Drill from 3536' to 4563'. Pull wiper trip to shoe with some packing off. 3/15-21/04 Drill from 4563' to 5779', wiper trip to 4380' with no problems. Drill from 5779' to 7140', trip for BHA change. Drill from 7140' to 7661', wiper trip to 6784'- POOH to run 7" casing. Ran 7" to 3800' - unable to circulate. Pump out to 9-5/8" casing shoe, regain circulation; and ran 7" to TD at 7661'. Cemented 7" per well plan with good circulation- floats held & reciprocated pipe during job. Set 7" slips, RU & test BOPE's-OK. Cleaned out shoe track plus one foot of new hole. POOH to pick-up core bbl. Current status: Coring. 3/21-29/04 Cored 90' of hole, had full recovery. PU 6-1/8" BHA and drilled to TD @ 8050' MD. RU SWS and ran dipole sonic, CMR, VSP on e-line; and MDT on drill pipe. Made clean-out run and ran/cemented 4-1/2" liner. Good circulation throughout the job. Ran 3-1/2" completion, ND BOPE & NU FMC tree- tested OK. Freeze protected the 7"x3-1/2" annulus to 1500'. 26(/ -óC> (. L e e , Made GR run to PBTD of 7451'. Set BPV, secured well, and released rig at 0800 hrs 3/28/04. Current Status: Doyon 141 moving back to Kuparuk field. . . Scout # 1 API #50-103-20479-00 Pennit #204-006 Weekly Drilling Operations Report 3/1-3/7/04 Wait on weather to move Doyon Rig 141 from Meltwater to Scout #1 location. Move camp and rig to Scout location on 3/5 to 3/6/04. NU and function test diverter, witnessed by Chuck Scheve with AOGCC. Drill out cement in 16" conductor. MU 12-114" drilling BHA, mix and circulate spud mud. 3/8-14/04 Spud Scout #1 at 13:30 on 3/8/04. Drill 12-1/4" hole from surface to surface casing point at 2444'. Short trip to 965', RIH to 2444', could not circulate, hole packed off. Pumped out of hole at minimum rate with no returns, LD MWD. RIH, washing from 320' to 920', re-establish full returns and circulate out large amounts cuttings. Wash and ream from 920' to 2444' with large amount of cuttings to surface. Circ three sweeps with diminishing amount of cuttings to surface. POOH with no problem. Ran 9- 5/8" L-80, 40#, BTC casing to 2437' with no problem. Reciprocate with full returns while pumping 175 bbl of 10.7 ppg Arctic Set Lite lead slurry and 72 bbls of 12.0 ppg LiteCrete tail slurry. Displace with mud and bump plug, 50 bbls of 10.7 ppg cement to surface. ND diverter. NU BOPE, test same. NU BOPE, test same with BLM witness. Rill with 8-112" BHA. Pressure test 9-5/8" casing to 2500 psi, drill out cement and 20' of new fonnation to 2464'. Perfonn FIT to 14.6 ppg EMW, no leakoff. Drill 8- 112" hole from 2464' to 3536'. Pull wiper trip from 3536' to casing shoe at 2437'. RIH with no problems. Drill from 3536' to 4563'. Pull wiper trip to shoe with some packing off. 3/15-21104 Drill from 4563' to 5779', wiper trip to 4380' with no problems. Drill from 5779' to 7140', trip for BHA change. Drill from 7140' to 7661', wiper trip to 6784'- POOH to run 7" casing. Ran 7" to 3800'- unable to circulate. Pump out to 9-5/8" casing shoe, regain circulation; and ran 7" to TD at 7661'. Cemented 7" per well plan with good circulation- floats held & reciprocated pipe during job. Set 7" slips, RU & test BOPE's-OK. Cleaned out shoe track plus one foot of new hole. POOH to pick-up core bbl. Current status: Coring. ASP Coordinates for Spark #4, Scout #1, & Spark #8 . . Bob, per our discussion today the coordinates for the above wells in NAD 27 ASP4 should be as follows: * Spark #4: Scout #1: X=278,294 & Y=5,958,093 X=257,976 & Y=5,958,609 ~¿o A PTD package for Spark #8 should be arriving shortly (if not already), and the coordinates in NAD 27 ASP4 should be as follows: * Spark #8: X=252,539 & Y=5,943,628 The legal descriptions in the permits remain as indicated. Thanks, Tom 265-6377 (w) 275-7352 (p) 265--1336 (f) 1 of 1 1/14120047:44 AM ,. . FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 Re: NPRA Scout # 1 ConocoPhillips (Alaska), Inc. Permit No: 204-006 Surface Location: 571' FSL, 225' FWL, Sec. 20, TllN- ROlE, UM Bottomhole Location: 571' FSL, 225' FWL, Sec. 20, Tl1N- ROlE, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above exploration well. This 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. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403AD prior to the approval of disposal operations. 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. In your application, it is indicated that testing and stimulation of the productive intervals in the well may be performed. A Sundry Application (Form 403) detailing the planned activities should be submitted for approval. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE tests must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sarah Palin Chair BY ORDER OF THE COMMISSION DATED this 7th of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. e STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 k'/ç~ 1 a. Type of work: Drill 12] Redrill Do Re-entry ODeepen 2. Name of Operator Conoco Phillips Alaska 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 571' FSL, 225' FWL Sec. 20, T11 N-R01 E, UM At top of productive interval 571' FSL, 225' FWL, Sec. 20, T11 N-R01 E, UM . At total depth 571' FSL, 225' FWL, Sec 20, T11 N-R01 E, UM 12. Distance to nearest property line 13. Distance to nearest well , 4709' @ TD feet Moose's Tooth "C", 3.3 mile: 16. To be completed for deviated wells Kickoff depth: 0 MD 18. Casing program size 1b. Type of well. Exploratory 12] Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (DF or KB) GL 50' & 28' RKB feet o 12] Development Oil 0 Multiple Zone 0 10. Field and Pool ./ 6. Property Desjlnation AA081857/ ALK-5202 7, Unit or property Name Exploration NPRA 8. Well number Scout #1 9. Approximate spud date February 25, 2004 14. Number of acres in property 5648 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3009 psig / At total depth (TVD) 3900 psig Setting Depth NPRA Exploration 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 8100' MD 18100' TVD , Maximum hole angle 0° Hole Casino Weiaht 24" 16" 63# 12.25" 9.625" 40# 8.5" 7" 26# 6.125" 4-1/2" 12.6# Specifications Grade Couplina B PEB L-80 BTC L-80 BTC-M L-80 IBT-M Lenath 80' 2430 7595 627 Top Bottom Quantitv of Cement MD TVD MD TVD !include staae data) Surface Surf. 108' 108' 190sxASI Surf. Surf. 2458' 2458' / 320 sx AS III Lite & 170 sx Class G Surf. Surf. 7623 7623 180 sx Class G+ additives 7473 7473 8100 8100 120 sx Class G+ additives 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface Production Length Size Cemented Measured depth True Vertical depth RECEIVED O!~C 2 2003 AJ8IÎ8œ& Gas Cons. Comm~!cif! Anchorage 20. Attachments Filing fee 12] Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 12] Drilling fluid program 12]Time vs depth plot ~efraction analysis 0 Seabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? ciiITTom CJrasSfJeld 265-6377 Signed ?~ f1~ Title: Drilling Team Leader Date iZ/;?3j2Do3 ' Paul Mazzolini ..... . T 1&:2 Commission Use On Iv . : Permit Number, ,. . / /'1.1" /" API number.. " / /07'0., Approval date I' I, ~ III J' I See cover letter 2DLf"-C-(~rc' 50- J tY3 - 2D '-f /:' (X) ,..7 1()'-1 for other requirements Conditions of approval Samples required ~ Yes 0 No Mud log required '1 ~ Yes 0 No Hydrogen sulfide measures 0 Yes ~ No Directional survey required 0 Yes !&IcII" Nàf? T I' /. O 0 ¡;¡t¡ 0 0 0 _'1C.fllì'i-f7cn'\; Required working pressure for BOPE 2M; . 3M; i.JS1' 5M; 1 OM; ~ _ ",^,~/.J Y VL~l é711 ). Other: 'Çc:::.\"t-"O.-\\.t:)~\([<>-\\.('\.. \c \::..c O"....:I-\"'O~~<..~ \>¡ I..\.\;J ~.. \" \..()\ ~'"~.u ao ~þ,.,~.\h..~ v¡¡!.<.£, (f~~O 5()CX)fS-' .....~\.,H..)\ ~~ V ~S~ ~OC) ~'\N ~~""" ~ \-.ct.~<:. Cßy\~efrìf l ,I '" l Approved by . . ' ;. ·~v Commissioner the commission Date r I i[) "1 Sarah ~ãÌio I ' Perforation depth: measured true vertical Form 10-401 Rev. 12/1/85· Submit in triplicate e Conoco Phillips Alaska, _. Drill and Case Plan for Scout #1 General Procedure: 1. MIRU Doyon 141 over pre-installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4" hole to the surface casing point at 2458' MD/2458' TVD. Run MWD /./ LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. ,.../ · Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 V2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town 9. Drill 8V2" hole to top of Jurassic at approx. ±7623' MD/+7623' TVD. Run MWD / LWD logging tools v in drill string as required for directional monitoring and formation data gathering. Will trip to pick-up rotary BHA, placing GRjResistivity as close to bit as possible to assist in picking casing point. 10. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 7623' MD / 7623' TVD). Cement casing to bring cement ±1000' above 7" shoe. 11. Make up 6 1/8" mill tooth bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment, circulate & condition mud, displace to coring fluid and TOOH. (LOT is not ~ planned for this casing string - see attached explanation). 13. PU core barrel, RIH and core at least one 60' core. TOOH, LD core barrel and PU 6-1/8" bit and drilling assembly and TIH. 14. Drill 6 1/8" hole to ±8100' MD / ±8100' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. 15. Log 6-1/8" wellbore as necessary. 16. Run and cement 4 V2" 12.6# L80 IBT-M Liner ,¡ .j 17. Make a cleanout run with bit and scrapers · Displace to filtered seawater or brine- depending on formation pressure. · Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). · Record results and fax to town 18. Run and land 3-1/2" or 4 V2" tubing with gas lift completion 19. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 20. Secure well, release rig. It Conoco Phillips Alaska, _. 21. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 22. Upon completion of testing or if the well is not completed, plug and abandon the well, or temporarily shutdown per applicable regulations. Thoroughly clean location and block off further ice road accessto location. _ Conoco Phillips Alaska,_. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Scout #1 Drillina Fluid Proøerties: Spud to surface casing point Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids 9.5 - 10.2 ppg 16 - 26 25 - 35 50 - 100 10 - 20 15 - 40 7 - 15 9.5 - 10 ± 10% Drill Out Intermediate hole 9.5 - 11.3 ppg ,/ 6 - 20 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 9.0 - 10 < 11% Production Hole (Intermediate shoe to TD 9.8 - 9.9 ppg 15 - 25 14 - 24 50 - 70 3-6 3-8 <10 9.0 - 12.0 <8% Drilline: Fluid System: Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticiøated Surface Pressure and Casina Desian: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size 16" 9-5/8" 7" 4-1 2'''' Casing Settin De th 108' MD 108' ìVD 2458' MD 2458' ìVD 7623' MD / 7623' ìVD 8100' MD 8100' ìVD Fracture Gradient 11.0 13.8 17.6 17.6 Expected Maximum Mud Weights: Pore Pressure 47 1065 3740 3900 ,/ 12-1/4" surface hole to 2458' MD / 2458' ìVD: 10.2 ppg 8-1/2" Intermediate hole to 7623' MD / 7623'ìVD: 11.3 ppg (for shale stabilization) .,/ 6-1/8" Production Hole to 8100' MD / 8100' ìVD: 9.9 ppg 4E--fc.....". 5(J,./t..<J ~~~ik.1.4... 7. 7.'7/ /.. ..ì .1ýL-' ¡yu__~.d' r.-¡ G'-t ~~ I <.. Z¿.'S-2/ff/. ~ e Conoco Phillips Alaska, ~. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 108' = 50 psi OR MASP = FPP - (0.11 x D) = 1065 - (0.11 x 2458') = 795 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.8 x 0.052) - 0.11] x 2458' MASP = 1493 psi OR MASP = FPP - (0.11 x D) = 3740 - (0.11 x 7623') = 2901 psi 3. Drilling below 7" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.6 x 0.052) - 0.11] x 7623' MASP = 6138 psi OR MASP = FPP - (0.11 x D) = 3900 - (0.11 x 8100') = 3009 psi ¡ e Conoco Phillips Alaska, e. Casing Design Performance Properties Size Grade B L-80 L-80 L-80 Connection PEB BTC BTC-M BTC Tensile Strength Joint 979 M 667 M 304 M Body 916 M 519 M 267 M Casing Setting Depth Rational: 16" @ 108' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8" @ 2458' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture / gradient and well control while drilling 8-1/2" hole to top of reservoir. 7" @ 7623' MD RKB Intermediate casing is set strictly to provide isolation of potentially troublesome shales. The shoe of this casing will be set immediately into the top of the objective with a planned core to be taken immediately below the 7" shoe. A LOT would require 20' of additional hole to be drilled and would jeopardize targeted core recovery. Bottom hole pressures are available from offset data in the area. Well Proximity Risks: None Drillina Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Scout #1 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached mud weight versus depth graph for the offset wells Lookout #1, Lookout #2, ARCO Spark #1, Rendezvous "A", Rendezvous #2, Mitre #1, and Moose's Tooth "C". Annular PumDina ODerations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disDosal well but will be recvcled or held for an open annulus.) The Scout #1 surface/intermediate casing annulus will be filled v with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. PAl may request approval to inject or dispose of fluids in the Scout #1 9-5/8" x 7" annulus at a later ,/ date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC 25.080. e Conoco Phillips Alaska, e· Geoloav: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (55) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE nsi Permafrost 600' - ~c-, 200' 260 K3 2480' \ "'b 200' Possible Oil or Gas 1075 ~. Sequence 97 3030' 200' 1311 Sequence 95 3340' 200' 1443 Sequence 93 3560' 200' 1580 Sequence 92 4565' 200' 2061 Base Ponded Turbidites 5780' 200' 2630 Disturbed/Pebble Shale Absent LCU 7255' ¿if ",it 200' 3324 $.;¡ç;; Top Jurassic UJU/J4 7545 .... 200' Probable Oil and/or 3740 Gas ctS Base J4 Silt 7740' 200' 3790 TD 8022' 3900 Ç;.,",-~ ~~\N ¿~W Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res .I 8-1/2" Intermediate Hole (Surface Casing setting depth to Top J4/UJU) LWD: GR/Res/Density/Neutron/PWD ,¡' 6-1/8" Production Hole (7" Shoe to TD) LWD: GR/Res/Density/Neutron/PWD 0/ Wireline: GR/Res/CMR/MDTNSP (Contingency: PEX/RSWC/Dipole Sonic) II. Coring Full Diameter 2.5" Core in Upper Jurassic (1- 2,60' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful II. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. ý Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Thirty to sixty-foot (30'-60') wet and dry samples will be collected from surface to surface casing setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well TD and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals. e Conoco Phillips Alaska, e. III. Flow Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. It Conoco Phillips Alaska, e. Scout #1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12-1/4" Hole / 9-5/8" Casing Interval Event Gas Hydrates Risk Level Low v Clay Balling Medium Abnormal Pressure in Surface Formations Lost Circulation Low .I Medium 8-1/2" & 6-1/8" Hole Event Lost circulation Risk Level High Hole swabbing on trips Low Directional Control Medium Sloughing Shale, Tight Hole High Abnormal Reservoir Pressure Hydrogen Sulfide gas Low ;/ Low ¡/ Miti ation Strate Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tem eratures Maintain planned mud parameters, Increase mud weight, use weighted swee s reduce fluid viscosi control ROP. Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runnin seeds. Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- lanned LCM ills lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, wei hted swee s. BHA design, on-sight geologic review and advisement of otential slum blocks. Increased mud density and fluid composition according to plan, controlled tri seeds swee s ECD monitorin . Well control drills, increased mud weight, contin encies for to set casin strin . H2S drills, detection systems, alarms, standard well control practices, mud scaven ers 1000' 2000' 3000' 4000' 5000' 6000' 7000' 8000' 9000' Well: Scout #1 _ Field: NPRA Exploration TVD/MD o TD @ 8100' o Vertical Section Est. RKB Elevation @ 78' Permafrost@678' 9-5/8" Csg Pt @ 2458' K3 @ 2558' Sequence 97 @ 3108' Sequence 95 @ 3418' Sequence 93 @ 3638' Sequence 92 @ 4643' Base Turbidites @ 5858' Disturbed Shale N/A LCU @ 7333' Top Jurassic & 7" Csg Pt @ 7623' Base J4 Silt @ 7818' . Estimated Surface Location: 571' FSL,225'FVVL Sec. 20, T11N,R1 E,UM e Scout #1 WELLBORE SCHEMATIC and CEMENT DESIGN 116" Conductor Casing at 108' MD / RKB I I Base of permafrost 678' MD 9-5/8" Surface Casing at 2,458' MD Top of Cement at 6,623' MD 7" Intermediate Casing at 7,623' MD 4-1/2" Production Liner @ 7,473' MD to 8,100' MD 12-1/4"H, 8-112" Hole 6-1/8" Hole . Conductor Casing Size / Hole Size Depth: Topol Cement Excess Calculated: Volume Calculations: (108 If) (170cf) (0.7854 elm) /(0.93 el/sx) 16" in 20" hole 108' MD RKB Surface 100% (2.00) = 170 eI 190 sx or Arctic Set 1 190 sx rounded Slurry Volume: 170 cf Slurry Weight 15.7 ppg Slurrv Yield 0.93 ellsx Surface Casing Stage 1: Volume (678 If) (980 If) (1,401 cf) (80011) (363cf) (0.3132 elm) (0.3132 elAf) 1(4.44 cf/sx) (0.3132 elAf) 1(2.40 cf/sx) excess 9-518" in 12·1/4" hole (4.50) = 956 eI (1.45) = 445 eI 315sx (1.45) = 363 eI 166sx System: Lead (Arctic Set 3 Ute cement + 9% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% S1(CaCl2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tall (UteCrete @ 12.0 ppg) Intermediate Casing Size / Hole Size Depth: Topol Cement Excess Calculated: BHT (Static): Volume around 7 ' (1.000 If) shoe ¡oint vol 17 cf+ (190 cl) (0.1268 el/lf) 1(1.17 cf/sx) Lead Tall shoe Joint vol 34 cl + Lead Slurry Volume: 1,401 cl Slurry Weight 10.7 ppg Slurry Yield 4.44 cflsx Thickening Time 6.0+ hours Tall Slurry Volume: 363 cf Slurry Weight 12.0 ppg Slurry Yield 2.40 cflsx Thickening Time 3.5 - 4.5 hours or 320 sx Arcffc Set 3 Lite or 170 sx Class G System: (Class G cement + 1% D800 + 0.2% 046 + 0.3% D65 Slurry Volume: 207 cf Slurry Weight 15.8 ppg Slurry Yield 1,17 cflsx Thickeninn Time 3.5 - 4.5 hours 7" in 8-112" hole 7,623' 6,623' 50% 16()1! F 13()1! F BHT (Circ): excess (1.50)= 190eI 177sx or 180sx Class G Production Casing Size / Hole Size Depth: Topol Cement Excess Calculated: BHT (Static): (477 If) (0.0942 el/lf) 4-112" in 6-1/8" hole 8,100' 7,450' 40"10 16()1!F 13()1! F BHT (Circ): excess (1.40) = 63 cl (63 cf) 1(1.20 cl/sx) Volume around 4-1/2" Vol. Between liner & Int. shoe joint vol 7 cl + Volume 01200' above liner System: (Class G cement w/Gasblok + 0.1 gps D47 (defeam.) + 3% D53 (Gyp) + 0.75% D65 (disp) + 1 gps D135 + 2 gps 0000 + 0.1% D8DO (ret.) 20sx 58 sx 40sx Slurry Volume: 122 cf Slurry Weight 15.8 ppg Slurry Yield 1.20 cllsx Thickenino Time 3.5 - 4.5 hours or 120sx Class G Cement volumes and blends are estimates only and subject to change before pumping. 12/16/2003 Scout #1 e Proposed Completion Schematic 16" 65# H-40 @ +/-108' MD Depths are based on est rig RKB Surface csg. 9-5/8" 40.0# L-80 BTC (+/- 2458' MD /2458' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+/- 7623' MD 17623' TVD) Production Liner 4-1/2" 12.6# L-80 IBT-M (+/- 8100' MD/81 00' TVD) e 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT -M pin down 4-1/2" 12.6# L-80 IBT-M Spaceout Pups as Required 4-1/2" 12.6# L-80 IBT-M Tubing to Surface 4-1/2" Camco 'DB' nipple w/3.875" profile set at +/- 500' MD. 4-1/2" x 6' L- 80 IBT-M pup installed above and below 4-1/2" 12.6# L-80 IBT-M tubing to landing nipple 4-1/2" x 1" Camco 'KBG-2' mandrels w/ DV's and RK latch, 6' L-80 handling pups installed above and below. Spaced out wI4-1/2", 12.6#Ift L-80 EUE8rd tubing as needed. 4-1/2" x 1" Camco 'KBG-2' mandrel w/latch & dummy, 6' L-80 handling pups installed above and below. 2 joints 4-112" 12.6# L-80 IBT-M tubing 4-1/2" x 1" Cameo 'KBG-2' mandrel w/latch & dummy, 6' L-80 handling pups installed above and below. 1 joint 4-112" 12.6# L-80 IBT-M tubing 4-1/2" Halliburton "XN" nipple w/3.725" profile 1 jt 4-1/2" 12.6# L-80 IBT-M tubing Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 4-1/2" L-80 IBT box up Liner Assemblv (run on drillpipe), Baker 7" x 4-1/2" 'lXP' Liner Top Isolation Packer with C-2 profile & 12' PBR Baker T' x 4-1/2" 'HMC' Liner Hanger 4-112" 12.6# L-80 IBT-M liner as needed 4-1/2" Baker Landing Collar 1 jt 4-112" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Collar 2jts 4-1/2" 12.6# L-80 IBT-M tubing 4-112" Baker Float Shoe 3-%" 9.3 ppf L-80 EUE rd may be substituted for the 4-%" T JB 12/17/03, v1 Scout w/Doyon 141 no pilot Expected Drill and Complete Time o , I I I i -- - - - - -- ,- - \ -- - -- - - - - u~u - -- -- - - - 1 - i- -- - -- - -- - - - - - - lu_l_u - - -- - - - -- - -- .- - Estimat~d Time to Drill & Complete I \ with MIRU is 33.5 days 1 , - - - - -- --- - - \- .- - - - - i- - -- - - -- -- - - - - i- - ... -- - - - -- - I I I , ~ . .... - - - - -- 1- - - - - i- .m - -- - - _m -- - i- - -- - - - - -. - --- - - - - - - - -- - - -- - - - - I"'V iV ì\ I , I ~.'- - - --- --- - - - - - - - - - \- --- - - --- - - -- - - - - ---- -1- -- - - - - - - - -. - -- -- utu - - - - - -- - - - -- 1 I I I , I , , I \ I 1 - - - - - - - - - - -- --1- - - [-- ... -- -- - - - - - -- - - - - - - - - --- - - - - - \ [' I I - - - - -- - - ~ - .-- - - - - 1- - - - ~-- - -- - - .- - - - -- - --- -- - - - - - - - - - - - 1- -- \- - - - - - ---- - - 1- -- - - - - - - - - - - - - - - - \ ¡ I' ¡ I - - - - - i- -- - - i--- - -- - - - - i- i- -- - -- - ,-- - - -- ¡- ~ - - - - - - - , -- --- - - -- - - - - -i- - - - - -- -- .- 4& "" I"" I '" ~ I k."A 'V'i .'" 1"'- . -- -1- - -. i- - ~ '- '- --- -- 1000 2000 3000 4000 5000 6000 8000 7 10 0'1 -~--~- ,¡ t~-:u:-~-~-,-,~~=-- -¡-~-~-:---~ ~-\f=I= ~ + t- -:u:-~-~jf-~-i- -= -- ~_¡u:- -~=L~-,-: ' , t=~=I=~-~ ~-t= '-,-=IMIRU. 120 rig loads from 100% pad r_~=:===~=~=~=\=I=u~-~-t= =:==:=~_~_ -~=:=-:-r _,_~=:==:= '=~_t=~Slougingshaes.lncr.MW 1000 " " from 11.3 ppg to 11.5 ppg to _': ' "" - _u_ _,_, : I ", \ , : ¡Drill 12-1/4" Hole I -~-:--- ,- -'-~-:-' : ~ : control - :ui- ~ -1 = = f ~ = _ - _' I , -: i- - i _:u - ¡ -: = 1- = 1- ~ \ ~ + = ~ - ~ - + = i: I ~ = _ - _ ~ -1-, = + - f = ~_,_ _, I I f- - 1- -:- - -; _ ;-, ,¡ I I , I - -; ¡ - ~ -:- - - ~ - -; ,-, - -~; ¡- I I I I I I I , ¡- -:- -: - -" I' 1- - 1- - ~ - ~ = -: - ¡ - -; - ¡ - - : i= -=~-:- I I I" I -~ ~ ~ I -~-+-i-= = =~j, 1=~=]9-5/8"set@314~' I :-~:H:II: ~_:- - - r ~HI ~: ~~ -,--,-i---I- -¡-+ ~ r-¡--'---"'-~-¡---- -:-\,.: ¡---I 14.5ppgFIT , !=~~=+ '_¡-_Iu ___-¡-+u-I-,.,-+-r- , , I : -. - f I I ~ - -, -, - -, - I - T , , UI I , ]I. + - f - I I I It" -, - -, - ,- -, -, 1- I T :- - I '" 1- -:'ï I ,- _,_=,=u~=r=~=:=-,-tT-~ ~_:_ I I T f u~-+-'--'-- u-j, I Ill' :-Lf :--'- -, :: 1-+-T-:- '--'--j--:uu:-i-+-T~ f 'I I I I -I=:=:=:===J 1=,_=,-= -'-~=F~= =¡=_:_ 4-r =~=¡= --= __ ~=:==:=UT-~-~-'- ====~-:=_=:=J_l=~= . =u_ -F -~=:==:=~= =T=~-:U'- -f-~-~-i- -~ ~ ,- ~-T-T- _:u,-; ¡-t-,-,-,-;- - _,_'u,- -T-,-r-,- u -~-,- -:-~-f-~- , I , ~_ ~_:u:_~_ _,_~_'u'_ _~_~_~_:_ _~ ~ _ I __~ ~_~_ _:u:_~_II_ _~_:_ '_ _' _~_:__:_ I_~_~_~__ ~ I ~ ~---:-~-~ ~- -j--:--:-~- -~-:--:-~ __L_L_i_ -~-~-~-:- -~ ~- - ~ 7-~- -:--:-~- olei -~-:--:- -7-~_~_L -1_-L_~_~___~_~_~_¡_ ¡- -r-I--¡-ì- - - ¡-T-r i-T ¡-r- -;-I-T-í- -1--1--' ~-r-I--- I-T r r ,T-¡-r---I ¡-T r- _u:_~_~_ -~-'- I ~- - -, -,- -~ L~_:_ '¡-~-~-, I ,-t 1-_ -~--~-~ , I 1-' ~_:u:_ : ~-~-:- ~--'-~-~u-:-~-t-~- -- -1- i' I -: -r +-- ---- --'-~-~-;----: -' ' ., .1:__ : -I-~--'- _'_1-_ _1-_~_I_ -+-1--~-'_ ,- --~-=--I -I -'--!- - - - + - -, - - T - iH r i - T - ,u -,- ~ - i - ~ - - -,- ~ - + -0' ~- :- IHI ¡;TD/M k tt t@ -:- i -':=~=T=1--1----I- ;-t-:- -I·' -i-- -:¡-1-- _'u'-_I_ ¡-~--I--!- -'--i-'--'u-; t ~ I a ea emp - - -, -,- - ~ -1 T ¡ ,- u ~ - + - , - ,- - I T - - T -,- t 1-- - I í I - r :- , - i~~~~o~~~:~~r~~rt: u + - - - ~ -:- -1- -- + r r -1- + - - - [ :- - clean hole, run '_ + =_ ~ ,- -,- -I -1- i- - =: =:- _ = + _ f = ~ -,- = ~ _ + _ - _, _1_ ~ _ ~ 1- 7"/CementlRun +i---;- -~-:U:-~-1'''' i ¡-¡-:- ,.,-+-i--.,.-, , I I I' , , " ~-+-.,. -GR/JB/USIT/MDT, , 'I'" I I " I'" :: I I I" , , " ::: ,run 2000' of tbg and =i--!-~-l= _~-I--I-J=. ==_= __ ¡-¡-r-=:=~--1--r-_ i ¡-J -:- -; ¡- -~ -- -'--~-I--:- =:-:=r--¡- ,=RDMO ___u_'_ I ~_ _ =~=~=__,_ =-¡=r ' _ I ~ ~_~ I I ;-,= _,= 1-- = = -e-, =1= _:~_,___ -ComDletion/QDerati, It -, ,-, - I - - - - - -,- - - - I - I - I' :" -- -, - -; ,- T -:- -' - i - - - - '- -, - - , - - - ,- - - - i-' - i '- '- +" ,; - ~ -I 8000 ~-'--I- -~- -~ -:-~-"'--, i I t-} ~+--~-t-t- - -,- -t-j- -:- ~-: ~: \, 'LL:__ - _LI - , : l L r-,- ,- r-I--1-4- --,--,-,--,- -,--,-r-I---'" , -¡-.., 1" T" -I"'-tfi!!iiiìill I ' ~ _Ii__:__:_~_ ~ ~ 7 ~._~ l -~-t- ,1.-__ _:_¡-~-~ _tl_ ,.J -' '1-; - ~ I -;-·1 - l' ~_~.._i__~_-1_L, _~_~_JI_.JI_.LI_~_ I _:__, _H _ ~ _ ~ ' I 9000 T- -I I ì-T-r-¡--c-ì 1- -: ~ r 11.' I - I ¡-j- :-' -;- ~-r-!- -¡-T-r-I----¡-;-T r~ -;- ri= -t-:--:-j r _ _'_ =Lt t' =j=i=~ - -'-j i-t-r' -:-j=L _t_:_ ' == =L=t_:_=:=- =Lt ~ ,___+- ~ L:__lj-j-Lt~ 2000 3000 ¡::- W W LI.. - J: 4000 t- Q" W Q Q 5000 W D:: :;) (fj ~ 6000 ::i 7000 116" set @ 108' I I I DRILLING TIME AND MUD WEIGHT CURVE Lookout #1 -<t--- Depth Weight - - o 10 15 20 5 25 30 TIME TO DRILL (DAYS) 35 40 50 45 55 Spud Well @ 0900 hrs 3/31/01 Release RÎg @ 0600 hrs 4/30/01 prepared by WBL 5/0701 11.9 11 11.5 11 11.1 10.9 I- :::r: ø 10.7 W ~ Q 10.5 ~ 10.3 10,1 9.9 9.7 9.5 9.3 60 2 11.8 11 11.4 11.2~ 11 10.8 !- :::I: 1 C> W ~ 10.4 g :æ 10.2 10 --+-- Depth DRILLING TIME AND MUD WEIGHT CURVE - ~- f- -+--1--+ _ _ L _ J. _ _i_ _ ..L _ I ! I I _ _ l- _ --! __ _ 1_ _ +. _ I I - - ,- --I f- - ....¡ "- - 1- - + - .L 1 _ _ L _ _1 _ _ 1_ _ 1- _ 1 1 I --1--1- -T- - -- - - f- - ....j-- -1- - +- _. J.. 1 _ I I L .1 _L .1 f- -¡ -1- _l..._ 1 1 1- -,- ,- - -+--1- - +- 1 1 -, - 1- - -ì -- f- -- -+ - - 1- -. +- ____J_ 1 , 1 -----¡-------¡---¡----¡-- _ _ L. _ -.l __L _ 1.. _ I , r r 1- + - I- I 1 I L ~ 1 I 1 1 r - 1 - -I- T )Iete Well & Re, I ' i I -'---'---'---'-- = 115' @ 6" set 3000 4000 ¡::- W W I.i.. ....... c w a:: :;) (J) « w :IE 5 o FIT 12.0 1000' 2000 3000 ~ W IL - ::E: t: w Q 4000 5000 6000 7000 8000 9000 10000 o - ~ - _1- _ , , , - ï - -,- - r -~--t--~ :-i-- _ 1 _ _,_ _ l _ , , , _ ~ _ _1_ _ .a.. _...I _ I I I - 1 - -,- - T - ï- - ~ - -,- - ~ - ~ - _ l _ _,_ _ l _ J_ I I I I ~ _ _1_ _ ~ _ .J _ _ , , I , - ï - -,- - r - , - - - ~ - -1-,-" -... -- _ 1 _ _,_ _ l .:. J _ _ I I I I _ .J. _ _1_ _ .L _ ~ _ _ , , "I - , - -1- - r - , - - - of '- -,- - ... - -f - - _ J _ _,_ _ l _ J _ _ I , I I _ ~ _ _1_ _ 1. _ ~ _ _ I I I I - , - -I· - r - , - - - ... - -1- - ~ - -4 - - _ l _ _I.;. _ l _ J _ _ , 1 1 1 _ .J_ _,_ _ 1. _ ..J _ _ 1 , - , - -.- - r - , - - -"-,-1--+"--1-- _ J _ _,_ _ l _ J _ _ I I t I _ .J _ _1_ _ 1. _ ..J _ _ , 1 1 , - , - -1- - r - , - ..; -"--1--+,--1-- f I J I -¡----ï-ï-- _ .J _ _,_ _ 1. _ ..J _ _ . 1 , 1 - , - -,- - r - , - - - .... _ -1- - .... - ..... - - , 1 1 , -ï--,--ï-'¡-- _ .l _ _,_ _ 1. _ ..J _ _ , 1 , - , - -,- - r - , - - _ 4 - _,_ - +' - '-I - - I I I I -ï--,--¡-¡-- _ .l _ _,_ _ 1. _ J _ _ I , , - "I - -- - r - , - - - 4,- __ -.. - -I-- 1 , , , - ï - -,- - r - í - - o , DRILLING TIME AND MUD WEIGHT CURVE' PAl Spark #1 _~_~_ ~_~_ ,__~_.J__~_~_~__~_~__~_~_ . f I I I , I Move In rig 3/2112000 -:r-ï----r-'--'--¡- -~-~---~~-..--~-+- - 1 --1- - 1 - 1 - -- - , - 1- - ~ - { -- - - ~ - ~ --:- - t-: _ _ ~ _ ~ _ _1_ _ L._ I I I I - - r - , - -1- - r - - - t- - ~ - -1- -- to - _ _ L _ .l _ _'_ _ l' _ I I I 1 __..._~__I__L_ --:--f--:--f-- --t--+--f-'-t-- __L_J_J__l_ I I , I __L_~_~__L_ --k-~_~__L_ I I I I I I I f --r-'--~-r- --r-Y-~--r- - --....-+-~--...- _ __L_J_J__L_ I I I I __L_.J__I__ _ , , , " - r - , - -,- - - _.L...:.-I__L_..1_ " , , -T--,--r-,-- -+--1--1--"-- _ .1 _ _I:.. _l_ J __ 1 " , 1 L_ __L_.J____L_.J__L_L_ I I I I -, I I I r '--r-T----r-'--r-y- ~--~-....----~-~--~-+- _J__L_.1____l_J__L_!_ I I I " I 1 __L_.J.__'_ L I , I I --'r-,--,- r- --"'-~--I- ...- _ _ L _ 1 _ _1_ l _ I 1 I I _.1_-'__L_ , " , 'I 1 1 1 I 1 1 -T-'--r-'---- -'-~r-T-~--r-'--r-r- -+--I--~-..----+' ~-_~-+- --I---I--~-~- 1 I . 1 . I 1 - I I 1 I I I -ï-ï--¡-ï----ï ¡--¡-ï- --¡-¡--.-ï- __L_.J.__'__L_ 1 , --r-,--, - - I- - 4 _ -, 1 1 , - - ¡ -, ï - -I _L_.1____L_~__L_L_ " 1 I I 1 -'----r-'--r-r- _... - - ---1-- -1--1--"'- . " I I - ï -- --ï-¡ --,-- ï- _ _L _.J __I I I , --r-,--, _ _ ... - ~ - -I 1 , , --¡-ï--, _,J_-'__L_.J____L_ , 1 1 I' 1 -T-'--r-'----r-'- -~-~--...-~-- -~-~-- , . " 1 1 , -ï--,--¡-ï-- -ï--,--, _J_-'__L_.l____L_J__L .1____l_~__L~L_ I I I 1 "I' I 1 ,., I -T-'--r-"l~---r-'--r "I----r"'--r-r- -~-~--~-~----~~~--~.- ----I--~--~_.~- I I I I I" -T-¡--¡-I-- -ï-.--¡- - __L_.l__'__L_ 1 I 1 .. --r-'--I--r- _ _I- -4 _,_1__"_ . ' I - - ï - ï - -,- - ï - __L_J._....I__L:_ I I I I --,- - Y - -,-- r- --~-+--I--~- _ _1_ _1_ _1_ _ L_ I I 1 I __L_.L_-I__L_ 1 I 1 I -r-y-,--r -1--+--1--'" _1__1__'__L , 1 . I _1._ , -r- ..:....- 1 -ï- __L_J_-'__L_ , , , , --r-T-,--r- --I--~-""--"'- __I__!__I__L_ 1 1 1 1 _ _,_ _ ~ _-1_ _L_ , , 1 , - -1- - r -,- -,-- - -1- - + - -1- -~- _ _'_ _ I. _ J__,L_ t 1 , 1 __I__J._..J__L_ I I I 1 - -1- - r-,- -,-- - -t- -... - --4- -t-- _ _1_ _ I. _ J _ _ L _ I I" I I _ _1_ _ J.. _ ~_ _L_ I I I 1 - -1- - r -,- -r- _ _,_ _ 1. _ J_ _L_ 1 , 1 1 __I__~_-I__L_ I ," , I --I--r-,--r- --I--"'-~--"'- _ _I__L _ J_ _L_ 1 I I I _ _'- _.L _..J_ _L._ , 1 'I 1 - -1- -r -,- -r- --"'-+''''~--~- __I__l_J__L_ I 1 I I __I__.1._..J__L_ I , 1 I - -1- - r -,- -r- - -1- - ... - -1- -... - _ _,_ _ 1. _ J_ _L_ I I 1 I __1_ _.1._ J__L._ 1 I I 1 --~ - r- ,--r- --t--....--I--~- I , I , --,--r-¡--¡- _1_ _ L_J_ _L_ 1 ,'f - I--r-,--r- _ __...._-f__I-- 1 1 1 - -I - ï - -1- -¡- 5 10 15 20, 25 30 TIME TO DRILL (DAYS) _1._ 1 -r- -..- 1 -ï- __L_~_-'__L_ , , t r --:r-T-,--r,- --...-.¡;-...--~- t 1 I 1 --I--ï--I--¡- __L_.1._J__l.:" . , 1 " --r-T-,--r- --~-~-",--..- , I 1 'I --,-'-ï--I--¡- _ -1_ _ L _.. _ _...._ 1 1 1 1 --,--r-'--I-- --r--~-..--~- _ _1_ _l_ J _ _'__ , , 1 1 _-I__L_~__""_ 1 I 1 I --I--r-,--,-- --1- -... -"1- -1-- _ _,_ _l_ J _ .;.1__ I II! _ -'_ _ L _ ~ _ _I- _ 1 , t 1 - -1- - r - , - -,- - _ _1_ _l_ J _ _I__ 1 1 1 , _ _,_ _ L _ -1_ _1-_ t I I I - -,- - r - "I - -1- - --1--"--1--1-- _ _1_ _ l _ .J _ _1_ _ . . t , _ J_ _ L _ ~ _ _I- _ I lit - -1- - r -, - -1-- - -1- - .. - 1 - -I- - _ _1_ _ l _ J _ _1_ _ I . I 1 _ _1_ _ L _ ~ _ _L_ I . 1 I - -1- - r -, - -1- - - -1- _... - ~ - -1-- _ _,_ _ L _ J _ _'-_ I I I I _ -'_ _ L _.. _ _'- _ . I I I - -1- - r -, - -,- - - -1- - ... - ... - -I- - I I t I --,--ï-¡--I-- _ _1_ _ L _ .J _ _L _ 1 I . I - -,- - r - , - -r - -'-1- - I- - ~ - -1--- "I t . t Logged ¡ --1-- .J__L_ I . 1 . 35 ~ Depth -Mud Weight _-J__L_~__I_-_ 1 , , 1 - -1- -r -,- -1-- -'"1--~-~--I-- _ J _ _ L _ 1 _ _1_ _ I , 1 I _"'__L_"&__I__ , , I I --,--ï.-¡--,-- - -1- -.... -.. - -1- _ J _ _ L _ 1 _ _'_ _ I . 1 1 _..J_ _ L. _.1 _ _I__ 1 I I I - -,- - r - , - -,- - - - t- - 1 - -1- - _ .J _ _ L _ 1 _ _,_ _ J I I 1 _.J_ _ L. _.1_ _I__ I I 1 1 - , - - r - , - -,- - - -1- - t- -... - -1-- _J__L_J__'__ t I . 1 _-I__L_.J__I_ ill I. -ï--r-T--,-- -~--...-...--.-- _ _1_ _ L _ .1 _ _1_ _ . "I 1 I ':"'.J__L._.1__I__ I 1 I 1 - , - - r - , - -1- - - -1- - ~ - ~ - -1- - 1 I I I --.--ï-ï--.- _~__L._.J.__'__ , I t 1 -,--r-,--,-- -....--...-~--I-- I I I , " --I--¡-ï--.-- _-'__L_.l__I__ . . I . -,--r-'--I-- _....__1-.:...4__1__ I I 1 . - -,- - ï - ï - -1- - - .-':', - ,--,-:- -,--r-'--I-- -....--~-~--I-- 1 I I f - -,- -¡ - ï - -.-- 40 . . . . 12.0 11.8 11.6 11.4 11.2_ 11.0 10.8 10.6 10.4 ... :J: 10.2 æ ~ 10.0 c ::» :2 9.8 9.6 9.4 9.2 e 9.0 8.8 8.6 8.4 8.2 45 Jt 9199 2000 ~-- 3000 116" set @ 10T! DRILLING TIME AND MUD WEIGHT CURVE Rendezvous "A" 4000 5000 6000 7000 8000 o L I ,-- -' ----i- I __.J_ ___L_ I I ---'1- , ____..J_____L I I --'1- , -' I '1 L -' I I --,----'1----- ____l-___ ..J I I ,-- '1- -----.--- I 1000 I ,- ----....,-- --I- I I I -~--I- -I I- I U I I -~-----~----~-----~ ~ I ¡ - -1-- r I 1 ____.J_ 1 _ ____..1______ I 1 r ---'----"1-----1 1 ì--- ____-1_____ I ï---- ____-1 I - - - -"4 , I I --I --r---- ____-1___ _L I 1- -- ____-1____ L I I 1 ---r---- _L 1 L -' I -I --I I l- I- I I ì-----,--- j I 1------ --~---- I--------j-----r-- -+-- Depth I -Mud Weight I L_ I ---,--- L____ 1 , L____J_____ I I ---¡- ---.....- __L___ J_____ I I , '1 11.4 11.2 -~-------j-----~-----.----- I I 1- 1 -! -!-! I 11 I ~--i-------+ 1 10.6 10.8 1 -;-- __1____- I r r I I ---r -r- ì-- _____~-----1-----1 ----~----- ----r- --I----ì L L-1 1 1 I --~---- t......-__ --! 1 I ------¡--- 1-._------1-- 1 1 10 I r 1-- I 1 I 1 0' I -1----- -! I 1 -----r------ 9.8 9.6 Rig@ DRILLING TIME AND MUD WEIGHT CURVE Rendezvous #2 -+-- Depth -Mud Weight -' I L I -----r-- ,- -' I -,----- ~_____L_ _____L I I --,-----r-- r---- ~-----~----~-----~---- ,r r L____-i _____L____ _____L____~_____ I I I ---r----'----- ______ __....1_ I I r , 11.4 I r 1000 11.2 2000 11 3000 4000 5000 10 6000 7000 4/8/01 DRILLING TIME AND MUD WEIGHT CURVE Mitre #1 ............. Depth I-Mud Weight 1000 -'-- I 1-- - +- -1-- +- -.....¡ I I I I I I 12 11.8 2000 3000 11 10.8 10.6 7000 8000 9000 o hrs 2000 3000 4000 5000 6000 7000 8000 9000 DRILLING TIME AND MUD WEIGHT CURVE Moose's Tooth C -+-- Depth Mud Weight o ------ + I I ---+------ I -, " I ~, , 1000 J 1 --,----- ______J_ _ 1 -----f-------{- 1 1 ~------ - ~ ------1------- t------~------ ------~ L______ ----__4______~__ ~ 1 1 I r------ - --~------ r Move În Doyon 141 3/23/01 from Randy A -r ______.1..___ I 1 -------¡-------r------T------ _1- __ 1 ---f- - I 1 .------ ------ I -I I - -,~ - - - - - - --Í - - - - - - -I- I 1 --1------ --^------- 1 .--.--¡---- -- -----,---- 1_ _ _ _ _ _ _ _ ~ _ _ _ _ _ _:_ _ _ _ _ _ _ _ _ _ _ _ _ J.. _ _ _ _____====t=_====J=======:====--- 1 I --------- - - - - ------ ~- 5 1 12.0 11.8 11.6 11A 11.2 _, 11.0 10.8 10.6 10A 10.2 10.0 9.8 f1.6 e e ConocóPhillips Box 100360 Alaska 99510-0360 December 24,2003 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill: Surface Location: t?~c ¿I-.;., ~, lv~^ 4/;;.. "-(" 2 .......ù ....t.f'~Q¡, .' ' (>(1 Scout #1 (Exploratory Test) (lGa.rI'~_ ' t/()J 571' FSL, 225' FWL, Sec 20, TllN-R1E ~...~8. X=752096, Y=5958939 ASP5 NAD27 ...."'i!ge·COQ¡I}¡~_ 571' FSL, 225' FWL, Sec 20, TllN-R1E ·"'VIOI¡ 571' FSL, 225' FWL, Sec 20, T11N-R1E Target Location: Bottom Hole Location: Dear Commissioner: PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8-1/2" well bore to the top of the objective with a LWD logging suite for I evaluation. ~"intermediate casing will be run in order to case off potentially sensitive shales and drilled out with a 6-1/8" bit. Only a minimal amount of hole ( < 1 ') will be drilled before POOH to pick-up a coring assembly. At least one 60' core will be ./ cut through the objective zone beginning immediately below the 7" shoe. The well will then be drilled to TD and depending on the logs either a 4-1/2" liner will be run and the well will be tested, post-rig or the well will be P&A'd. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate casing, a 4-1/2" production liner and either 4-1/2" or 3-1/2" tubing. Please find attached information as required by 20 MC 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 MC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 MC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 MC 25.005 (c) (2)- straight hole. e e 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 AAC 25.035 (a) (1) and (b) have been submitted previously. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). ) (Previously submitted- on record) :t~ (k-r6tfrYl- I ¡/v-RJlr,£ (2~"':'3 Zit' 8) PHILUPS does not anticipate the presence of H2S in the formations to be v encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, coring, and mud logging operations are planned and / descriptions are attached. The following are Conoco Phillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 AAC 25.071) Greg Wilson, Geologist 263-4748 The anticipated spud date for this well is Februarv 25. 2004. If you have any questions or require further information, please contact Tom Brassfield at (907) 265- 6377 or Paul Mazzolini at (907) 263-4603 Sincerely, J~' Tom Brassfield Senior Drilling Engin er cc: CONFIDENTIAL - Scout #1 Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 I#;) e e SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS 3760 PERENOSA ANCHORAGE AK 99515 1008 J2)¿'1/öJ . 62-14/311 DATE $ (OO,W ,/2-^-ð I/)" -- .0. """,,'~'".' (,/l.:;.-:-- DOLLARS l.!J ~g:~"BB"," ~.... CHASE Ch.se M.nh.n.n Bank USA, N,A, Valid Up To 5000 Dollars U 200 White Clay Center Or., New-ark. DE 19711 ". . r .'00 h,¡ S".,.¡ ..... iLL':': .~:])~¡~ I: 0 j ¡. ¡. 0 0 ¡. It It I: 2 ¡. a It ? ¡. t:¡ 0 ? t:¡ 2 ? b III ¡. 0 0 a e e TRANSMlT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~0 CJ -I- I . :2{~ ¿I-Cúé) PTD# Q.:'{. V \0\0\\ a f' ~<¿\ \ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. . (If API number Productionsbould continue to be reported as last two (2) digits a function' of the original API number, stated are between 60-69) above. Pll.OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ex ception. (Companv Name) assumes tbe liability of any protest to the spacing ,exception tbat may occur. / / DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals through target zones. " Rev: 07/] 0/02 C\jody\templates Well Name: SCOUT 1 Program EXP Well bore seg PTD#: 2040060 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType EXP I PEND GeoArea 890 Unit OnlOff Shore On Annular Disposal 1 p~lTT)itfee !,!ttaçhe~L _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Le!,!s~_n.umberappropriate_ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _UJltq.ue weltn_arn~_a[1d o~mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ 4 WeJlJocat~d ina d_efil1eJ:ipool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ Exploratory wildc!.!t _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJlJocat~d pr_oper _distance from driJling ul1itb9Ul1dary_ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJocat~dproperdistance_fromotlJerwelJs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s_ _ _ _f\JearestweIUsfishCkTest1,_-2._8_miNE _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 7 _SutfiçieI1Lacre!.!9-e_ay!.!ilable in_drilJiog unjL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jtd~yiated, js weJlbore pl!.!Ul1clu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ Verti~al welL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _O-perator OI1I}' !,!f{eçted party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-pecator lJas_appropriateJ~9nd inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ 11 p~lTT)it ~a[1 be iss~ed wjtlJout conservaJiOI1 order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 P~lTT)it c_a[1 be issu_ed wjtlJout !'!dmil1istcatille_approyal _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 1/5/2004 13 Can permit be approved before 15-daywait Yes 14 WellJocatedwithil1 area !.!Ild_strata authorized by_l[1jectiolJ Or d~r#(P.utIO#in_cornrn~ots)_(For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 15 _AJlw~lJs_witniJ1Jl4_rTJile_area_ofreyiewid~oUfied(Focservjc~_wellOI1I}'>- _ _ _ _ _ _ _ _ _ _, _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _, _ _ _ _ __ 16 Pre-produ_cedi[1jector; J:i.uration_ofpre--proJ:iuctiol1l~ss_th!,!n_3mOllths(For_servicewellonly) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 17 ACMPJ'inding of Con_sistency has bee_nJssued_ forthis projeçt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ KayeLaugnljll, JI='Q:_NoReyiew R~Q~ir~d for Sco_ut 1. _ 1J5104 SF"[~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Administration Appr Date . Engineering Appr Date L,T.1/612004 ¡Jff,vl Vy Geology Appr SFD Date 115/2004 Geologic Commissioner: áJ¡S Field & Pool D D 18 _C90du_ctor strillg_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urfac~_c!.!sil1g_pJQte~ts alLknowll USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ f\Jo USDWs exp_ected inarea_(aquifers <;:3175' TYDJIl Moose's Tooth Cc!.!lculate >to,O_OO ppm._Se~_also "Sh_allow 20 _CMT v_ol adeQ~ateto çirc_ulate_o_n _col1ductor_ & SUJtC$g _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _y~s _ _ _ _ Sali[1itiesJlJthe NPRAArea" letterJep_ort from Arco dated 3l2l200t i[1 welJ file 2Q1,Q03). SfD _ _ _ _ _ _ _ 21 _CMT v_ol adeQ~ateto tie-inJongstri[1g tos.urf csg_ _ No_ _ _ _ _ _ _ J\rmutar disposal rny Þe proposed. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyeraJl koownpro_d.uctiye lJori~Olls_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23Casiog designs !,!d_eQuate for C,T, B&perrTJafr_ost _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 Mequ<ltetan_kage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ YJ:!s _ _ _ Rig js_e_q.uippe_d_with steel_pits. _ No reseJlle_pjt-planlJed. _DriUio9- wast to _dispos<lt weJls or_approye_d_ano~li. 25 Jta_ re-J:irilL has_ a tOA03 for <lbandOllment be~o apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 AJ:iequ<ltewellboresep!.!ratjo_n-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _YJ:!s_ _ _ _ _ _ _f\JeaJestweIL2)~miJe_s_awa}'(fishCre_ek), Ne¡,:¡restnewwelJ,Moose:s_Tooth_C_(3.3_miles)f\Joproximit}'problems, _ 27 Jtdiverter Jequired, does iLmeet reguJatioos_ _ _ _ YJ:!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 _DJillilJg flujd_program schem¡,:¡tic& equip JistadequatJ:!_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ:!s _ _ _ _ _ _ _ Expected BHF' 9.5 EMW aUD. Pla_noed_MW _9.8_ -9.9. Highec mud_ weight plal1n~d in8_-1J2"hole _due to_shales, _ 29 BOPEs, do they meet reguJatioo _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ:!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 _BOPE-PJess ratiog appropriate;testto(put psig in_commel1ts)_ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ:!s _ _ _ _ _ CalcuJatedMASP_ 3009 psi. 3500 psi_appropriate. CPAlususaJly tests Jo 5000 psi._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _CMke_rTJanjfold cQmpJies w/API RF'-53 (May 84) _ _ _ _ _ _ _ _ _ _ _ YJ:!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur withoutoperationshutdown_ _ _ _ _ _ YJ:!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Jspresence_ofH2Sg!,!s_prob_able_ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _tt2Swas_llotellco~nteJedontheotheJwelJsjl1theaœa._RigjseqUipped_with_sellsorsand!.!larrn_s._ _ _ __ 34 MecbanicaLcoodjUon of wells withil1 J\OR verified (forservicew~U onM _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 35 P~rmit cao be iss~ed w/o_ hydcogen_ s_ulfide meas_ures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ tt2S wasn9t obseryed_ io neaJbyMoose's Tooth_ C welt H2S sensors will_be utili~ed_ duriog driJling operatiolJs_. _ _ _ 36D_ata_PJeselJted Oil pote_ntial oyerpressurezOl1es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~L _ _ _ f\Jo sh_allow ha~ards are <l1Jt[cipated accocding Jo a sh_aUow ha~ard report su_brnjtted fOJ CarÞ0l11 (203-218). See 37S~ismic_an!.!lysjs_ of sbaJlow gas_zooes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ:!S _ _ _ _ Gœg Wilson, CPJ\I; f\Jo obvious gasilJdj~ators_ ilJ shaJlow portions ot3_D_data. 1L5/Q4SFD_ _ __ 38 _S~!.!bed _cOl1ditiOIJ survey Jif off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Conta_ct l1arne/phoneJor weekly progress reports [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ:!s _ _ _ Tom Brassfield 907.-265-637Z _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Date: Engineering Commissioner: Date H2S was not observed in the nearby (3 miles) Moose's Tooth C well. Scout 1 will be mudlogged, and H2S sensors will be utilized during drilling operations. Shallow hazards information presented in report contained in Carbon 1 well file (203-218). Shallow velocity data indicate slightly elevated pore pressures may exist below permafrost, but gradients should drop back to 9 ppg by 3000' MD. Pressure will rise again from normal at 6000' to 11.3 - 11.9 ppg at 8200' MD. Nearby Moose's Tooth C was drilled with max mud wt of 11,0 000. Public Commissioner Date V1)~ \~\ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. . . . Approved by: ¡f-Obl ~ fþY~1Þ- 20 c¡- ò6 b --- ConocJ'Phillips FINAL WELL REPORT SCOUT #1 CONOCOPHILLIPS ALASKA, INC. rco--'--'--"--l Compiled by: Barry Wright Fletcher England Date: 1 0/2312004 . 1. 1.1. 1.2. 2. 2.1. 2.2. 3. 3.1. 3.2. 3.3. 4. 4.1. 4.2. . 4.3. 4.4. 5. 5.1. 5.2. 5.3. Enclosures .,./ Col'1OCOPhillips Scout #1 SCOUT #1 Final Well Report TABLE OF CONTENTS MUDLOGGING EQUIPMENT & CREW .................................. ................................. 3 Equipment SUßIIII8ry ............................................................................................................................ 3 Crew ....... ..."".."......"".... ........... ..............."................... ....". ................... .... ....... ....... ... ............... ...""".... ..................... ........ ... 3 GEN ERAL WELL DETAilS..... ........ .... ... .... ....... ..... .... ...... ................ .............. ......11I..... 4 Objectives..............................................................................................................................................4 Well SUßIIII8ry .......................................................................................................................................4 GEOLOGICAL DATA... ................ ...................... ... .............. ....... ............. ..... ....... ......5 Lithostratigraphy .............................................. .................................................................................... 5 Mudlog Sumtnary .................................................................................................................................. 6 Sampling Program I Sample Dispatch...............................................................................................9 PRESSURE I FORMATION STRENGTH DA T A.................................................... 10 Formation IntegritylLeak Off Tests .................................................................................................. 10 Wireline Fonnation Tests ................................................................._................................................ 1 0 Pore Pressure Evaluatio:n Introduction ......................................................_.............._.._............... 1 0 Pore Pressure Summary ................................................................................................................... 11 DRilliNG DATA...... .................. ....... .................... .................. ..... ........ ........... ........ 12 SUNey Data .....................................................................................................................................·....12 Bit Record............................................................................................................................................15 Mud Record ........................................................................................................................................... 15 2" = 100' Scale Formation Log 2" = 100' Scale LWD I Lithology Log 2" = 100' Scale Drilling Dynamics Log 2" = 100' Scale Gas Ratio Log . 2 . . . "....,/ ConocóPhillips Scout #1 1. MUDLOGGING EQUIPMENT & CREW 1.1. EauiDment Summary Parameter Equipment Type / Position Total Comments Downtime OGM degasser (upstream flowline o hrs Ditch gas position) Flame ionization total & chromatograph detector Rate of penetration Primary drawworks block position (ROP) indicator Hydraulic head system on Ohrs mud house Pump stroke counter Magnetic proximity sensor o hrs (SPM) Hook Load (HL) I Weight Hydraulic pressure cell Ohrs on bit (WOB) Drill string torque (TRO) WITS feed from Totco - Unreliable; WITS signal fluctuating Top drive rotary (RPM) WITS feed from Totco Unable to transfer data - from WITS feed Standpipe pressure WITS feed from T otco - Unreliable; WITS signal (SPP) fluctuating Mud flow inlout MFI derived from SPMlMFO WITS Unable to transfer data (MFIIMFO) feed from T otco - from WITS feed Pit levels x 6 WITS feed from Totco - Unreliable; WITS signal fluctuating Mudlogging unit HP compaq Pentium 4 140 Gb PC - computer system 1.2. Crew Unit Type : Skid Unit Number : ML012 Da s 16 16 Technician Peter Ramse Years 3 3 *1 Years experience as Mudlogger "2 Days at wellsite between spud and total depth of well Additional Comments Technician required to rig up WITS feed while drilling the 121/4" hole section. Technician also on location at surface casing point to assist with gas equipment maintenance. 3 ~ ConocoPhillips Scout #1 2. GENERAL WELL DETAILS 2.1. Obiectives The Scout #1 well was planned as a vertical evaluation well to determine reservoir quality and productivity, and establish the hydrocarbon characteristics of the Upper Jurassic Alpine Sands equivalent. 22 WI S . . el ummarv Well Scout #1 AFE WCD.E02'x050 Classification Exploration License Rig Name I Doyon 1411 Arctic Suñace 70017' 15.00" N Water Depth NA RT Elevation 131.4' Tyoe Land Rig Co-Ordinates 151057' 33.012" W AMSL Primary Upper Jurassic Primary 7662' MDRT Secondary None Secondary N/A TarGet Alpine Sands TarGet Deoth (-7530' TVDSS) TarGet TarGet Deoth Spud Date 03/08/2004 TD Depth 8050' MDRT TD Formation Kingak TD Date 03/23/04 (-7917' TVDSS) Completion Suspended Suspension 03/28/04 Days Drilling 16 Days Testing 0 Status Date Hole Maximum Deoth Mud Weight Deviation Casing Shoe Deoth FIT MDRT rvDSS TD Formation Coring MDRT rvDSS Section (ft) (ft) (ppg) (oinc) ILiner (ft) (ft) (ppg) 20· 108' 23' 16" 108' 23' 12 1/4" 2444' -2313' Colville Group 10.3 0.31 - 9 5/8" 2437' -2306' 14.6 81/2" 7661' -7530' Miluveach Shale(LCU) 10.3-11.3 2.82 - 7" 7661' -7530' NA 7662'- - 61/8" 8050' -7917' Kingak Formation 9.8 2.54 7752' 4~ 8050' 7917'N NA A Additional Comments Problems with hole cleaning and packing off of clays at connections while drilling 12 %" hole section with 10.3 ppg PHPA mud system. Reduced ROP and pumped sweeps. Additional hole cleaning problems with clay balls while performing wiper trip after surface TD. Washed to bottom at increased GPM to ensure removal of clay balls. Continue hole cleaning problems with lost circulation and packing off of clay balls while performing wiper trips every +1- 1000' in 8 W hole section. Wiper trips required pumping out and circulating hole clean every 4-5 stands. Lost returns were encountered while running 7" casing. LCM was pumped and the casing was staged into the hole 3-6 joints at a time while circulating 3 BPM. A bottoms up was circulated every 6 joints to ensure hole stability. The HRZ with its corresponding high gamma signature was not present in the Scout 1 well. Hole essentially vertical to TD. 4 . . . . . . ~. ConocóPhillips Scout #1 3. GEOLOGICAL DATA 3.1. Lithostratiaraohv Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. FORMATION PROGNOSED DRILUNG PICK MDRT(ft) TVDSS(ft) MDRT(ft) TVDSS(ft) Base Permafrost 828 -750 -800 --669 (K-3) 2558 -2480 2637 -2506 Seq.97 3108 -3030 3150 -3019 Seq.95 3418 -3340 3496 -3365 Seq.93 3638 -3560 3652 -3521 Seq. 92 4643 -4565 4610 -4479 Base Ponded Turbidites 5858 -5780 5800 -5669 Pebble Shale Disturbed Zone Not Present Not Present Top HRZ 7293 -7215 Not Present Bottom HRZ 7333 -7255 Not Present Miluveach Shale (LCU) 7333 -7255 7321 -7190 UJUI Alpine Equivalent Sands 7623 -7545 7663 -7532 Base J4 Silt 7818 -7740 7800 -7669 Kingak Formation 7800 -7669 Total Depth 8068 -7990 8050 -7919 5 . . . ~ . ConocOPhlllips Scout #1 3.2. Mudloa Summary The following text provides a brief summary of the defining lithological and drilling characteristics for that part of the well over which drill cuttings were collected. For more detail the reader is referred to the 2"=100' scale mudlog included in this report. Colville Group First Returns 108' to 2637' MDRT (23' to -2506' TVDSS) Succession dominated by olive gray to brownish gray claystones with localized occurrence of tuffaceous ash, siltstone, very fine sand, and calcitic stringers. Sub-division of the interval is somewhat difficult because of similarities and thickness of claylclaystone units. Medium gray to dark gray claystones showing increased induration and incipient fissility begin to appear in samples below 2370' MDRT (-2239' TVDSS). Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 255 11 80 1.00 0.10 0.40 Torok Grouo 2637' to 7321' MORT (-2506' to -7190' TVOSS) Succession dominated by olive gray to brownish gray claystones with localized occurrence of tuffaceous ash, siltstone, and very fine sandstone. Overall, silts increased with depth. Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 210 28 85 1.02 0.02 0.26 Base Ponded Turbidites 5800' to 5900' MORT (-5669' to -5769' TVOSS) Light gray to brownish gray very fine sandstone. Grains ranged up to fine lower in size and were moderately well sorted with subangular to subround rounding. Cuttings were typically firm to firm friable with occasional hard, calcite cemented fragments. Sandstones were mostly clay matrix supported with +1- 10% grain support. The very fine grain size commonly graded to a sandy siltstone with claystone interbeds. Scattered aggregate pyrite was observed in samples. 20-60% dull to bright yellow sample fluorescence, increasing in occurrence and intensity with depth, was observed. Fluorescent cuttings exhibited an immediate pale white to yellow cut. Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 135 36 93 1.18 0.24 0.80 6 . . . "....,; ConocóPhillips Scout #1 HiahlY Radioactive Zone (HRZ) Not present in this well. UPPER JURASSIC Miluveach Shales 7321' to 7663' MDRT (-7190' to -7532' TVOSS) Section initially marked by small percentage (3-5%) of grayish red dolostone in sample at 7320' MORT (- 7189 TVDSS). Sequence is dominated by dark yellowish brown to dusky yellowish brown shale, with localized brownish gray to medium gray siltstone occurrences. Shales display poor to incipient fissility along subplanar partings. A 'silty bench' at the base of the Miluveach Shale was selected as the 7" casing point for this well. This siltstone, at approximately 7655' MDRT (7524' TVDSS), is characterized most notably by its high glauconite content and its corresponding overall moderate green to grayish green color. Also, the occurrence of two subsequent gas peaks were recorded; one smaller peak (71 units) at 7648' MORT (- 7517' TVDSS) and one larger peak (231 units) at 7659' MORT (-7528 TVDSS). Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 133 8 73 4.62 0.52 1.11 JURASSIC Jurassic Aloine Eauivalent Sands 7663' to 7786' MORT (-7532' to -7655' TVDSS) Dominantly grayish brown to moderate brown sandstone to silty sandstone. Top of section is medium to fine grained, but decreases to very fine with depth. Siltstone and silts overall increase downward. Occasional calcite fracture fill, pyrite burrow-fill, and below approximately 7680' MORT (7549' TVDSS) common (10- 20%) disseminated ultra fine glauconite grains. High gas throughout section, with a high of 2118 units (20.5% Methane Equivalent) at 7681' MORT (7550' TVDSS). Spotty dull yellow sample fluorescence, white to pale yellow cut fluorescence, and trace slow streaming cut. Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 129 12 52 20.50 0.18 18.70 ~ 7786' to 7800' MDRT (-7655' to -7669' TVDSS) Sequence dominated by moderate brown to dark reddish brown, siltstone and light brownish gray to brownish gray claystone. Siltstone cuttings noticeably more indurated than above and crumbly to slightly crunchy. Silty to gritty texture. No oil indicators observed. Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 138 108 126 17.80 4.04 10.20 7 . . . --/ Conoc:c)Phillips Scout #1 Kinaak Formation 7800' to 8050' MORT (-7669' to -7917' TVDSS) Olive black to olive gray carbonaceous shale with siltstone, claystone, and trace sandstone interbeds. Abundant disseminated microcrystalline pyrite in cuttings. Cuttings were typically massive in structure with occasional poorly developed fissility. Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 144 36 92 4.04 0.40 1.45 8 eonoc:ÓPhillips Scout #1 3 3 Samolina Prooram I Samole Disoatch . . . Set Type I Puroose Interval Freauency Dispatched to Unwashed Wet 108' - 7000' 30' Bayview Warehouse A Biostratigraphy 7000' - 8050' 10' 8105 Eleusis Drive Owner: CPAI Anchorage, AK 99502 Unwashed Wet 108' - 7000' 30' Bayview Warehouse B Biostratigraphy 7000' - 8050' 10' 8105 Eleusis Drive Owner: Anadarko Anchorage, AK 99502 Washed, screened & dried 108'- 30' Bayview Warehouse C Reference Samples 7000'7000' - 10' 8105 Eleusis Drive Owner: CPAI 8050' Anchorage, AK 99502 Washed, screened & dried 108'- 30' Bayview Warehouse D Reference Samples 7000'7000' - 10' 8105 Eleusis Drive Owner: CPAI (second set) 8050' Anchorage, AK 99502 Washed, screened & dried 450'- 30' Bayview Warehouse E Reference Samples 7000'7000' - 10' 8105 Eleusis Drive Owner: BLM 8050' Anchorage, AK 99502 Washed, screened & dried 108'- 30' Bayview Warehouse F Reference Samples 7000'7000' - 10' 8105 Eleusis Drive Owner: Anadarko 8050' Anchorage, AK 99502 Washed, screened & dried 108' - 7000' 30' Bayview Warehouse G Reference Samples 8105 Eleusis Drive Owner: State AOGCC 7000' - 8050' 10' Anchorage, AK 99502 Cali-Bond Gas Bags Bayview Warehouse H Gas Analysis 250' - 8000' 250'+ shows 8105 Eleusis Drive Owner: CPAI Anchorage, AK 99502 Samplex Trays, Bayview Warehouse I washed, screened 108' - 7000' 30' 8105 Eleusis Drive Reference Samples 7000' - 8050' 10' Anchorage, AK 99502 Owner: CPAI Bottled mud samples Bayview Warehouse J KI Core tracer analysis 7663' - 7752' Spot 8105 Eleusis Drive Owner: CPAI Anchorage, AK 99502 Unwashed, canned K Gas Hydrate Analysis 120' - 3000' 60' USGS Owner: USGS Core Chips Anadarko Petroleum Co. 1201 Lake Robbins Drive L Initial Core Analysis 7662' - 7752' 3' The Woodlands, TX Owner: CPAIIAnadarko 77380 Sample frequency was locally altered according to drillrate constraints. . 9 "....,~ ConocóPhillips Scout #1 · 4. PRESSURE I FORMATION STRENGTH DATA 4.1. Formation InteGrity/Leak Off Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). MDRT ft 2464' 7661' TVDSS ft -2333' FORMATION Lower Colville Group -7530' No test due to corin Miluveach Shales LOT (Leak Off Test) in emboldened italics. 4.2. Wireline Formation Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). TEST MDRT TVDSS EMW COMMENTS No. ft ft 1 7686.3 -7554.9 3744 9.39- Good Test Low Permeabir 2 7691.2 -7559.8 3726 9.34 Low Permeability 3 7700.3 -7568.9 Tite Tite Dry Test · 4.3. Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; Background Gas (BG) Mud Weight (MW) Pressure Tests (RFT) Connection Gas (CG) Hole Conditions (HC) Trip Gas (TG) Resistivity (RES) Quantitative Methods During the well quantitative estimation was limited to the following parameters; Corrected D exponent (DXC) Pressure Tests (MDT) Sonic (SON) CMR VSP Pressure tests provide the most definitive data. However, it is considered that estimates derived using Eaton Method calculations on corrected D exponent and Sonic data are also representative at certain levels. Results Summary Final wellsite derived pore pressure evaluation is summarized in table form (Section 4.4) and graphical format (Figure *). Certain abbreviations have been used, all of which are outlined either above or below. · HYD = Hydrostatic pressure SST = Sandstone EXTRAP = Extrapolated SHL = Shale CLST = Claystone SL TST = Siltstone 10 ConocóPt·tillips Scout #1 4.4. Pore Pressure Summary . Equivalent mud weight (EMW) is calculated from rotary table (RT). Formation Primary Interval Toos Pore Pressure (EMM Trend Source of MDRT TVDSS Min Max Quantitative Interval Lithology (ft) (ft) (OOG) (OOG) Trend Indicators Estimate Base Permafrost CLST 108 -23 8.4 8.4 - BG HYD Colville Group CLST 108 -23 8.4 8.6 - BG MW (K-3) CLST 2637 -2506 8.5 8.7 +ve BG MW SeQ.97 SST/SL TST 3150 -3019 8.5 8.7 - BG MW SeQ.95 SSTISL TST 3496 -3365 8.6 8.8 +ve BG MW SeQ.93 SSTISL TST 3652 -3521 8.7 8.9 +ve BG MW SeQ.92 SST/SL TST 4610 -4479 8.7 8.9 - BG MW Base Ponded SST 5800 -5669 8.8 9.0 BG MW Turbidites - Miluveach Shale SHL 7321 -7190 9.0 9.2 +ve BG MW (LCU) UJUI Alpine BG,TG, Equivalent SST 7663 -7532 9.2 9.4 +ve MDT MDT Sands Base J4 Silt SLTST 7800 -7669 9.1 9.3 -ve BG MW Kingak SHUCLST 7800 -7669 9.0 9.2 - BG MW Formation Total Depth , SHUCLST 8050 -7917' 9.0 9.2 - BG MW Refer to Section 4.3 for explanation of abbreviations used. . The following text highlights key details of the final wellsite assessment of the pore pressure profile Normal pore pressures (8.4ppg to 9.0ppg EMW) are maintained until approximately 7321 ft MORT at which point levels of background gas incur a slight increase. Unfortunately the inability to construct normal compaction trends for DXC, does not permit the quantitative estimation of pore pressure. A maximum value of 9.2ppg EMW has been estimated primarily on the basis of lack of connection gas with a mud weight of 11.3ppg and absence of hole instability. This value may be a maximum. Pore pressures, at intervals between 7663 ft MDRT and 7691 ft MDRT, have been accurately measured by MDT pressure tests to values between 9.3 and 9.4. This maximum value is considered to be maintained until approximately 8050 ft MDRT on the basis of an apparent normal compaction trend for sonic transit times, lack of connection gas and absence of any increasing trend in the normaflZed drill gas. . 11 ---/ ConocOPhillips Scout #1 . 5. DRlLUNG DATA 51 S D . . . urvev ata Depth Inclination Azimuth TVD NIS E/W Section DogLeg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (dphf) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE-IN 195.24 0.00 0.00 195.24 0.00 0.00 0.00 0.00 280.43 0.06 311.03 280.43 0.03 -0.03 0.03 0.07 376.18 0.2 21.35 376.18 0.22 -0.01 0.22 0.19 465.79 0.25 321.08 465.79 0.51 -0.08 0.51 0.26 557.08 0.25 319.67 557.08 0.82 -0.34 0.82 0.01 649.50 0.31 15.31 649.50 1.21 -0.40 1.21 0.29 741.67 0.17 12.85 741.67 1.59 -0.30 1.59 0.15 831.16 0.28 323.06 831.16 1.89 -0.40 1.89 0.24 922.55 0.28 323.87 922.54 2.25 -0.67 2.25 0.00 1015.74 0.31 358.61 1015.73 2.68 -0.80 2.68 0.19 1108.46 0.14 350.60 1108.45 3.04 -0.83 3.04 0.19 1200.63 0.25 306.41 1200.62 3.27 -1.01 3.27 0.20 1294.13 0.28 354.84 1294.12 3.62 -1.20 3.62 0.23 1385.43 0.31 299.97 1385.42 3.96 -1.43 3.96 0.30 1479.10 0.31 333.18 1479.09 4.32 -1.77 4.32 0.19 1572.31 0.31 331.07 1572.30 4.76 -2.00 4.76 0.01 1665.03 0.31 330.96 1665.02 5.20 -2.24 5.20 0.00 1757.36 0.17 324.47 1757.35 5.53 -2.45 5.53 0.15 1850.22 0.06 333.43 1850.21 5.69 -2.55 5.69 0.12 1942.41 0.25 267.49 1942.40 5.73 -2.77 5.73 0.25 2036.47 0.28 287.00 2036.45 5.79 -3.19 5.79 0.10 2129.27 0.25 275.8 2129.25 5.87 -3.61 5.87 0.06 2221.98 0.36 324.45 2221.96 6.13 -3.98 6.13 0.29 2314.5 0.31 334.24 2314.48 6.59 -4.26 6.59 0.08 2373.43 0.25 311.54 2373.41 6.82 -4.43 6.82 0.21 2536.6 0.33 308.88 2536.58 7.35 -5.06 7.35 0.05 2630.05 0.70 323.69 2630.02 7.98 -5.61 7.98 0.42 2721.98 0.63 305.91 2721.95 8.73 -6.35 8.73 0.24 2816.2 0.56 331.72 2816.16 9.44 -6.99 9.44 0.29 2909.02 0.44 311.24 2908.98 10.07 -7.47 10.07 0.23 3002.1 0.38 315.16 3002.06 10.52 -7.95 10.52 0.07 3095.43 0.45 308.08 3095.38 10.96 -8.45 10.96 0.10 3188.65 0.53 333.38 3188.6 11.59 -8.93 11.59 0.24 3282.46 0.50 343.09 3282.41 12.35 -9.24 12.35 0.10 . 12 . . . "....,/ ConocOPhillips Scout #1 Depth Inclination Azimuth TVD NIS EIW Section DogLeg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (dphf) 3375.51 0.66 0.18 3375.45 13.27 -9.36 13.27 0.25 3468.33 0.67 358.53 3468.27 14.34 -9.37 14.34 0.02 3563.03 0.25 123.63 3562.96 14.77 -9.21 14.77 0.89 3656.29 0.25 165.09 3656.22 14.46 -8.99 14.46 0.19 3749.93 0.22 182.07 3749.86 14.09 -8.94 14.09 0.08 3843.42 0.22 206.48 3843.35 13.74 -9.03 13.74 0.10 3936.55 0.38 162.96 3936.48 13.29 -9.02 13.29 0.28 4030.01 0.47 156.68 4029.94 12.64 -8.78 12.64 0.11 4121.97 0.37 146.55 4121.90 12.09 -8.47 12.09 0.14 4215.62 0.31 229.30 4215.54 11.63 -8.49 11.63 0.48 4309.13 0.31 230.65 4309.05 11.31 -8.88 11.31 0.01 4402.24 0.50 242.39 4402.16 10.96 -9.44 10.96 0.21 4495.7 0.45 236.66 4495.62 10.57 -10.1 10.57 0.07 4589.28 0.83 241.34 4589.19 10.04 -11.00 10.04 0.41 4683.22 0.39 161.13 4683.13 9.41 -11.5 9.41 0.91 4776.41 0.76 134.47 4776.31 8.67 -10.95 8.67 0.48 4870.27 0.51 138.24 4870.17 7.93 -10.23 7.93 0.27 4963.93 0.33 155.11 4963.82 7.37 -9.84 7.37 0.23 5055.95 0.09 145.83 5055.84 7.11 -9.69 7.11 0.27 5149.79 0.12 154.15 5149.68 6.92 -9.60 6.92 0.04 5243.34 0.25 170.78 5243.23 6.62 -9.52 6.62 0.15 5336.91 0.20 192.81 5336.80 6.26 -9.53 6.26 0.11 5430.33 0.14 266.23 5430.22 6.10 -9.67 6.10 0.22 5523.48 0.25 203.63 5523.37 5.90 -9.87 5.90 0.24 5616.69 0.26 238.81 5616.58 5.60 -10.13 5.60 0.17 5711.03 0.31 253.82 5710.92 5.42 -10.56 5.42 0.09 5804.92 0.31 261.59 5804.81 5.31 -11.06 5.31 0.05 5898.21 0.35 218.39 5898.10 5.05 -11 .49 5.05 0.26 5991.29 0.06 184.61 5991.18 4.78 -11 .67 4.78 0.32 6084.61 0.19 81.78 6084.50 4.81 -11.53 4.81 0.22 6177.44 0.09 170.59 6177.33 4.70 -11.37 4.70 0.22 6271.07 0.12 23.59 6270.96 4.72 -11.31 4.72 0.22 6364.14 0.28 46.14 6364.03 4.97 -11.11 4.97 0.18 6457.43 0.38 12.39 6457.31 5.43 -10.88 5.43 0.23 6551.45 0.74 19.65 6551.33 6.3 -10.61 6.3 0.40 13 · · · ~. ConocOPhillips Scout #1 Depth Inclination Azimuth TVD NIS EIW Section DogLeg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (dphf) 6644.52 0.74 33.39 6644.39 7.37 -10.08 7.37 0.19 6831.09 1.02 43.16 6830.94 9.59 -8.28 9.59 0.17 6924.02 1.05 50.78 6923.85 10.73 -7.06 10.73 0.15 7017.73 1.19 57.24 7017.55 11.8 -5.58 11.80 0.20 7071.49 1.22 54.35 7071.29 12.49 -4.64 12.49 0.13 7118.74 1.47 51.07 7118.53 13.1 -3.77 13.1 0.56 7213.22 2.77 50.44 7212.95 15.31 -1.07 15.31 1.37 7306.63 3.45 50.35 7306.22 18.55 2.84 18.55 0.74 7399.77 3.52 52.93 7399.18 22.06 7.28 22.06 0.18 7494.42 3.14 54.88 7493.67 25.3 11.72 25.3 0.41 7588.41 3.09 56.59 7587.53 28.18 15.94 28.18 0.11 7626.74 2.82 58.18 7625.80 29.25 17.61 29.25 0.75 7696.17 2.98 58.78 7695.15 31.08 20.6 31.08 0.24 7790.09 3.07 56.66 7788.93 33.73 24.79 33.73 0.15 7884.00 2.80 56.83 7882.72 36.43 28.8 36.43 0.28 7975.86 2.54 63.15 7974.48 38.51 32.5 38.51 0.43 8050.00 2.54 63.15 8048.55 40.00 35.43 40.00 0.00 14 ConocJ'Phillips Scout #1 Bit Jets I TFA Wear BHA IRun 1/1 2x16, 1x18, 1-1-WT -A-O-I-NO- TD ROT 1x12 10.752 2 5x15 10.863 1-1-WT-G-D-I-NO-BHA ROT 2RR 5x15/0.863 1-1-WT -G-D-I-NO- TD ROT 3 3x20 I 0.920 1-1-WT -A-E-I-NO- TD ROT 1C Core Not Available ROT 4 5x15 10.863 -NO-A-D-I-NO- TD ROT Gels 8-13/11-18/13-20 5-14/10-29/14-32 4-6/7-1119-15 4-7/7-15/9-21 Abbreviations MW = Mud Weight ECD = Effective Circulating Density FC = Filter Cake Sols = Solids Gels = 30 sec & 30 minute FL = Water or Filtrate Loss Tot CI = Total Chlorides. YP = Yield Point . Sd VIS PV OIW OIW Ratio 2190 1-2//87-90 190 tr/90 = Sand content = Funnel Viscosity = Plastic Viscosity = Oil to Water ratio . 15 . I I I I I I I I I I I I I I I I I I I Core Lab RESERVOIR OPTIMIZATION AOGt~ CORE LABORATORIES fCONFIDENTÏÃil ~ ~ v --- a Q \ç CORE ANALYSIS RESULTS CONOCOPHILLlPS ALASKA, INC. SCOUT #1 WELL COLVILLE RIVER FIELD CL FILE 57111-104084 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (661) 392-8600 I I I I I I I I I I I I I I I I I I I Petroleum Services Division 3430 Unicorn Road Bakersfield, California 93308 Tel: 661-392-8600 Fax: 661-392-0824 www.corelab.com e Core Lab RESERVOIR OPTIMIZATION Andreas Andreou ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 July 8, 2004 Subject: Transmittal of Conventional Core Analysis Data Scout 1 Well Colville River Field CL File No. 57111-10484 Dear Mr. Andreou: Core Laboratories field personnel provided handling services for conventional aluminum inner-barrel cores recovered from the subject well. Upon completion of coring, the recòvered core was packaged and shipped to our Anchorage, Alaska laboratory for initial processing. Upon arrival at the laboratory the core was scanned for natural gamma radiation. The scanned core was removed from the aluminum barrels, sample segments were set aside, and the remaining core was slabbed using a one-quarter/three-quarter cut. The one-quarter slabs were mounted in slab boxes for photography and description, and the three-quarter sections were wrapped with Saran and foil, dipped in Core Seal and boxed. Horizontal and vertically oriented plug samples were drilled from each of the set- aside sample segments for shipment to our Bakersfield, California laboratory for analysis. Slabbing and plug drilling was performed using Isopar as the coolanUlubricant. The one-third slabbed core was photographed under white light and ultra-violet light for presentation with our Core Viewer. Both the horizontally and vertically oriented samples were analyzed by Dean-Stark methods. Porosity and permeability were determined using the CMS-300 automated core measurement system. Alternate vertical plugs were crushed and leached for KI (potassium iodide) tracer analysis. Analysis of the tracer extracts was performed by Metrohm-Peak. Core and sample remnants were sent to ConocoPhil/ips' Bayview Geological Facility in Anchorage, Alaska. Remaining tracer extract was forwarded by Metrohm-Peak to ConocoPhillips in Bartlesville Oklahoma. We appreciate this opportunity to have been of service and look forward to working with you again in the future. ;j Distribution: 1 Core Book, 1 CD : addressee CLB IDl\III NY.5E ------------------- Conoco Phillips Alaska Location: Sec 20-11N-1E UM File No.: 57111·104084HCP Scout 1 Elevation: API No.: 50 -103 - 20479 Core LaI:i Colville River Field Drlg Fluid: Gel Date: 26 - April- 2004 Horizontal Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Den ft md % % % glee 1 7662.3 0.04 14.9 22.4 27.7 0.81 50.1 2.68 (4) Sst gry-ltan vfgr vs1ty lsp stn wh-g1d flor 2 7663.3 0.04 12.7 20.7 33.6 0.62 54.3 2.67 (4) Sst gry-1tan vfgr vslty lsp stn wh-gld flor 3 7664.3 0.02 10.9 17.2 50.5 0.34 67.7 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 4 7665.4 0.04 12.6 16.8 36.1 0.46 52.8 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 5 7666.3 0.04 11.7 19.9 43.8 0.45 63.7 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 6 7667.3 0.03 12.7 20.1 36.4 0.55 56.5 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 7 7668.3 0.03 11.7 18.1 44.0 0.41 62.2 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 8 7669.3 0.02 11.7 14.1 45.2 0.31 59.3 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 9 7670.3 0.03 13.2 16.4 35.6 0.46 52.0 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 10 7671.4 0.02 11.5 15.1 47.0 0.32 62.1 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 11 7672.3 0.03 12.8 15.7 40.6 0.39 56.3 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 12 7673.3 0.04 11.8 16.4 44.8 0.37 61.2 2.68 (4) Sst gry-1tan vfgr vslty Isp stn wh-gld flor 13 7674.2 0.05 12.3 16.0 42.5 0.38 58.5 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-g1d flor 14 7675.3 0.05 12.8 24.2 30.7 0.79 54.9 2.67 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 15 7676.2 0.02 10.3 22.1 47.5 0.47 69.7 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 16 7677.3 0.03 11.4 18.8 43.0 0.44 61.8 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 17 7678.4 0.07 8.7 27.0 46.9 0.58 73.9 2.68 (4) Sst gry-ltan vfgr vs1ty Isp stn wh-gld flor 18 7679.3 0.05 8.0 18.5 66.4 0.28 85.0 2.69 (4) Sst gry-1tan vfgr vslty lsp stn wh-gld flor 19 7680.4 0.03 9.2 27.8 48.3 0.58 76.1 2.69 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 20 7681.4 0.07 12.5 26.7 28.5 0.94 55.2 2.68 (4) Sst gry~ltan vfgr vslty Isp stn wh-gld flor 21 7682.3 0.16 14.5 20.1 23.3 0.86 43.4 2.67 (4) Sst gry-ltan vfgr v~lty Isp stn wh-gld flor 22 7683.3 0.38 15.5 15.3 24.0 0.63 39.3 2.67 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 23 7684.3 0.47 15.3 16.3 33.0 0.49 49.3 2.66 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 24 7685.3 0.28 14.2 0.0 43.3 0.00 43.3 2.67 (3) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 25 7686.3 0.10 11.6 0.0 49.6 0.00 49.6 2.67 (3) Sst gry-ltan vfgr vslty Isp stn wh-gld flor ------------------- Conoeo Phillips Alaska Location: Sec 20-11N-1E UM File No.: 57111-104084HCP Scout 1 Elevation: API No.: 50 - 103 - 20479 Core Lab Colville River Field Drlg Fluid: Gel Date: 26 - April - 2004 Horizontal Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Total Den ft md % % % glee 26 7687.3 0.33 15.8 0.0 41.7 0.00 41.7 2.67 (3) Sst gry-1tan vfgr vslty lsp stn wh-g1d flor 27 7688.3 0.73 15.5 14.0 32.5 0.43 46.5 2.67 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 28 7689.3 0.13 14.4 16.5 25.0 0.66 41.5 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 29 7690.3 0.07 12.4 0.0 48.4 0.00 48.4 2.67 (3) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 30 7691.3 0.07 12.6 0.0 47.5 0.00 47.5 2.67 (3) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 31 7692.3 0.10 15.0 0.0 39.4 0.00 39.4 2.67 (3) Sst gry-1tan vfgr vslty lsp stn wh-g1d flor 32 7693.3 0.06 13.8 14.8 30.3 0.49 45.2 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 33 7694.3 0.06 13.2 25.5 31.7 0.80 57.1 2.66 (4) Sst gry-1tan vfgr vslty lsp stn wh-g1d flor 34 7695.3 0.06 12.2 0.0 48.1 0.00 48.1 2.68 (3) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 35 7696.3 0.04 11.7 17.6 38.4 0.46 56.0 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 36 7697.3 0.05 13.6 16.2 30.9 0.53 47.1 2.67 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 37 7698.3 0.20 19.4 17.5 23.3 0.75 40.8 2.70 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-gld flor 38 7699.3 0.04 13.4 15.9 33.4 0.48 49.3 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 39 7700.3 0.03 10.5 15.3 48.9 0.31 64.1 2.68 (4) Sst gry-1tan vfgr vslty lsp stn wh-g1d flor 40 7701.3 0.03 13.3 16.3 34.9 0.47 51.2 2.68 (4) Sst gry-1tan vfgr vsIty lsp stn wh-g1d flor 41 7702.3 0.03 12.9 18.4 34.6 0.53 52.9 2.68 (4) Sst gry-1tan vfgr vslty lsp stn wh-g1d flor 42 7703.3 0.02 11.3 17.3 45.5 0.38 62.8 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 43 7704.3 0.03 12.7 16.9 37.3 0.45 54.2 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 44 7705.6 0.04 9.8 17.6 58.2 0.30 75.8 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-g1d flor 45 7706.3 0.07 14.2 17.9 30.5 0.59 48.4 2.68 (4) Sst gry~ltan vfgr vslty lsp stn wh-gld flor 46 7707.3 0.11 15.0 18.6 28.1 0.66 46.8 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 47 7708.3 0.05 12.8 19.5 35.9 0.54 55.4 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 48 7709.3 0.06 13.9 20.7 31.0 0.67 51.7 2.68 (4) Sst gry-1tan vfgr vs1ty lsp stn wh-g1d flor 49 7710.3 0.06 14.6 20.9 29.0 0.72 49.8 2.68 (4) Sst gry-ltan vfgr vsity lsp stn wh-g1d flor 50 7711.3 0.06 12.6 0.0 53.2 0.00 53.2 2.68 (3) Sst gry-ltan vfgr vs1ty lsp stn wh-g1d flor ------------------- Conoco Phillips Alaska Location: Sec 20-11N-1E UM File No.: 57111-104084HCP Scout 1 Elevation: API No.: 50 - 103 - 20479 Colville River Field Drlg Fluid: Gel Date: 26 - April - 2004 Horizontal Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Total Den ft md % % % glee 51 7712.3 0.07 13.2 0.0 47.8 0.00 47.8 2.68 (3) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 52 7713.3 0.07 12.1 0.0 48.6 0.00 48.6 2.71 (3) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 53 7714.3 0.04 11.9 0.0 56.3 0.00 56.3 2.68 (3) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 54 7715.3 0.03 11.7 19.9 40.3 0.49 60.2 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 55 7716.3 0.03 9.5 20.8 55.2 0.38 75.9 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 56 7717.3 0.02 9.2 15.6 60.4 0.26 76.0 2.69 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 57 7718.3 0.03 8.8 17.7 63.8 0.28 81.5 2.69 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 58 7719.3 0.02 8.5 14.8 68.0 0.22 82.8 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 59 7720.3 0.01 9.7 19.7 52.6 0.37 72.3 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 60 7721.3 0.02 10.7 22.9 45.9 0.50 68.8 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 61 7722.3 0.02 10.8 19.6 47.7 0.41 67.4 2.67 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 62 7723.4 0.01 10.1 27.1 47.4 0.57 74.5 2.69 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 63 7724.3 0.09 7.0 22.7 73.6 0.31 96.3 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 64 7725.4 0.01 9.4 24.4 47.5 0.51 71.9 2.67 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 65 7726.4 0.02 12.8 22.6 38.4 0.59 61.1 2.73 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 66 7727.3 0.07 7.8 16.4 70.5 0.23 86.9 2.69 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 67 7728.3 0.12 7.4 15.7 73.6 0.21 89.3 2.70 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 68 7729.4 0.02 10.0 19.8 48.5 0.41 68.3 2.67 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 69 7730.3 0.02 11.3 21.3 38.2 ·0.56 59.5 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 70 7731.4 0.02 10.7 19.8 43.7 0.45 63.4 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 71 7732.4 0.02 9.5 46.4 31.7 1.47 78.1 2.68 (4) Sst gry-ltan vfgr vßlty Isp stn wh-gld flor 72 7733.3 0.01 7.9 14.7 67.3 0.22 82.0 2.68 (4) Sst gry-Itan vfgr vslty Isp stn wh-gld flor 73 7734.3 0.02 10.9 20.9 42.5 0.49 63.4 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 74 7735.3 0.04 10.3 23.0 46.8 0.49 69.9 2.68 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor 75 7736.3 0.01 10.0 26.8 45.7 0.59 72.5 2.69 (4) Sst gry-ltan vfgr vslty Isp stn wh-gld flor ------------------- Conoco Phillips Alaska Location: Sec 20-11N-1E UM File No.: 57111-104084HCP Scout 1 Elevation: API No.: 50 - 103 - 20479 !:ore Lab Colville River Field Drlg Fluid: Gel Date : 26 - April- 2004 Horizontal Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Total Den ft md % % % glee 76 7737.3 0.02 10.9 23.8 44.5 0.54 68.3 2.67 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 77 7738.4 0.03 12.3 23.3 37.6 0.62 60.8 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 78 7739.3 0.03 12.3 22.8 37.7 0.60 60.4 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 79 7740.3 0.02 12.1 27.7 34.1 0.81 61.8 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 80 7741.4 0.02 11.4 28.5 36.9 0.77 65.4 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 81 7742.3 0.02 10.0 25.8 47.9 0.54 73.7 2.69 (4) Sst gry-ltan vfgr vsIty lsp stn wh-gld flor 82 7743.3 0.04 9.1 19.6 61.5 0.32 81.1 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 83 7744.4 0.01 6.7 14.6 80.6 0.18 95.3 2.69 (4) Sst gry-ltan vfgr vsIty lsp stn wh-gld flor 84 7745.3 0.01 7.9 21.8 59.8 0.36 81.6 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 85 7746.3 0.02 9.4 25.8 52.0 0.50 77.8 2.69 (4) Sst gry-ltan vfgr vsIty lsp stn wh-gld flor 86 7747.4 0.02 9.0 25.5 54.9 0.47 80.4 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 87 7748.3 0.02 10.0 24.4 45.5 0.54 69.9 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 88 7749.3 0.04 12.9 30.9 26.0 1.18 56.9 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 89 7750.3 0.02 11.1 40.4 34.3 1.18 74.7 2.68 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 90 7751.7 0.15 11.7 42.1 38.1 1.11 80.2 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor 91 7752.6 F/0.75 12.2 49.0 38.0 1.29 87.0 2.69 (4) Sst gry-ltan vfgr vslty lsp stn wh-gld flor F/ Indicates Visible Fracture(s) Present ------------------- ~ &\ Core Lab Conoco Phillips Alaska Scout 1 Colville River Field Location: Sec 20-l1N-1E UM Elevation: Drlg Fluid: Gel File No.: 57111-104084HCP API No.: 50 - 103 - 20479 Date: 26 - April - 2004 Vertical Core Analysis Results Sample Depth Perm. Porosity Fluid Saturation Grain Mthd Description No. Kair Oil I Water I OIW I Total Den ft md % % % Ratio % glee 1 7662.0 0.06 12.6 25.7 37.6 0.68 63.3 2.68 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 2 7663.0 0.02 12.4 24.1 37.5 0.64 61.6 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 3 7664.0 0.05 12.2 20.5 41.3 0.50 61.8 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 4 7665.0 0.02 11.6 23.1 43.1 0.53 66.2 2.68 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 5 7666.0 0.05 12.0 18.0 44.3 0.41 62.3 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 6 7667.0 0.03 12.0 23.0 39.8 0.58 62.8 2.68 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 7 7668.0 0.05 12.0 16.9 44.9 0.38 61.8 2.70 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 8 7669.0 0.02 10.5 19.5 51.5 0.38 71.1 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 9 7670.0 0.07 14.2 15.5 32.8 0.47 48.3 2.68 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 10 7671.0 0.02 11.6 21.7 46.9 0.46 68.6 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 11 7672.0 0.05 13.1 16.9 39.2 0.43 56.1 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 12 7673.0 0.02 12.5 19.4 39.3 0.50 58.7 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 13 7674.1 0.06 12.8 15.6 38.4 0.41 54.0 2.69 (4) 5st gry-tan vfgr vslty I-msp stn wht-gld flor 14 7675.0 0.05 13.6 17.6 34.7 0.51 52.3 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 15 7676.0 0.05 11.0 29.2 40.6 0.72 69.8 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 16 7677.0 0.03 13.1 19.2 39.3 0.49 58.4 2.70 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 17 7678.0 0.03 11.3 4.4 47.2 0.09 51.6 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 18 7679.0 0.02 9.0 26.1 51.3 0.51 77.4 2.70 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 19 7680.0 0.06 10.5 19.9 46.1 0.43 66.0 2.70 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 20 7681.0 0.03 11.1 20.1 45.3 0.44 65.3 2.69 (4) Sst gry~tan vfgr vslty I-msp stn wht-gld flor 21 7682.0 0.13 14.1 19.2 24.5 0.79 43.7 2.67 (4) Sst gry-tan vfgr v~lty I-msp stn wht-gld flor 22 7683.0 0.32 14.9 17.2 23.4 0.73 40.7 2.67 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 23 7684.0 0.22 16.1 24.8 14.6 1.70 39.4 2.67 (4) Sst gry-tan vfgr vslty I-msp sm wht-gld flor 24 7685.0 0.14 14.5 18.8 22.6 0.83 41.4 2.67 (4) Sst gry-tan vfgr vslty I-msp sm wht-gld flor 25 7686.0 0.09 13.0 19.8 33.2 0.60 53.1 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor ------------------- ~ Conoco Phillips Alaska Location: Sec 20-11N-1E UM File No.: 57111-104084HCP ~: %; Scout 1 Elevation: API No.: 50 - 103 - 20479 ~41 Colville River Field Drlg Fluid: Gel Date: 26 - April - 2004 Core LaIÍ Vertical Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Total Den ft md % % % glee 26 7687.0 0.12 14.7 22.2 22.6 0.98 44.9 2.67 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 27 7688.0 F/14.54 16.7 19.5 25.4 0.77 44.9 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 28 7689.0 0.31 15.5 20.8 22.2 0.94 43.0 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 29 7690.0 0.04 12.5 18.0 33.6 0.53 51.6 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 30 7691.0 0.06 13.8 19.2 31.0 0.62 50.2 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 31 7692.0 0.11 15.6 16.6 22.5 0.74 39.1 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 32 7693.0 0.05 14.9 17.4 30.2 0.58 47.6 2.71 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 33 7694.0 0.06 14.4 25.5 22.3 1.15 47.8 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 34 7695.0 0.06 13.3 21.6 26.4 0.82 48.0 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 35 7696.0 0.03 12.4 17.9 38.0 0.47 55.9 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 36 7697.0 0.04 14.3 22.1 28.5 0.77 50.6 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 37 7698.0 0.16 19.8 21.1 18.5 1.14 39.6 2.71 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 38 7699.0 0.02 13.6 18.8 32.8 0.57 51.6 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 39 7700.0 0.02 11.8 19.7 39.2 0.50 59.0 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 40 7701.0 0.03 12.3 21.1 38.7 0.55 59.8 2.78 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 41 7702.0 0.04 13.7 20.7 30.6 0.68 51.3 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 42 7703.0 0.02 12.6 20.6 38.4 0.53 59.0 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 43 7704.0 0.02 12.2 18.4 39.1 0.47 57.5 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 44 7705.1 0.02 9.7 28.2 48.0 0.59 76.2 2.70 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 45 7706.0 0.06 13.5 21.3 31.3 0.68 52.6 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 46 7707.0 0.10 15.0 22.9 25.0 0.91 47.9 2.68 (4) Sst gry-tan vfgr v~lty I-msp sm wht-gld flor 47 7708.0 0.06 13.5 20.4 33.8 0.60 54.2 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 48 7709.0 0.06 14.2 23.0 28.3 0.81 51.3 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 49 7710.0 0.02 14.1 28.9 24.8 1.17 53.7 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 50 7711.0 0.04 12.7 22.7 35.5 0.64 58.2 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor ------------------- Conoco Phillips Alaska Location: Sec 20-11N-IE UM File No.: 57111-104084HCP Scout 1 Elevation: API No.: 50 -103 - 20479 Core Lati Colville River Field Drlg Fluid: Gel Date: 26 - April - 2004 Vertical Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Total Den ft md % % % glee 51 7712.0 0.02 13.2 26.9 29.6 0.91 56.5 2.68 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 52 7713.0 0.03 12.9 23.6 29.8 0.79 53.4 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 53 7714.0 0.02 12.7 24.2 33.5 0.72 57.7 2.69 (4) Sst gry-tan vfgr vslty 1-msp stn wht-g1d flor 54 7715.0 0.02 11.3 40.6 30.7 1.32 71.3 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 55 7716.0 0.02 10.3 24.0 48.3 0.50 72.3 2.70 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 56 7717.0 0.01 9.9 22.0 53.6 0.41 75.7 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 57 7718.0 0.02 9.3 57.4 26.9 2.14 84.3 2.69 (4) Sst gry-tan vfgr vs1ty I-msp stn wht-gld flor 58 7719.0 0.01 9.2 34.3 48.0 0.71 82.3 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 59 7720.0 0.01 9.6 28.7 48.4 0.59 77.1 2.71 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 60 7720.9 0.02 11.1 24.8 43.7 0.57 68.5 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 61 7722.0 0.02 10.8 32.5 41.0 0.79 73.5 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 62 7723.0 0.02 10.8 23.8 47.0 0.51 70.8 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 63 7724.0 0.01 7.3 15.0 77.9 0.19 92.9 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 64 7725.0 0.02 9.0 24.1 55.3 0.44 79.5 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 65 7726.0 0.02 9.4 23.3 51.9 0.45 75.2 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-gld flor 66 7727.0 0.02 8.0 33.5 54.5 0.61 88.0 2.69 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 67 7728.0 0.01 8.4 23.4 60.1 0.39 83.6 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 68 7729.0 0.02 10.1 24.2 46.6 0.52 70.8 2.67 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 69 7730.0 0.01 12.0 22.4 34.8 0.64 57.2 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 70 7731.0 0.02 12.3 24.0 34.5 0.70 58.5 2.68 (4) Sst gry~tan vfgr vslty I-msp stn wht-gld flor 71 7732.0 0.02 9.7 22.5 49.8 0.45 72.3 2.69 (4) Sst gry-tan vfgr v~lty I-msp stn wht-gld flor 72 7733.0 0.01 9.0 22.5 55.8 0.40 78.3 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 73 7734.0 0.01 10.8 23.4 41.8 0.56 65.2 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 74 7735.0 0.02 11.6 28.2 37.7 0.75 65.9 2.69 (4) Sst gry-tan vfgr vs1ty I-msp stn wht-gld flor 75 7736.0 0.01 10.9 47.7 23.7 2.01 71.4 2.70 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor ------------------- Conoco Phillips Alaska Location: Sec 20-11N-1E UM File No.: 57111-104084HCP Scout 1 Elevation: API No.:, 50 -103 - 20479 Core Lab Colville River Field Drlg Fluid: Gel Date: 26 - April- 2004 Vertical Core Analysis Results Sample Depth Perm. Porosity Grain Mthd Description No. Kair Oil Total Den ft md % % % glee 76 7737.0 0.02 11.4 61.6 11.2 5.48 72.8 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 77 7738.0 0.01 12.1 29.9 32.3 0.93 62.2 2.68 (4) Sst gry-tan vfgr vslty I-msp stn wht-gld flor 78 7739.0 0.02 12.6 30.3 33.4 0.91 63.7 2.68 (4) Sst gry-tan vfgr vslty l-msp stn wht-gld flor 79 7740.0 0.01 12.0 25.4 33.4 0.76 58.8 2.70 (4) Sst gry-tan vfgr vslty l-msp stn wht-gld flor 80 7741.0 0.02 11.1 29.9 41.9 0.71 71.8 2.68 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 81 7742.0 0.02 11.2 43.6 23.6 1.84 67.2 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wht-g1d flor 82 7743.0 0.01 9.8 27.4 51.7 0.53 79.1 2.70 (4) Sst gry-tan vfgr vs1ty l-msp stn wht-g1d flor 83 7744.0 0.01 7.8 16.6 62.9 0.26 79.5 2.70 (4) Sst tan vfgr vslty l-m stn domg flor 84 7745.0 0.01 7.8 33.3 56.5 0.59 89.8 2.68 (4) Sst tan vfgr vs1ty I-m stn domg flor 85 7746.0 0.01 9.5 51.6 31.0 1.66 82.6 2.68 (4) Sst gry-tan vfgr vs1ty 1-msp stn wh-g1d flor 86 7747.0 0.01 10.1 31.7 45.5 0.70 77.2 2.69 (4) Sst gry-tan vfgr vs1ty I-msp stn wh-g1d flor 87 7748.0 0.01 9.1 66.8 18.6 3.59 85.4 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wh-gld flor 88 7749.0 0.04 13.0 29.0 28.3 1.03 57.2 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wh-gld flor 89 7750.0 0.02 11.2 62.2 14.8 4.22 77.0 2.69 (4) Sst gry-tan vfgr vs1ty 1-msp stn wh-gld flor 90 7751.0 0.02 8.5 44.8 30.7 1.46 75.5 2.68 (4) Sst gry-tan vfgr vslty l-msp stn wh-gld flor 91 7751.9 0.02 11.7 42.0 32.8 1.28 74.8 2.68 (4) Sst gry-tan vfgr vslty l-msp stn wh-gld flor F/ Indicates Visible Fracture(s) Present ------------------- Company: KOC Well: MG-196, 197 & 200 Job ID: 50334-04032 Depth Interval Volume of Retort Fluid Produced at Various Temperatures Well Core Box Top Bot Plug ID Depth, ft Retort @ 1200°F Oil,cc Water, cc MG-200 7 15 4400.00 4401.00 2 PluQS 18 4400.40 Y ;'''''T~ 1.35 28 4400.56 Y ~ 0.50 MG-200 I 8 I 14 14652.00 4658.00 2 PluQS 78 4654.14 Y 0.40 88 4654.80 Y 0.10 MG-197 81 22 14625.00 4629.00 2 PluQS 38 4626.75 Y iì 0.10 48 4626.92 Y ~ 0.10 MG-197 6 1 4 14298.00 4299.00 2 PluQS 68 4298.13 Y 0.20 78 4298.30 Y 0.15 BG-540 6 1 13 14784.00 4785.00 2 PluQs 18 4784.10 ~U 0.55 28 4784.32 0.60 ------------------- Conoco Phillips Alaska Scout 1 Colville River Field File No.: 57111-104084HCP API No.: 50 - 103 - 20479 Date : 26 - April - 2004 Core Lab Conventional Core Analysis Procedures and Conditions Procedure (1) Procedure (2) Procedure (3) Procedure (4) Procedure (5) Sampling· Method Arbor Cut Drilled Carved Drilled Drilled Drill Coolant N/A Liquid Nitrogen N/A Isopar Brine Jacket Material Lead Lead None None N/A Saturation Method Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Retort Porosity Method Grain Volume Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Pore Vol Pore Volume Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Grain Vol Bulk Vol-Grain Vol Summation Of Fluids Bulk Volume Pore Vol + Grain Vol Pore Vol + Grain Vol Mercury Displacement Mercury Displacement Mercury Displacement Permeability Method Air Air Air Air Air Common Conditions Sleeved Sample Seating Pressure: N/A ConfIning Pressure Pore Vol & Permeability: 400 psig Perm Only Samples Dried At 235 Degrees Fahrenheit Additional Extraction by Soxhlet with Methylene Chloride/Methanol Oil Density used in Calculation: 0.85 grms/cc - -- - -- - - - - - - - - - -- - - ConocoPhillips Alaska Inc. Scout #1 Colville River Field CL File No. : 57111 -104084 wre LaIÏ CMS-300 Permeability (Horizontal Samples) 1 7662.3 0.043 0.024 6.10E+01 1.16E+15 9.25E+04 0.022 0.012 7.05E+01 6.13E+14 2.43E+04 2 7663.3 0.042 0.022 7.04E+01 5.27E+14 3.82E+04 0.021 0.014 4.42E+01 5.19E+13 2.33E+03 3 7664.3 0.024 0.012 8.35E+01 1.40E+15 5.44E+04 0.012 0.0069 5.76E+01 5.78E+14 1.32E+04 4 7665.4 0.040 0.022 6.76E+01 9.17E+14 6.45E+04 0.024 0.017 3.38E+01 1.49E+15 8.09E+04 5 7666.3 0.038 0.023 5.04E+01 2.40E+15 1.85E+05 0.016 0.0077 8.48E+01 3.88E+14 1.00E+04 6 7667.3 0.032 0.016 8.08E+01 1.27E+15 6.65E+04 0.018 0.010 6.43E+01 2.38E+14 7.95E+03 7 7668.3 0.034 0.019 6.12E+01 2.32E+15 1.46E+05 0.015 0.0068 9.96E+01 8.17E+14 1.87E+04 8 7669.3 0.019 0.013 4.06E+01 2.00E+14 8.60E+03 0.012 0.0053 1.04E+02 3.08E+14 5.55E+03 9 7670.3 0.034 0.017 7.89E+01 3.64E+14 2.04E+04 0.022 0.011 8.85E+01 8.71E+13 3.06E+03 10 7671.4 0.018 0.010 6.02E+01 2.13E+14 7.30E+03 0.012 0.0053 1.05E+02 3.19E+14 5.64E+03 11 7672.3 0.034 0.019 6.80E+01 1.64E+15 1.01 E+05 0.019 0.0093 8.55E+01 2.03E+14 6.28E+03 12 7673.3 0.038 0.021 6.73E+01 1.35E+15 9.29E+04 0.017 0.0075 9.59E+01 3.89E+14 9.48E+03 13 7674.2 0.048 0.033 3.52E+01 1.30E+15 1.39E+05 0.020 0.012 4.81E+01 1.69E+14 6.98E+03 14 7675.3 0.053 0.024 9.92E+01 1.05E+12 8.04E+01 0.028 0.013 8.52E+01 5.46E+13 2.42E+03 15 7676.2 0.018 0.0085 9.13E+01 9.10E+14 2.52E+04 0.0092 0.0061 4.36E+01 5.68E+14 1.14E+04 16 7677.3 0.032 0.014 1.01E+02 8.99E+13 4.13E+03 0.016 0.0093 5.85E+01 4.15E+14 1.26E+04 17 7678.4 0.068 0.050 2.79E+01 1.42E+12 2.29E+02 0.010 0.0075 2.87E+01 1.78E+14 4.63E+03 18 7679.3 0.046 0.030 4.27E+01 1.83E+13 1.76E+03 0.0080 0.0050 4.77E+01 9.46E+13 1.63E+03 19 7680.4 0.030 0.013 1.10E+02 1.40E+14 5.80E+03 0.011 0.0056 8.75E+01 5.79E+14 1.08E+04 20 7681.4 0.069 0.033 8.46E+01 2.74E+13 2.92E+03 0.041 0.018 9.96E+01 2.03E+13 1.21 E+03 21 7682.3 0.158 0.089 5.58E+01 1.93E+12 5.57E+02 0.123 0.069 5.76E+01 3.41E+12 7.67E+02 22 7683.3 0.382 0.287 2.24E+01 9.87E+12 9.07E+03 0.274 0.178 3.65E+01 6.89E+11 4.02E+02 23 7684.3 0.473 0.320 3.22E+01 9.09E+11 9.41E+02 0.408 0.277 3.16E+01 1.22E+12 1.10E+03 24 7685.3 0.303 0.173 5.24E+01 2.09E+11 1.17E+02 0.229 0.129 5.34E+01 1.08E+12 4.57E+02 25 7686.3 0.076 0.037 8.07E+01 2.19E+13 2.65E+03 0'.048 0.021 9.56E+01 8.17E+12 5.74E+02 26 7687.3 0.392 0.292 2.30E+01 1.10E+13 1.03E+04 0.273 0.167 4.28E+01 1.76E+11 9.67E+01 27 7688.3 0.734 0.505 2.95E+01 5.41E+11 8.83E+02 0.652 0.449 2.93E+01 6.65E+11 9.70E+02 28 7689.3 0.128 0.068 6.52E+01 2.57E+12 5.65E+02 0.094 0.048 7.18E+01 6.17E+11 9.60E+01 29 7690.3 0.059 0.026 1.04E+02 3.12E+13 2.59E+03 0.039 0.017 9.66E+01 1.00E+13 5.71E+02 30 7691.3 0.055 0.023 1.15E+02 1.71E+12 1.25E+02 0.036 0.015 1.10E+02 1.90E+13 9.41E+02 31 7692.3 0.098 0.048 7.77E+01 5.71E+12 8.94E+02 0.069 0.033 8.33E+01 8.47E+12 9.06E+02 32 7693.3 0.058 0.025 1.09E+02 5.45E+12 4.34E+02 0.043 0.020 8.73E+01 5.98E+12 3.97E+02 - - - - -- - - - - - - - - - - - - - ConocoPhillips Alaska Inc. Scout #1 Colville River Field CL File No. : 57111 . 104084 Core Lab CMS-300 Permeability (Horizontal Samples) 33 7694.3 0.059 0.027 9.71E+01 3.90E+13 3.35E+03 0.039 0.017 9.69E+01 2.72E+13 1.55E+03 34 7695.3 0.045 0.D18 1.27E+02 2.08E+13 1.20E+03 0.029 0.012 1.12E+02 6.31E+13 2.53E+03 35 7696.3 0.035 0.015 1.09E+02 4.39E+14 2.15E+04 0.022 0.011 8.20E+01 1.01E+15 3.60E+04 36 7697.3 0.050 0.020 1.16E+02 4.69E+13 3.09E+03 0.034 0.014 1.10E+02 3.61E+13 1.68E+03 37 7698.3 0.200 0.117 5.06E+01 7.50E+11 2.83E+02 0.163 0.094 5.26E+01 1.77E+12 5.42E+02 38 7699.3 0.043 0.022 7.98E+01 7.88E+14 5.54E+04 0.027 0.014 7.42E+01 5.85E+14 2.71E+04 39 7700.3 0.027 0.013 9.29E+01 3.33E+13 1.36E+03 0.012 0.0072 6.06E+01 3.76E+14 8.93E+03 40 7701.3 0.033 0.017 7.91E+01 9.51E+14 5.23E+04 0.021 0.012 5.80E+01 2.37E+14 9.53E+03 41 7702.3 0.032 0.016 8.04E+01 4.65E+14 2.45E+04 0.021 0.014 3.93E+01 1.84E+14 8.64E+03 42 7703.3 0.016 0.0079 9.36E+01 1.64E+14 4.22E+03 0.011 0.0048 1.08E+02 4.00E+14 6.28E+03 43 7704.3 0.027 0.016 5.97E+01 1.46E+14 7.43E+03 0.018 0.0083 9.39E+01 1.37E+14 3.79E+03 44 7705.3 0.035 0.018 7.54E+01 2.00E+14 1.18E+04 0.013 0.0064 8.51 E+01 5.99E+14 1.29E+04 45 7706.3 0.067 0.030 9.46E+01 1.55E+13 1.52E+03 0.047 0.022 9.30E+01 2.04E+13 1.44E +03 46 7707.3 0.110 0.057 7.11E+01 2.19E+11 4.01 E+01 0.081 0.041 7.44E+01 7.22E+12 9.56E+02 47 7708.3 0.052 0.023 1.01E+02 1.49E+14 1.10E+04 0.031 0.015 8.47E+01 3.32E+13 1.65E+03 48 7709.3 0.061 0.028 9.53E+01 9.98E+13 8.90E+03 0.039 0.018 9.70E+01 1.60E+13 9.27E+02 49 7710.3 0.060 0.025 1.10E+02 8.20E+12 6.66E+02 0.041 0.019 8.93E+01 1.62E+12 1.01E+02 50 7711.3 0.051 0.020 1.23E+02 1.08E+13 7.06E+02 0.031 0.014 9.45E+01 4.41E+13 2.07E+03 51 7712.3 0.058 0.026 9.78E+01 1.15E+14 9.60E+03 0.035 0.017 8.81E+01 1.11E+13 6.11E+02 52 7713.3 0.050 0.022 1.03E+02 9.22E+13 6.58E+03 0.028 0.012 1.04E+02 7.27E+13 2.93E+03 53 7714.3 0.036 0.018 7.60E+01 5.80E+14 3.45E+04 0.020 0.013 4.08E+01 1.60E+14 7.06E+03 54 7715.3 0.030 0.015 7.88E+01 7.99E+14 3.92E+04 0.015 0.0096 4.63E+01 3.79E+14 1.20E+04 55 7716.3 0.030 0.016 6.83E+01 4.81E+13 2.55E+03 0.0084 0.0035 1.15E+02 6.71E+14 8.02E+03 56 7717.3 0.018 0.010 6.21E+01 3.70E+14 1.23E+04 0.0065 0.0027 1.23E+02 1.12E+15 1.02E+04 57 7718.3 0.031 0.019 5.44E+01 4.42E+13 2.66E+03 0.0067 0.0027 1.22E +02 1.05E+15 9.90E+03 58 7719.3 0.016 0.0087 7.51E+01 1.56E+14 4.46E+03 0.0051 0.0036 3.62E+01 1.56E+15 1.90E+04 59 7720.3 0.014 0.0066 9.60E+01 3.62E+15 7.83E+04 0.0062 0.0033 7.59E+01 2.00E+15 2.21E+04 60 7721.3 0.019 0.0091 9.22E+01 1.20E+14 3.55E+03 0.0086 0.OÓ37 1.14E+02 6.32E+14 7.79E+03 61 7722.3 0.017 0.011 5.02E+01 2.44E+14 8.78E+03 0.0088 0.0037 1. t4E+02 6.05E+14 7.64E+03 62 7723.4 0.014 0.0091 4.25E+01 3.76E+14 1.13E+04 0.0061 0.0025 1.25E+02 1.27E+15 1.09E+04 63 7724.3 0.091 0.080 9.70E+00 7.11E+11 1.83E+02 0.013 0.0097 2.79E+01 1.95E+13 6.57E+02 64 7725.4 0.014 0.0069 9.49E+01 3.30E+15 7.45E+04 0.0062 0.0031 8.65E+01 1.83E+15 1.89E+04 - - - - - -- - - - - - -- - - - - - ConocoPhillips Alaska Inc. Scout #1 Colville River Field CL File No. : 57111 - 104084 Core Lab CMS-300 Permeability (Horizontal Samples) 65 7726.4 0.017 0.0080 9.53E+01 1.54E+14 4.01E+03 0.0083 0.0035 1.15E+02 6.81E+14 8.08E+03 66 7727.3 0.070 0.041 5.59E+01 8.89E+12 1.16E+03 0.0094 0.0070 2.56E+01 4.01E+13 9.78E+02 67 7728.3 0.125 0.078 4.39E+01 3.33E+12 8.22E+02 0.015 0.0065 9.84E+01 1.96E+14 4.48E+03 68 7729.4 0.017 0.0090 7.27E+01 2.03E+15 5.98E+04 0.0077 0.0048 5.23E+01 9.41E+14 1.49E+04 69 7730.3 0.021 0.0100 9.05E+01 3.71E+15 1.21E+05 0.011 0.0046 1.11E+02 6.41E+14 9.76E+03 70 7731.4 0.018 0.0087 9.14E+01 1.70E+15 4.80E+04 0.0096 0.0053 7.10E+01 6.98E+14 1.21E+04 71 7732.4 0.016 0.0079 9.07E+01 3.27E+15 8.45E+04 0.0065 0.0033 8.09E+01 1.37E+15 1.53E+04 72 7733.3 0.011 0.0050 1.00E+02 4.52E+14 7.44E+03 0.0043 0.0017 1.39E+02 2.77E+15 1.57E+04 73 7734.3 0.018 0.0087 9.10E+01 1.58E+15 4.45E+04 0.0097 0.0058 5.78E+01 6.86E+14 1.30E+04 74 7735.3 0.040 0.034 1.42E+01 1.21E+13 1.33E+03 0.0095 0.0039 1.11E+02 5.08E+14 7.03E+03 75 7736.3 0.014 0.0086 5.83E+01 2.76E+14 7.75E+03 0.0075 0.0031 1.19E+02 8.44E+14 8.94E+03 76 7737.3 0.021 0.012 6.61E+01 1.09E+15 4.13E+04 0.011 0.0048 1.07E+02 3.87E+14 6.18E+03 77 7738.4 0.029 0.017 6.29E+01 1.37E+15 7.42E+04 0.016 0.011 4.57E+01 3.21E+14 1.11E+04 78 7739.3 0.027 0.013 8.44E+01 1.08E+15 4.61E+04 0.016 0.0088 6.66E+01 2.65E+14 7.62E+03 79 7740.3 0.020 0.0096 9.08E+01 6.79E+14 2.12E+04 0.013 0.0084 4.71E+01 3.21E+14 8.77E+03 80 7741.4 0.016 0.0078 9.44E+01 4.96E+14 1.26E +04 0.010 0.0063 5.48E+01 5.28E+14 1.09E+04 81 7742.3 0.018 0.0085 9.08E+01 7.18E+14 1.99E+04 0.0089 0.0054 5.39E+01 6.55E+14 1.17E+04 82 7743.3 0.043 0.031 3.03E+01 9.49E+12 9.59E+02 0.011 0.0085 2.16E+01 1.30E+14 3.76E+03 83 7744.4 0.012 0.0061 7.88E+01 2.64E+14 5.30E+03 0.0032 0.0012 1.50E+02 5.04E+15 2.08E+04 84 7745.3 0.0075 0.0033 1.18E+02 8.13E+14 8.78E+03 0.0030 0.0011 1.53E+02 5.85E+15 2.23E+04 85 7746.3 0.018 0.0099 7.03E+01 3.35E+15 1.09E+05 0.0066 0.0035 7.25E+01 1.93E+15 2.30E+04 86 7747.4 0.017 0.0085 8.87E+01 1.53E+15 4.26E+04 0.0065 0.0034 7.71E+01 1.49E+15 1.71E+04 87 7748.3 0.018 0.0085 9.14E+01 1.83E+15 5.07E+04 0.0083 0.0048 6.10E+01 8.28E+14 1.32E+04 88 7749.3 0.044 0.019 1.03E+02 2.74E+14 1.72E+04 0.029 0.013 9.82E+01 5.59E+13 2.38E+03 89 7750.3 0.021 0.010 9.00E+01 3.59E+15 1.19E+05 0.012 0.0052 1.07E+02 1.13E+15 1.95E+04 90 7751.7 0.152 0.098 4.02E+01 7.83E+11 2.48E+02 0.052 0.030 5.45E+01 2.09E+13 2.10E+03 91 7752.6 0.751 0.593 1.72E+01 1.21E+12 2.30E+03 0.223 0.1~0 2.57E+01 6.04E+11 3.23E+02 ------ - - - - - - - - - - - - - ConocoPhillips Alaska Inc. Scout #1 Colville River Field CL File No. : 57111 - 104084 CMS-300 Permeability (Vertical Samples) 2V 7663.0 0.0071 0.0031 1.19E+02 8.56E+14 9.00E+03 4V 7665.0 0.0061 0.0026 1.25E+02 1.21E+15 1.06E+04 6V 7667.0 0.0056 0.0024 1.27E+02 1.42E+15 1.14E+04 8V 7669.0 0.0041 0.0017 1.38E+02 2.66E+15 1.54E+04 10V 7671.0 0.0050 0.0021 1.31E+02 1.83E+15 1.29E+04 12V 7673.0 0.0080 0.0035 1.16E+02 6.80E+14 8.07E+03 14V 7675.0 0.016 0.0076 9.60E+01 1.62E+14 4.09E+03 16V 7677.0 0.0089 0.0039 1.12E+02 5.52E+14 7.33E+03 18V 7679.0 0.0026 0.0010 1.56E+02 7.26E+15 2.50E+04 20V 7681.0 0.0092 0.0041 1.11E+02 5.12E+14 7.07E+03 22V 7683.0 0.249 0.154 4.33E+01 6.53E+11 3.27E+02 24V 7685.0 0.077 0.044 5.76E+01 4.72E+14 6.75E+04 26V 7687.0 0.082 0.062 2.40E+01 1.01E+15 2.05E+05 28V 7689.0 0.263 0.147 5.56E+01 1.29E+13 6.17E+03 30V 7691.0 0.019 0.0089 9.22E+01 1.18E+14 3.53E+03 32V 7693.0 0.017 0.0081 9.43E+01 1.41E+14 3.84E+03 34V 7695.0 0.020 0.0092 9.51E+01 4.14E+14 1.27E+04 36V 7697.0 0.018 0.0084 9.35E+01 1.32E+14 3.71E+03 40V 7701.0 0.0071 0.0031 1.19E+02 8.50E+14 8.97E+03 42V 7703.0 0.0069 0.0030 1.20E+02 9.06E+14 9.24E+03 44V 7705.1 0.0039 0.0016 1.40E+02 2.99E+15 1.62E+04 46V 7707.0 0.054 0.029 6.90E+01 2.05E+14 1.96E+04 48V 7709.0 0.028 0.014 8.23E+01 4.87E+13 2.32E+03 50V 7711.0 0.012 0.0053 1.04E+02 3.03E+14 5.50E+03 52V 7713.0 0.013 0.0061 1.01 E+02 2.34E+14 4.87E+03 54V 7715.0 0.0048 0.0020 1.32E+02 1.88E+15 1.30E+04 56V 7717.0 0.0027 0.0011 1.54E+02 6.31E+15 2.32E+04 58V 7719.0 0.0023 0.0009 1.61E+02 8.76E+15 2.70E+04 60V 7720.9 0.0039 0.0016 1.39E+02 2.88E+15 1.60E+04 62V 7723.1 0.0042 0.0017 1.37E+02 2.56E+15 1.51E+04 .64V 7725.1 0.0026 0.0010 1.55E+02 6.73E+15 2.39E+04 66V 7727.0 0.0020 0.0007 1.68E+02 1.21E+16 3.15E+04 ------------------- [ore Lab ConocoPhillips Alaska Inc. Scout #1 Colville River Field CL File No. : 57111 - 104084 CMS-300 Permeability (Vertical Samples) 68V 7729.1 0.0038 0.0015 1.41E+02 3.14E+15 1.66E+04 70V 7731.1 0.0069 0.0030 1.20E+02 8.82E+14 9.12E+03 72V 7733.1 0.0023 0.0009 1.60E+02 8.52E+15 2.67E+04 74V 7735.0 0.0048 0.0020 1.32E+02 1.87E+15 1.30E+04 76V 7737.0 0.0054 0.0023 1.28E+02 1.46E+15 1.16E+04 78V 7739.0 0.011 0.0049 1.06E+02 1.49E+16 2.48E+05 80V 7741.1 0.0064 0.0027 1.22E+02 1.05E+15 9.90E+03 82V 7743.0 0.0028 0.0011 1.53E+02 5.82E+15 2.23E+04 84V 7745.0 0.0021 0.0008 1.64E+02 1.03E+16 2.92E+04 86V 7747.1 0.0043 0.0018 1.36E+02 2.36E+15 1.45E+04 88V 7749.0 0.017 0.014 1.68E+01 1.05E+14 5.08E+03 90V 7751.5 0.0030 0.0012 1.50E+02 5.03E+15 2.08E+04 ------------------- ConocoPhillips Alaska Inc. Scout #1 CoreLab Colville River Field CL File No. : 57111 - 104084 Horizontal and Vertical Permeability Sample Depth Permeability Kair (md) Klinkenberg-Corrected (md) ID. ft Horizontal . I Vertical Horizontal I Vertical SS1 400 Dsia I CMS 800 NOB I CMS 2600 NOBI SS 1 400 Dsia I CMS 2600 NOB CMS 800 NOB I CMS 2600 NOB I CMS 2600 NOB 1 7662 0.04 0.043 0.022 0.06 0.024 0.012 2 7663 0.04 0.042 0.021 0.02 0.0071 0.022 0.014 0.0031 3 7664 0.02 0.024 0.012 0.05 0.012 0.0069 4 7665 0.04 0.040 0.024 0.02 0.0061 0.022 0.017 0.0026 5 7666 0.04 0.038 0.016 0.05 0.023 0.0077 6 7667 0.03 0.032 0.018 0.03 0.0056 0.016 0.010 0.0024 7 7668 0.03 0.034 0.015 0.05 0.019 0.0068 8 7669 0.02 0.019 0.012 0.02 0.0041 0.013 0.0053 0.0017 9 7670 0.03 0.034 0.022 0.07 0.017 0.011 10 7671 0.02 0.018 0.012 0.02 0.0050 0.010 0.0053 0.0021 11 7672 0.03 0.034 0.019 0.05 0.019 0.0093 12 7673 0.04 0.038 0.017 0.02 0.0080 0.021 0.0075 0.0035 13 7674 0.05 0.048 0.020 0.06 0.033 0.012 14 7675 0.05 0.053 0.028 0.05 0.016 0.024 0.013 0.0076 15 7676 0.02 0.018 0.0092 0.05 0.0085 0.0061 16 7677 0.03 0.032 0.016 0.03 0.0089 0.014 0.0093 0.0039 17 7678 0.07 0.068 0.010 0.03 0.050 0.0075 18 7679 0.05 0.046 0.0080 0.02 0.0026 0.030 0.0050 0.0010 19 7680 0.03 0.030 0.011 0.06 0.013 0.0056 20 7681 0.07 0.069 0.041 0.03 0.0092 0.033 0.018 0.0041 21 7682 0.16 0.158 0.123 0.13 0.089 0.069 22 7683 0.38 0.382 0.274 0.32 0.249 0.287 0.178 0.154 23 7684 0.47 0.473 0.408 0.22 0.320 0.277 24 7685 0.28 0.303 0.229 0.14 0.077 0.173 0.129 0.044 25 7686 0.10 0.076 0.048 0.09 0.037 0.021 26 7687 0.33 0.392 0.273 0.12 0.082 0.292 0.167 0.062 27 7688 0.73 0.734 0.652 F/14.54 0.505 0.449 28 7689 0.13 0.128 0.094 0.31 0.263 0.068 0.048 0.147 29 7690 0.07 0.059 0.039 0.04 0.026 0.017 30 7691 0.07 0.055 0.036 0.06 0.019 0.023 0.015 0.0089 31 7692 0.10 0.098 0.069 0.11 0.048 0.033 SS 1 - Steady-state permeability ------------------- !"!!f....".~... ~i~~.·. ConocoPhillips Alaska Inc. ~ Scout #1 ~ Core Lab Colville River Field CL File No. : 57111 - 104084 Horizontal and Vertical Permeability Sample Depth Permeability Kair (md) Klinkenberg-Corrected (md) ID. ft Horizontal I Vertical Horizontal I Vertical SS1 4000sla I CMS 800 NOB I CMS 2600 NOBI Ss1 4000sltl T CMS 2600 NOB CMS 800 NOB ICMS 2600 NOB I CMS 2600 NOB 32 7693 0.06 0.058 0.043 0.05 0.017 0.025 0.020 0.0081 33 7694 0.06 0.059 0.039 0.06 0.027 0.017 34 7695 0.06 0.045 0.029 0.06 0.020 0.018 0.012 0.0092 35 7696 0.04 0.035 0.022 0.03 0.015 0.011 36 7697 0.05 0.050 0.034 0.04 0.018 0.020 0.014 0.0084 37 7698 0.20 0.200 0.163 0.16 0.117 0.094 38 7699 0.04 0.043 0.027 0.02 0.022 0.014 39 7700 0.03 0.027 0.012 0.02 0.013 0.0072 40 7701 0.03 0.033 0.021 0.03 0.0071 0.017 0.012 0.0031 41 7702 0.03 0.032 0.021 0.04 0.016 0.014 42 7703 0.02 0.016 0.011 0.02 0.0069 0.0079 0.0048 0.0030 43 7704 0.03 0.027 0.018 0.02 0.016 0.0083 44 7706 0.04 0.035 0.013 0.02 0.0039 0.018 0.0064 0.0016 45 7706 0.07 0.067 0.047 0.06 0.030 0.022 46 7707 0.11 0.110 0.081 0.10 0.054 0.057 0.041 0.029 47 7708 0.05 0.052 0.031 0.06 0.023 0.015 48 7709 0.06 0.061 0.039 0.06 0.028 0.028 0.018 0.014 49 7710 0.06 0.060 0.041 0.02 0.025 0.019 50 7711 0.06 0.051 0.031 0.04 0.012 0.020 0.014 0.0053 51 7712 0.07 0.058 0.035 0.02 0.026 0.017 52 7713 0.07 0.050 0.028 0.03 0.013 0.022 0.012 0.0061 53 7714 0.04 0.036 0.020 0.02 0.018 0.013 54 7715 0.03 0.030 0.015 0.02 0.0048 0.015 0.0096 0.0020 55 7716 0.03 0.030 0.0084 0.02 0.016 0.0035 56 7717 0.02 0.018 0.0065 0.01 0.0027 0.010 0.0027 0.0011 57 7718 0.03 0.031 0.0067 0.02 0.019 0.0027 58 7719 0.02 0.016 0.0051 0.01 0.0023 0.0087 0.0036 0.0009 59 7720 0.01 0.014 0.0062 0.01 0.0066 0.0033 60 7721 0.02 0.019 0.0086 0.02 0.0039 0.0091 0.0037 0.0016 61 7722 0.02 0.017 0.0088 0.02 0.011 0.0037 62 7723 0.01 0.014 0.0061 0.02 0.0042 0.0091 0.0025 0.0017 SS 1 - Steady-state permeability ------------------- ConocoPhillips Alaska Inc. Scout #1 Colville River Field CL File No. : 57111 - 104084 Horizontal and Vertical Permeability Sample Depth Permeability Kair (md) Klinkenberg-Corrected(md) ID. ft Horizontal I Vertical Horizontal I Vertical 5S 1 400 Dsia I CMS 800 NOB I CMS 2600 NOB I SS1 400 Dsia I CMS 2600 NOB CMS 800 NOB I CMS 2600 NOB I CMS 2600 NOB 63 7724 0.09 0.091 0.013 0.01 0.080 0.0097 64 7725 0.01 0.014 0.0062 0.02 0.0026 0.0069 0.0031 0.0010 65 7726 0.02 0.017 0.0083 0.02 0.0080 0.0035 66 7727 0.07 0.070 0.0094 0.02 0.0020 0.041 0.0070 0.0007 67 7728 0.12 0.125 0.015 0.01 0.078 0.0065 68 7729 0.02 0.017 0.0077 0.02 0.0038 0.0090 0.0048 0.0015 69 7730 0.02 0.021 0.011 0.01 0.010 0.0046 70 7731 0.02 0.018 0.0096 0.02 0.0069 0.0087 0.0053 0.0030 71 7732 0.02 0.016 0.0065 0.02 0.0079 0.0033 72 7733 0.01 0.011 0.0043 0.01 0.0023 0.0050 0.0017 0.0009 73 7734 0.02 0.018 0.0097 0.01 0.0087 0.0058 74 7735 0.04 0.040 0.0095 0.02 0.0048 0.034 0.0039 0.0020 75 7736 0.01 0.014 0.0075 0.01 0.0086 0.0031 76 7737 0.02 0.021 0.011 0.02 0.0054 0.012 0.0048 0.0023 77 7738 0.03 0.029 0.016 0.01 0.017 0.011 78 7739 0.03 0.027 0.016 0.02 0.011 0.013 0.0088 0.0049 79 7740 0.02 0.020 0.013 0.01 0.0096 0.0084 80 7741 0.02 0.016 0.010 0.02 0.0064 0.0078 0.0063 0.0027 81 7742 0.02 0.018 0.0089 0.02 0.0085 0.0054 82 7743 0.04 0.043 0.011 0.01 0.0028 0.031 0.0085 0.0011 83 7744 0.01 0.012 0.0032 0.01 0.0061 0.0012 84 7745 0.01 0.0075 0.0030 0.01 0.0021 0.0033 0.0011 0.0008 85 7746 0.02 0.018 0.0066 0.01 0.0099 0.0035 86 7747 0.02 0.017 0.0065 0.01 0.0043 0.0085 0.0034 0.0018 87 7748 0.02 0.018 0.0083 0.01 0.0085 0.0048 88 7749 0.04 0.044 0.029 0.04 0.017 0.019 0.013 0.014 89 7750 0.02 0.021 0.012 0.02 0.010 0.0052 90 7752 0.15 0.152 0.052 0.02 0.0030 0.098 0.030 0.0012 91 7752 F/0.75 0.751 0.223 0.02 0.593 0.160 SS 1 - Steady-state permeability I I I I I I I I I I I I I I I I I I I 7660.0 . 7670.0 7680.0 7690.0 7700.0 ¢:: 7710.0 7720.0 . 7730.0 . 7740.0· 7750.0 . 7760.0 . 0.001 CPAI Scout #1 Permeability Profile 7650.0 0.010 0.100 1.000 10.000 I<linkenberg-Corrected Permeability (1<1) md ¡ , ì PDPK Hariz. @ 800 psi NOB Hariz. @ 2600 psi NOB --- Vert. @ 2600 psi NOB lij 100.000 I I ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 1 7662.10 1.15 0.807 2 7662.21 1.19 0.842 3 7662.31 1.08 0.747 I 4 7662.40 1.81 1.33 5 7662.50 1.13 0.789 6 7662.61 1.34 0.959 I 7 7662.71 2.19 1.64 8 7662.81 1.56 1.13 9 7662.92 1.19 0.834 10 7663.01 0.776 0.520 I 11 7663.10 0.226 0.124 12 7663.21 0.719 0.476 13 7663.30 0.273 0.156 I 14 7663.40 0.991 0.682 15 7663.51 0.199 0.107 16 7663.60 0.944 0.649 17 7663.71 0.277 0.158 I 18 7663.81 0.637 0.416 19 7663.91 0.214 0.116 20 7664.01 1.53 1.10 I 21 7664.10 0.722 0.479 22 7664.21 0.747 0.498 23 7664.31 2.69 2.05 24 7664.41 2.59 1.97 I 25 7664.61 5.45 4.44 26 7664.71 8.04 6.60 27 7664.81 0.438 0.268 I 28 7664.91 1.07 0.743 29 7665.03 0.987 0.681 30 7665.11 1.49 1.08 I 31 7665.21 0.920 0.629 32 7665.30 0.877 0.598 33 7665.41 0.643 0.420 34 7665.51 0.218 0.119 I 35 7665.60 0.704 0.464 36 7665.71 0.321 0.188 37 7665.81 1.07 0.745 I 38 7665.91 0.129 0.063 39 7666.00 0.190 0.101 40 7666.10 3.28 2.53 41 7666.19 8.64 7.27 I 42 7666.30 0.851 0.578 43 7666.41 0.450 0.278 44 7666.51 8.45 6.97 I 45 7666.61 0.691 0.454 46 7666.71 1.31 0.935 I I I .1£\ ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 ~~ Scout #1 I Core LaI:Ì Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 47 7666.81 1.14 0.795 48 7666.91 1.37 0.984 49 7666.96 6.29 5.10 I 50 7667.11 0.718 0.476 51 7667.21 0.877 0.597 52 7667.30 0.520 0.330 I 53 7667.41 0.139 0.069 54 7667.51 0.538 0.343 55 7667.60 0.530 0.336 56 7667.71 0.659 0.431 I 57 7667.81 0.752 0.500 58 7667.91 1.04 0.724 59 7667.98 0.731 0.484 I 60 7668.11 2.26 1.70 61 7668.20 1.67 1.21 62 7668.31 0.975 0.672 63 7668.45 0.372 0.223 I 64 7668.60 0.873 0.593 65 7668.71 0.820 0.554 66 7668.83 1.62 1.18 I 67 7668.91 4.22 3.31 68 7669.01 3.30 2.54 69 7669.11 1.50 1.09 70 7669.21 0.958 0.660 I 71 7669.31 0.601 0.390 72 7669.40 0.300 0.173 73 7669.50 0.630 0.412 I 74 7669.61 0.350 0.208 75 7669.71 0.659 0.434 76 7669.81 0.741 0.492 77 7669.93 6.21 5.01 I 78 7670.02 0.104 0.048 79 7670.11 1.14 0.799 80 7670.21 0.256 0.144 I 81 7670.31 1.23 0.871 82 7670.40 0.447 0.276 83 7670.50 0.224 0.123 I 84 7670.61 1.36 0.971 85 7670.71 0.255 0.144 86 7670.80 1.29 0.914 87 7670.90 0.469 0.292 I 88 7670.91 0.359 0.215 89 7671.11 1.59 1.15 90 7671.21 0.155 0.078 I 91 7671.30 3.95 3.08 92 7671.41 1.81 1.33 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Core LaI:Î Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 93 7671.54 0.551 0.353 94 7671.59 0.763 0.509 95 7671.72 0.907 0.621 I 96 7671.80 0.439 0.270 97 7671.91 0.491 0.309 98 7672.02 1.07 0.746 I 99 7672.10 9.31 7.74 100 7672.21 0.190 0.101 101 7672.30 0.215 0.117 102 7672.40 0.434 0.266 I 103 7672.51 0.308 0.179 104 7672.60 0.247 0.138 105 7672.70 0.626 0.409 I 106 7672.81 0.253 0.142 107 7672.90 0.395 0.240 108 7672.99 0.530 0.337 109 7673.11 0.605 0.394 I 110 7673.21 0.919 0.631 111 7673.31 0.904 0.620 112 7673.40 0.499 0.315 I 113 7673.51 0.987 0.681 114 7673.60 1.19 0.843 115 7673.70 2.82 2.16 116 7673.81 0.839 0.567 I 117 7673.90 0.648 0.426 118 7674.00 0.546 0.349 119 7674.11 1.37 0.981 I 120 7674.21 0.654 0.429 121 7674.31 0.444 0.275 122 7674.40 1.12 0.780 123 7674.51 0.859 0.584 I 124 7674.60 0.692 0.455 125 7674.71 0.224 0.123 126 7674.81 0.943 0.648 I 127 7674.91 1.29 0.916 128 7674.99 1.05 0.726 129 7675.11 0.521 0.331 I 130 7675.22 0.475 0.297 131 7675.30 1.81 1.33 132 7675.41 1.17 0.827 133 7675.51 1.45 1.04 I 134 7675.61 1.02 0.704 135 7675.81 2.10 1.56 136 7675.91 0.963 0.666 I 137 7676.00 2.00 1.48 138 7676.11 0.897 0.615 I I I A ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Core LaI:Î Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 139 7676.20 1.62 1.18 140 7676.31 3.84 3.01 141 7676.41 0.651 0.427 I 142 7676.51 0.221 0.121 143 7676.60 2.14 1.60 144 7676.71 0.302 0.175 I 145 7676.80 0.860 0.584 146 7676.90 0.834 0.565 147 7676.96 3.15 2.43 148 7677.11 1.07 0.742 I 149 7677.21 3.08 2.37 150 7677.21 6.45 5.33 151 7677.30 0.934 0.643 I 152 7677.40 0.264 0.149 153 7677.41 4.94 3.92 154 7677.50 0.144 0.072 155 7677.60 1.70 1.24 I 156 7677.60 6.26 5.17 157 7677.71 0.210 0.114 158 7677.80 2.62 2.00 I 159 7677.81 1.73 1.26 160 7677.91 0.280 0.160 161 7677.97 0.675 0.443 162 7678.03 0.997 0.688 I 163 7678.10 1.15 0.801 164 7678.23 4.02 3.15 165 7678.33 0.468 0.292 I 166 7678.40 1.84 1.36 167 7678.41 3.87 3.02 168 7678.51 0.558 0.359 169 7678.61 6.81 5.66 I 170 7678.61 0.785 0.526 171 7678.71 0.890 0.609 172 7678.81 1.15 0.804 I 173 7678.81 6.97 5.67 174 7678.90 1.46 1.05 175 7678.98 1.38 0.985 176 7679.02 3.62 2.82 I 177 7679.12 3.22 2.50 178 7679.19 8.85 7.46 179 7679.21 3.11 2.40 I 180 7679.31 3.26 2.52 181 7679.40 2.13 1.58 182 7679.40 2.45 1.86 I 183 7679.51 15.4 13.2 184 7679.58 0.673 0.444 I I I " ConoeoPhillips Alaska Inc. CL File No. : 57111 - 104084 <1IiIr . Scout #1 ~ Colville River Field I ÜJn! laI:Ì Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 185 7679.60 4.38 3.46 186 7679.71 0.695 0.459 187 7679.80 1.36 0.976 I 188 7679.81 0.645 0.423 189 7679.90 1.18 0.829 190 7680.00 2.63 2.00 I 191 7680.11 1.19 0.833 192 7680.21 3.16 2.44 193 7680.30 1.62 1.18 194 7680.52 2.62 1.99 I 195 7680.71 1.24 0.875 196 7680.91 1.47 1.06 197 7681.12 2.18 1.63 I 198 7681.30 2.86 2.20 199 7681.51 3.08 2.38 200 7681.71 1.20 0.844 201 7681.91 1.25 0.882 I 202 7682.10 1.51 1.09 203 7682.32 2.76 2.11 204 7682.50 1.63 1.18 I 205 7682.71 1.73 1.27 206 7682.91 2.81 2.15 207 7683.11 1.67 1.22 208 7683.21 1.56 1.13 I 209 7683.31 2.41 1.82 210 7683.41 1.85 1.37 211 . 7683.51 2.63 2.00 I 212 7683.60 2.34 1.76 213 7683.71 2.24 1.68 214 7683.81 2.37 1.79 215 7683.91 2.50 1.90 I 216 7684.01 3.82 2.99 217 7684.11 1.83 1.35 218 7684.21 3.54 2.76 I 219 7684.31 2.95 2.27 220 7684.41 4.13 3.25 221 7684.51 2.56 1.95 222 7684.61 3.57 2.79 I 223 7684.82 3.52 2.73 224 7684.91 2.04 1.52 225 7685.00 3.16 2.44 I 226 7685.11 0.542 0.347 227 7685.21 3.31 2.57 228 7685.31 0.279 0.160 229 7685.40 3.32 2.58 I 230 7685.51 0.621 0.406 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 231 7685.61 4.47 3.53 232 7685.71 0.847 0.575 233 7685.81 3.98 3.12 I 234 7685.90 1.40 1.00 235 7686.11 0.726 0.482 236 7686.21 7.59 6.33 I 237 7686.30 0.495 0.312 238 7686.40 4.38 3.46 239 7686.50 0.548 0.351 240 7686.61 7.02 5.83 I 241 7686.71 0.581 0.376 242 7686.80 0.923 0.634 243 7686.91 1.22 0.862 I 244 7686.99 6.04 4.96 245 7687.11 1.03 0.713 246 7687.21 0.663 0.437 247 7687.31 1.13 0.791 I 248 7687.41 1.37 0.982 249 7687.50 2.90 2.23 250 7687.58 1.20 0.845 I 251 7687.71 8.72 7.21 252 7687.81 1.40 1.01 253 7688.00 2.35 1.77 254 7688.11 1.10 0.771 I 255 7688.21 2.73 2.09 256 7688.30 1.25 0.892 257 7688.40 2.39 1.80 I 258 7688.51 1.54 1.12 259 7688.62 1.40 1.01 260 7688.70 1.44 1.04 261 7688.80 2.78 2.13 I 262 7688.91 1.53 1.11 263 7688.99 3.97 3.12 264 7689.11 1.28 0.907 I 265 7689.20 3.02 2.33 266 7689.31 2.09 1.56 267 7689.40 2.37 1.79 268 7689.51 1.60 1.16 I 269 7689.60 2.68 2.04 270 7689.70 1.26 0.890 271 7689.81 4.26 3.36 I 272 7689.91 1.22 0.867 273 7690.00 3.38 2.62 274 7690.11 0.940 0.613 I 275 7690.21 2.81 2.15 276 7690.31 0.968 0.666 I I I 4\ ConocoPhillips Alaska Inc. CL File No. : 57111 . 104084 Scout #1 .....~ Colville River Field I ÜJre Lab Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 277 7690.39 3.49 2.72 278 7690.52 1.26 0.895 279 7690.71 1.17 0.824 I 280 7690.77 2.97 2.28 281 7690.91 0.654 0.428 282 7691.02 4.19 3.30 I 283 7691.21 4.57 3.63 284 7691.31 1.32 0.940 285 7691.40 7.68 6.41 286 7691.51 1.46 1.05 I 287 7691.71 1.28 0.908 288 7691.91 0.908 0.623 289 7692.00 0.739 0.492 I 290 7692.10 0.678 0.446 291 7692.21 0.452 0.279 292 7692.31 0.999 0.690 293 7692.41 1.56 1.13 I 294 7692.50 1.31 0.936 295 7692.60 2.06 1.54 296 7692.71 1.16 0.814 I 297 7692.81 1.88 1.39 298 7692.91 0.949 0.654 299 7693.03 1.00 0.690 300 7693.10 1.23 0.871 I 301 7693.20 1.81 1.32 302 7693.30 0.739 0.463 303 7693.43 2.32 1.74 I 304 7693.50 0.526 0.334 305 7693.61 4.33 3.42 306 7693.71 0.516 0.327 307 7693.81 7.48 6.23 I 308 7693.91 0.631 0.412 309 7693.97 3.50 2.73 310 7694.11 1.77 1.30 I 311 7694.21 3.49 2.72 312 7694.31 1.11 0.778 313 7694.41 4.01 3.15 314 7694.51 0.687 0.453 I 315 7694.61 6.74 5.59 316 7694.71 0.732 0.486 317 7694.83 5.32 4.25 I 318 7694.90 0.846 0.574 319 7695.11 0.886 0.605 320 7695.21 0.459 0.285 321 7695.31 0.991 0.683 I 322 7695.41 0.471 0.294 I I I ''t\ ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 6 Scout #1 I Core LaIÌ Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 323 7695.51 0.955 0.659 324 7695.60 1.03 0.709 325 7695.71 1.31 0.940 I 326 7695.81 0.377 0.226 327 7695.91 1.30 0.926 328 7695.98 0.940 0.645 I 329 7696.21 1.23 0.874 330 7696.31 3.49 2.71 331 7696.40 2.98 2.29 332 7696.50 0.999 0.691 I 333 7696.62 1.67 1.21 334 7696.71 0.204 0.110 335 7696.81 3.43 2.67 I 336 7696.91 0.276 0.157 337 7697.11 1.10 0.767 338 7697.21 2.10 1.57 339 7697.31 1.71 1.25 I 340 7697.41 2.04 1.52 341 7697.51 1.17 0.829 342 7697.60 2.41 1.82 I 343 7697.70 1.32 0.946 344 7697.78 2.65 2.02 345 7697.91 1.33 0.952 346 7698.01 3.03 2.33 I 347 7698.10 1.49 1.07 348 7698.20 3.48 2.71 349 7698.41 2.69 2.05 I 350 7698.51 5.20 4.16 351 7698.63 3.54 2.75 352 7698.71 2.04 1.52 353 7698.80 3.67 2.86 I 354 7698.91 3.18 2.46 355 7699.01 2.64 2.01 356 7699.21 2.69 2.05 I 357 7699.30 4.04 3.16 358 7699.39 2.26 1.69 359 7699.51 5.30 4.23 360 7699.61 2.09 1.55 I 361 7699.70 2.93 2.26 362 7699.81 1.51 1.09 363 7699.91 3.72 2.90 I 364 7700.06 2.12 1.58 365 7700.21 0.920 0.632 366 7700.30 2.32 1.75 367 7700.40 2.85 2.18 I 368 7700.51 2.71 2.07 I I I ¿ ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 ¡f~~ Scout #1 ~ Colville River Field I Core Lab Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 369 7700.61 1.47 1.05 370 7700.74 2.59 1.97 371 7700.81 1.18 0.831 I 372 7700.91 3.11 2.41 373 7701.03 0.411 0.251 374 7701.21 0.820 0.553 I 375 7701.31 7.60 6.23 376 7701.40 0.528 0.336 377 7701.51 5.32 4.25 378 7701.60 0.603 0.391 I 379 7701.71 5.59 4.47 380 7701.80 1.23 0.869 381 7701.91 6.25 5.05 I 382 7701.99 0.914 0.626 383 7702.21 0.884 0.603 384 7702.31 0.328 0.193 385 7702.36 0.902 0.617 I 386 7702.51 0.683 0.450 387 7702.61 1.36 0.979 388 7702.71 0.693 0.457 I 389 7702.81 1.32 0.942 390 7702.90 0.669 0.440 391 7703.03 2.09 1.55 392 7703.11 1.01 0.703 I 393 7703.21 1.98 1.47 394 7703.30 1.11 0.774 395 7703.41 1.62 1.18 I 396 7703.51 1.03 0.711 397 7703.60 3.63 2.83 398 7703.71 0.972 0.665 399 7703.80 2.16 1.61 I 400 7703.93 1.17 0.823 401 7704.01 0.230 0.127 402 7704.11 1.48 1.06 I 403 7704.21 0.389 0.235 404 7704.31 1.81 1.33 405 7704.41 0.153 0.078 406 7704.51 2.52 1.91 I 407 7704.60 0.274 0.156 408 7704.71 7.17 5.85 409 7704.78 1.12 0.782 I 410 7705.01 0.444 0.274 411 7705.12 3.29 2.54 412 7705.21 1.69 1.23 I 413 7705.31 3.06 2.36 414 7705.35 1.99 1.48 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 . 104084 Scout #1 I Core LaIÏ Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 415 7705.52 4.06 3.19 416 7705.61 1.19 0.836 417 7705.71 0.673 0.442 I 418 7705.81 1.13 0.794 419 7705.91 1.19 0.835 420 7706.03 1.56 1.13 I 421 7706.11 5.84 4.69 422 7706.21 1.38 0.990 423 7706.31 0.719 0.477 424 7706.41 1.70 1.24 I 425 7706.50 0.783 0.526 426 7706.61 1.87 1.38 427 7706.71 1.65 1.21 I 428 7706.81 1.93 1.43 429 7706.91 1.40 1.01 430 7707.03 2.52 1.91 431 7707.10 1.64 1.20 I 432 7707.21 1.19 0.838 433 7707.30 1.33 0.945 434 7707.41 1.12 0.780 I 435 7707.51 1.14 0.800 436 7707.61 1.41 1.01 437 7707.81 1.66 1.21 438 7707.91 0.989 0.683 I 439 7708.03 0.939 0.646 440 7708.21 1.03 0.718 441 7708.31 1.56 1.13 I 442 7708.36 1.29 0.919 443 7708.51 1.94 1.43 444 7708.61 1.70 1.24 445 7708.70 1.11 0.777 I 446 7708.84 1.36 0.978 447 7708.91 2.11 1.57 448 7709.01 1.18 0.828 I 449 7709.11 0.643 0.420 450 7709.21 1.47 1.06 451 7709.31 0.851 0.579 452 7709.40 1.26 0.895 I 453 7709.51 0.756 0.506 454 7709.61 1.32 0.938 455 7709.71 0.823 0.557 I 456 7709.79 1.13 0.790 457 7709.91 0.740 0.494 458 7710.01 2.30 1.73 I 459 7710.11 1.53 1.11 460 7710.21 0.576 0.371 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Commént ft md md I 461 7710.30 0.864 0.556 462 7710.41 0.966 0.667 463 7710.51 1.29 0.925 I 464 7710.61 0.780 0.523 465 7710.80 1.51 1.09 466 7710.91 5.68 4.55 467 7711.02 1.17 0.825 I 468 7711.11 4.56 3.61 469 7711.21 7.42 6.06 470 7711.31 2.50 1.90 I 471 7711.38 1.26 0.892 472 7711.51 0.746 0.498 473 7711.61 1.53 1.11 474 7711.71 0.240 0.133 I 475 7711.80 1.60 1.16 476 7711.91 0.710 0.471 477 7712.01 2.25 1.68 I 478 7712.10 0.592 0.384 479 7712.21 1.70 1.24 480 7712.30 0.607 0.396 I 481 7712.41 1.76 1.29 482 7712.51 1.22 0.868 483 7712.61 2.50 1.90 484 7712.71 0.357 0.213 I 485 7712.81 3.07 2.37 486 7712.91 1.31 0.941 487 7713.01 2.51 1.90 I 488 7713.10 0.414 0.253 489 7713.21 2.60 1.98 490 7713.31 0.561 0.361 491 7713.41 7.26 5.93 I 492 7713.51 0.388 0.216 493 7713.63 2.34 1.76 494 7713.71 0.327 0.192 I 495 7713.80 1.77 1.30 496 7713.91 0.314 0.184 497 7714.01 1.26 0.897 498 7714.10 0.523 0.332 I 499 7714.21 1.21 0.858 500 7714.31 0.506 0.320 501 7714.37 4.18 3.27 I 502 7714.51 1.11 0.781 503 7714.61 1.38 0.993 504 7714.71 0.319 0.187 505 7714.81 1.13 0.791 I 506 7714.91 0.214 0.116 I I I ~, ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 ,c,~~ Scout #1 yr...·' I ~~ Colville River Field ['ore Lab Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 507 7715.02 1.67 1.22 508 7715.10 0.359 0.214 509 7715.31 0.537 0.343 I 510 7715.41 1.42 1.02 511 7715.50 0.279 0.160 512 7715.61 1.57 1.14 I 513 7715.71 0.541 0.346 514 7715.81 2.95 2.27 515 7715.91 0.475 0.297 516 7716.05 1.39 0.997 I 517 7716.11 0.387 0.234 518 7716.21 1.26 0.892 519 7716.31 0.385 0.232 I 520 7716.41 1.37 0.987 521 7716.51 0.474 0.297 522 7716.61 0.642 0.421 523 7716.70 0.673 0.442 I 524 7716.91 0.283 0.163 525 7717.11 3.91 3.07 526 7717.21 1.94 1.44 I 527 7717.30 0.606 0.394 528 7717.51 1.07 0.746 529 7717.61 0.834 0.564 530 7717.71 0.375 0.226 I 531 7717.81 6.27 5.06 532 7717.91 0.479 0.301 533 7718.11 2.91 2.24 I 534 7718.21 2.93 2.25 535 7718.31 0.741 0.494 536 7718.41 0.886 0.605 537 7718.52 1.04 0.723 I 538 7718.61 0.395 0.239 539 7718.73 0.712 0.472 540 7718.91 1.35 0.968 I 541 7719.01 1.29 0.915 542 7719.11 1.16 0.815 543 7719.21 0.745 0.496 544 7719.31 0.955 0.660 I 545 7719.41 0.664 0.435 546 7719.51 1.04 0.721 547 7719.60 1.02 0.709 I 548 7719.70 0.677 0.446 549 7719.91 0.398 0.242 550 7720.01 0.345 0.204 I 551 7720.23 0.601 0.390 552 7720.31 1.34 0.952 I I I ~\ ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 ~ Colville River Field I Core LaIÌ Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 553 7720.51 0.453 0.282 554 7720.61 1.24 0.874 555 7720.70 0.559 0.359 I 556 7720.81 1.37 0.977 557 7720.91 0.670 0.440 558 7721.05 2.19 1.64 559 7721.11 1.21 0.860 I 560 7721.21 0.235 0.130 561 7721.31 2.78 2.13 562 7721.41 0.304 0.176 I 563 7721.54 0.376 0.224 564 7721.59 1.41 1.01 565 7721.71 0.307 0.179 I 566 7721.81 2.27 1.70 567 7721.91 0.697 0.461 568 7722.02 1.81 1.33 569 7722.11 3.00 2.31 I 570 7722.21 0.476 0.297 571 7722.31 0.890 0.609 572 7722.41 1.59 1.15 I 573 7722.51 0.458 0.285 574 7722.61 1.01 0.696 575 7722.71 0.623 0.408 576 7722.80 0.883 0.602 I 577 7722.91 0.347 0.206 578 7723.04 0.854 0.580 579 7723.11 0.094 0.043 I 580 7723.21 0.816 0.550 581 7723.30 0.249 0.140 582 7723.40 2.09 1.56 583 7723.51 0.388 0.235 I 584 7723.61 1.32 0.941 585 7723.71 0.609 0.397 586 7723.80 2.21 1.65 I 587 7723.91 0.783 0.526 588 7724.03 5.62 4.52 589 7724.11 0.406 0.248 590 7724.26 1.59 1.15 I 591 7724.31 0.316 0.185 592 7724.51 1.87 1.37 593 7724.71 1.33 0.949 I 594 7724.81 0.113 0.053 595 7724.91 0.120 0.058 596 7725.01 1.31 0.939 597 7725.11 0.138 0.069 I 598 7725.20 2.05 1.52 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Core Lab Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 599 7725.31 6.97 5.67 600 7725.40 2.57 1.95 601 7725.60 0.167 0.086 I 602 7725.71 0.626 0.410 603 7725.82 2.60 1.98 604 7725.91 0.387 0.234 I 605 7726.00 2.06 1.54 606 7726.11 0.237 0.132 607 7726.21 0.929 0.638 608 7726.30 0.505 0.320 I 609 7726.41 1.30 0.931 610 7726.52 1.66 1.21 611 7726.61 2.09 1.56 I 612 7726.71 0.380 0.229 613 7726.79 1.53 1.10 614 7726.91 0.334 0.197 615 7727.02 0.685 0.451 I 616 7727.11 0.220 0.121 617 7727.21 1.93 1.42 618 7727.30 0.328 0.193 I 619 7727.44 2.42 1.82 620 7727.51 0.200 0.107 621 7727.61 1.98 1.46 622 7727.71 0.183 0.096 I 623 7727.81 1.07 0.741 624 7727.91 1.09 0.765 625 7728.02 2.39 1.81 I 626 7728.15 0.200 0.107 627 7728.21 0.272 0.155 628 7728.31 0.290 0.167 629 7728.41 0.663 0.436 I 630 7728.51 0.079 0.034 631 7728.61 0.537 0.342 632 7728.71 0.105 0.049 I 633 7728.86 0.265 0.150 634 7728.91 0.164 0.084 635 7729.01 1.07 0.740 636 7729.10 0.157 0.080 I 637 7729.20 0.683 0.449 638 7729.33 0.252 0.142 639 7729.40 1.04 0.719 I 640 7729.53 0.579 0.374 641 7729.70 0.328 0.193 642 7729.80 2.61 1.98 I 643 7729.91 0.196 0.105 644 7730.02 2.14 1.61 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 . 104084 Scout #1 I Core laI:Î Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 645 7730.11 0.550 0.353 646 7730.21 1.67 1.22 647 7730.31 0.306 0.178 I 648 7730.41 3.96 3.11 649 7730.50 0.240 0.134 650 7730.60 1.52 1.09 I 651 7730.70 0.194 0.103 652 7730.80 2.05 1.52 653 7730.91 0.300 0.174 654 7731.03 1.28 0.911 I 655 7731.10 0.403 0.245 656 7731.21 1.79 1.31 657 7731.30 0.236 0.131 I 658 7731.40 2.13 1.59 659 7731.51 0.180 0.095 660 7731.61 0.278 0.158 661 7731.70 1.29 0.913 I 662 7731.80 0.354 0.211 663 7731.90 0.577 0.373 664 7732.03 1.74 1.28 I 665 7732.11 1.07 0.744 666 7732.21 1.77 1.30 667 7732.31 1.17 0.818 668 7732.41 1.84 1.36 I 669 7732.61 1.56 1.14 670 7732.71 3.52 2.74 671 7732.80 0.486 0.305 I 672 7732.90 0.596 0.387 673 7733.11 1.20 0.848 674 7733.22 0.392 0.219 675 7733.31 1.33 0.950 I 676 7733.40 1.22 0.857 677 7733.51 0.515 0.327 678 7733.61 2.48 1.88 I 679 7733.70 1.11 0.776 680 7733.80 1.73 1.27 681 7733.90 0.390 0.236 682 7734.02 1.31 0.935 I 683 7734.10 0.427 0.263 684 7734.21 1.83 1.35 685 7734.30 0.465 0.290 I 686 7734.41 1.83 1.35 687 7734.50 0.483 0.303 688 7734.61 1.24 0.873 I 689 7734.70 0.284 0.163 690 7734.81 0.941 0.647 I I I 4\ ConocoPhillips Alaska Inc. CL File No. : 57111 -104084 Scout #1 I àììiiL,.. Colville River Field Core Lab Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 691 7734.91 0.582 0.376 692 7735.02 1.19 0.840 693 7735.10 0.397 0.241 I 694 7735.21 2.17 1.62 695 7735.30 0.432 0.266 696 7735.40 1.40 1.00 I 697 7735.55 0.412 0.251 698 7735.61 1.37 0.980 699 7735.80 1.11 0.776 700 7735.90 1.57 1.14 I 701 7736.01 0.905 0.619 702 7736.11 0.546 0.350 703 7736.20 1.24 0.874 I 704 7736.31 0.384 0.233 705 7736.41 1.53 1.11 706 7736.50 1.30 0.927 707 7736.61 1.19 0.838 I 708 7736.71 0.498 0.315 709 7736.81 1.21 0.852 710 7736.91 0.708 0.469 I 711 7737.02 1.54 1.11 712 7737.11 1.56 1.13 713 7737.20 1.55 1.12 714 7737.31 0.312 0.182 I 715 7737.40 1.61 1.17 716 7737.51 0.412 0.252 717 7737.61 1.53 1.11 I 718 7737.71 0.442 0.273 719 7737.80 1.32 0.940 720 7737.90 0.329 0.194 721 7738.01 3.39 2.62 I 722 7738.10 1.21 0.851 723 7738.21 2.73 2.09 724 7738.31 2.05 1.52 I 725 7738.40 0.496 0.312 726 7738.51 0.663 0.435 727 7738.60 0.510 0.322 728 7738.71 0.783 0.525 I 729 7738.81 1.11 0.777 730 7738.91 0.832 0.563 731 7739.02 1.08 0.749 I 732 7739.15 0.999 0.689 733 7739.20 1.03 0.710 734 7739.30 0.895 0.611 735 7739.40 0.819 0.553 I 736 7739.50 0.907 0.621 I I I ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I ÜJr"e L.aI:Ì Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 737 7739.60 1.65 1.20 738 7739.70 2.56 1.95 739 7739.80 2.66 2.02 I 740 7739.90 0.550 0.351 741 7740.01 0.627 0.409 742 7740.10 0.989 0.681 743 7740.20 0.674 0.444 I 744 7740.30 1.29 0.921 745 7740.40 1.07 0.741 746 7740.51 1.18 0.830 I 747 7740.60 0.664 0.437 748 7740.70 0.489 0.306 749 7740.80 2.72 2.07 I 750 7740.90 1.02 0.702 751 7741.00 0.359 0.214 752 7741.10 1.21 0.848 753 7741.20 0.977 0.675 I 754 7741.30 0.917 0.628 755 7741.40 0.605 0.392 756 7741.47 0.617 0.402 I 757 7741.61 1.17 0.821 758 7741.70 1.89 1.40 759 7741.82 1.01 0.699 760 7741.90 0.660 0.432 I 761 7742.04 0.599 0.389 762 7742.10 8.07 6.64 763 7742.10 0.497 0.313 I 764 7742.20 0.941 0.647 765 7742.30 1.09 0.760 766 7742.40 0.504 0.318 767 7742.50 0.599 0.388 I 768 7742.60 0.499 0.314 769 7742.70 0.640 0.419 770 7742.80 0.609 0.396 I 771 7742.90 1.51 1.09 772 7743.10 0.949 0.653 773 7743.23 1.32 0.942 774 7743.30 0.450 0.278 I 775 7743.40 0.385 0.232 776 7743.50 0.487 0.306 777 7743.60 0.522 0.331 I 778 7743.70 0.348 0.206 779 7743.80 0.503 0.317 780 7743.90 0.946 0.651 781 7744.00 0.856 0.581 I 782 7744.10 3.98 3.12 I I I A\ ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 Scout #1 I Core Lab Colville River Field Pressure-Decay Profille Permeability I Point Depth Ka KI Comment ft md md I 783 7744.20 0.431 0.265 784 7744.30 0.365 0.218 785 7744.40 0.267 0.151 I 786 7744.49 0.717 0.475 787 7744.70 0.392 0.237 788 7744.80 0.560 0.359 I 789 7744.90 1.29 0.920 790 7745.01 1.25 0.884 791 7745.11 1.22 0.860 792 7745.21 1.04 0.721 I 793 7745.30 1.36 0.977 794 7745.40 1.20 0.841 795 7745.50 2.14 1.60 I 796 7745.60 3.07 2.37 797 7745.70 2.53 1.92 798 7745.80 0.654 0.429 799 7745.90 0.709 0.469 I 800 7746.00 0.636 0.416 801 7746.10 1.35 0.962 802 7746.20 4.37 3.44 I 803 7746.30 4.68 3.71 804 7746.40 2.23 1.67 805 7746.50 1.15 0.809 806 7746.60 0.685 0.450 I 807 7746.70 1.31 0.935 808 7746.80 3.28 2.53 809 7746.90 1.34 0.959 I 810 7747.00 1.11 0.778 811 7747.10 0.835 0.565 812 7747.19 0.979 0.677 813 7747.30 1.31 0.930 I 814 7747.40 3.72 2.90 815 7747.52 2.68 2.04 816 7747.60 0.666 0.439 I 817 7747.70 1.19 0.841 818 7747.80 1.31 0.933 819 7747.90 1.23 0.865 820 7748.03 1.47 1.06 I 821 7748.10 1.20 0.850 822 7748.20 0.849 0.575 823 7748.30 0.989 0.684 I 824 7748.40 1.34 0.961 825 7748.50 0.925 0.635 826 7748.60 1.15 0.808 I 827 7748.70 1.17 0.823 828 7748.80 1.24 0.878 I I I I I I I I I I I I I I I I I I I I ~ ConocoPhillips Alaska Inc. CL File No. : 57111 - 104084 ~\ Scout #1 ~iB~ Colville River Field [ore I..aI:i Pressure-Decay Profille Permeability Point Depth Ka KI Comment ft md md 829 7748.90 1.35 0.966 830 7749.03 0.682 0.451 831 7749.10 0.846 0.574 832 7749.20 1.17 0.820 833 7749.30 1.34 0.963 834 7749.40 1.16 0.813 835 7749.50 2.11 1.57 836 7749.60 0.714 0.472 837 7749.70 0.932 0.640 838 7749.80 1.23 0.873 839 7749.90 0.827 0.559 840 7750.02 1.24 0.881 841 7750.10 0.985 0.679 842 7750.17 1.19 0.839 843 7750.30 0.368 0.220 844 7750.40 0.765 0.511 845 7750.50 0.764 0.511 846 7750.60 1.23 0.874 847 7750.70 0.535 0.340 848 7750.80 0.455 0.282 849 7750.90 0.445 0.275 850 7751.00 0.286 0.164 851 7751.10 0.374 0.225 852 7751.20 1.06 0.738 853 7751.27 0.800 0.538 854 7751.59 2.81 2.15 855 7751.68 0.594 0.385 856 7751.82 0.714 0.472 857 7751.90 0.697 0.459 858 7752.00 3.45 2.68 859 7752.26 3.54 2.75 860 7752.30 0.769 0.515 861 7752.40 0.882 0.602 862 7752.50 1.80 1.33 863 7752.60 2.95 2.27 864 7752.70 1.48 1.06 I ConocoPhillips Alaska File No. : 57111 = 104084CP I Scout #1 API No. : 50 = 103 = 20479 Colville River Field Date: March 23, 2004 I Core Gamma Surface log I 7662.00 31 7662.56 27 I 7663.11 30 7663.67 23 7660 7664.22 27 7664.78 35 I 7665.33 29 7665.89 30 7666.45 23 7670 7667.00 34 I 7667.56 31 7668.11 29 7668.67 31 7669.22 37 7680 7669.78 30 I 7670.34 28 7670.89 33 7671.45 28 I 7672.00 29 7672.56 27 7690 7673.11 28 7673.67 26 I 7674.23 37 7674.78 30 7675.34 25 7700 7675.89 39 I 7676.45 25 7677.00 27 - ¢: 7677.56 35 .....- 7678.11 30 7710 I 7678.67 27 7679.23 34 7679.78 25 7680.34 28 7680.89 36 7720 I 7681.45 31 7682.00 23 7682.56 31 I 7683.12 36 7683.67 39 7730 7684.23 32 7684.78 35 I 7685.34 36 7685.89 31 7686.45 32 7740 7687.01 31 I 7687.56 26 7688.12 32 7688.67 28 7689.23 40 I 7689.78 34 7690.34 26 7690.90 32 7691.45 29 I 7692.01 40 7692.56 26 7693.12 26 7693.67 40 I I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Scout #1 Colville River Field Core Gamma Suñace Log Depth Gamma (ft) API 7694.23 28 7694.78 29 7695.34 21 7695.90 30 7696.45 23 7697.01 30 7697.56 36 7698.12 31 7698.67 26 7699.23 19 7699.79 24 7700.34 29 7700.90 38 7701.45 23 7702.01 35 7702.56 33 7703.12 31 7703.68 27 7704.23 28 7704.79 29 7705.34 17 7705.90 26 7706.45 23 7707.01 37 7707.56 38 7708.12 29 7708.68 37 7709.23 26 7709.79 38 7710.34 25 7710.90 36 7711.45 32 7712.01 40 7712.57 23 7713.12 43 7713.68 26 7714.23 39 7714.79 39 7715.34 29 7715.90 30 7716.46 28 7717.01 35 7717.57 28 7718.12 29 7718.68 31 7719.23 25 7719.79 20 7720.35 35 7720.90 27 7721.46 31 7722.01 31 7722.57 38 7723.12 33 7723.68 30 7724.23 31 7724.79 26 7725.35 36 7725.90 31 File No. : 57111 . 104084CP API No. : 50-103 - 20479 Date: March 23, 2004 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Scout #1 Colville River Field Core Gamma Suñace Log Depth Gamma (ft) API 7726.46 24 7727.01 30 7727.57 28 7728.12 34 7728.68 24 7729.24 30 7729.79 38 7730.35 38 7730.90 30 7731.46 28 7732.01 27 7732.57 39 7733.13 38 7733.68 16 7734.24 45 7734.79 34 7735.35 30 7735.90 32 7736.46 27 7737.02 28 7737.57 25 7738.13 38 7738.68 34 7739.24 22 7739.79 23 7740.35 44 7740.90 30 7741.46 33 7742.02 26 7742.57 32 7743.13 36 7743.68 26 7744.24 39 7744.79 33 7745.35 29 7745.91 35 7746.46 44 7747.02 33 7747.57 32 7748.13 27 7748.68 26 7749.24 19 7749.80 35 7750.35 26 7750.91 29 7751.46 27 7752.02 31 7752.57 25 File No. : 57111 -104084CP API No. : 50 - 103 - 20479 Date: March 23, 2004 ------------------- ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 - 104084CP API No. : 50 - 103 - 20477 Core Lab Scout #1 Well - Iodide Analysis I Avg I in Mud = 696 mg/L Smpl Depth OS Water Rock Wt 0.1. Water I Concen I Mass Mud Vol Lab Swi Corr Swi (cc) (g) (cc) (mg/L) (mg) (cc) (%) (%) 1 7662.0 1.30 64.500 96.520 nd n/a n/a 37.6 n/a 3 7664.0 1. 42 66.190 100.140 nd n/a n/a 41.3 n/a 5 7666.0 1. 36 60.160 90.730 0.173 0.016 0.023 44.3 43.6 7 7668.0 1.23 54.200 81.700 0.200 0.016 0.023 44.9 44.0 9 7670.0 1.19 58.520 87.760 0.114 0.010 0.014 32.8 32.4 11 7672.0 1. 39 62.920 93.840 0.149 0.014 0.020 39.2 38.6 13 7674.0 1.14 54.270 80.920 0.148 0.012 0.017 38.4 37.8 15 7676.0 0.69 36.660 76.400 0.114 0.009 0.013 40.6 39.9 17 7678.0 1.25 55.940 83.180 0.176 0.015 0.021 47.2 46.4 19 7680.0 1.40 69.380 103.600 0.232 0.024 0.035 46.1 45.0 21 7682.0 0.89 59.240 89.100 0.242 0.022 0.031 24.5 23.6 23 7684.0 0.40 37.990 83.810 0.270 0.023 0.032 14.6 13.4 25 7686.0 1. 02 54.770 84.530 0.168 0.014 0.020 33.2 32.5 27 7688.0 1.14 59.980 89.270 0.862 0.077 0.111 25.4 22.9 29 7690.0 1. 03 57.340 87.300 0.178 0.016 0.022 33.6 32.9 31 7692.0 0.98 62.940 94.490 0.146 0.014 0.020 22.5 22.0 33 7694.0 0.90 64.420 98.020 0.210 0.021 0.030 22.3 21.6 35 7696.0 1.28 63.760 95.370 0.153 0.015 0.021 38.0 37.4 37 7698.0 0.94 55.680 83.620 0.253 0.021 0.030 18.5 17.9 39 7700.0 1.29 65.670 98.900 0.216 0.021 0.031 39.2 38.3 41 7702.0 1. 00 54.920 82.700 0.145 0.012 0.017 30.6 30.1 43 7704.0 1.29 63.500 95.530 0.156 0.015 0.021 39.1 38.5 45 7706.0 1.16 63.960 96.670 0.165 0.016 0.023 31.3 30.7 47 7708.0 1.26 64.200 96.950 0.209 0.020 0.029 33.8 33.0 49 7710.0 1. 08 70.980 106.550 0.141 0.015 0.022 24.8 24.3 51 7712.0 1. 06 63.150 94.760 0.141 0.013 0.019 29.6 29.1 53 7714.0 1.13 61. 960 99.730 0.094 0.009 0.013 33.5 33.1 55 7716.0 1.21 58.860 89.880 0.134 0.012 0.017 48.3 47.6 ------------------- ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 - 104084CP API No. : 50 - 103 - 20477 Core Lab Scout #1 Well - Iodide Analysis I Avg I in Mud = 696 mg/L Smpl Depth OS Water Rock Wt 0.1. Water I Concen I Mass Mud Vol Lab Swi Corr Swi (cc) (g) (cc) (mg/L) (mg) (cc) (%) (%) 57 7718.0 0.66 63.780 96.820 0.120 0.012 0.017 26.9 26.2 59 7720.0 0.69 35.940 86.750 0.098 0.009 0.012 48.4 47.5 61 7722.0 0.71 38.360 82.490 0.124 0.010 0.015 41. 0 40.2 63 7724.0 0.58 25.110 86.700 0.076 0.007 0.009 77.9 76.6 65 7726.0 1. 39 68.820 119.330 0.107 0.013 0.018 51.9 51.2 67 7728.0 0.80 38.890 81.360 0.134 0.011 0.016 60.1 58.9 69 7730.0 1.10 62.270 93.930 0.099 0.009 0.013 34.8 34.4 71 7732.0 1. 30 64.940 97.710 0.153 0.015 0.021 49.8 49.0 73 7734.0 1.13 59.640 89.340 0.118 0.011 0.015 41.8 41.2 75 7736.0 0.64 59.160 89.420 0.192 0.017 0.025 23.7 22.8 77 7738.0 1. 00 60.110 90.140 0.218 0.020 0.028 32.3 31.4 79 7740.0 1. 00 59.050 88.170 0.165 0.015 0.021 33.4 32.7 81 7742.0 0.55 49.640 76.160 0.170 0.013 0.019 23.6 22.8 83 7744.0 0.59 29.720 61.770 0.143 0.009 0.013 62.9 61.5 85 7746.0 0.60 49.260 74.480 0.194 0.014 0.021 31.0 29.9 87 7748.0 0.31 44.710 72.570 0.194 0.014 0.020 18.6 17 .4 89 7750.0 0.39 56.030 84.800 0.141 0.012 0.017 14.8 14.1 91 7751. 9 0.99 60.820 87.150 0.161 0.014 0.020 32.8 32.1 ------------------- ~, n,~) ~!;i~.", ~. Core Lab ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 -104084CP API No. : 50 -103 - 20477 Tracer - Chloride Analysis I Avg CI in Mud = 33,980 mg/L Smpl Depth DS Water Rock Wt. D.I. Water CIConcen CI Mass Mud Vol; Corr CI Equiv NaCI (cc) (g) (cc) (mg/L) (mg) (cc) (ppm) TDS (ppm) 1 7662.0 1.30 64.50 96.52 187.302 18.078 n/a n/a n/a 3 7664.0 1.42 66.19 100.14 179.800 18.005 n/a n/a n/a 5 7666.0 1.36 60.16 90.73 177.580 16.112 0.023 11474 18918 7 7668.0 1.23 54.20 81.70 189.881 15.513 0.023 12197 20110 9 7670.0 1.19 58.52 87.76 177.617 15.588 0.014 12844 21177 11 7672.0 1. 39 62.92 93.84 192.854 18.097 0.020 12713 20960 13 7674.0 1.14 54.27 80.92 190.959 15.452 0.017 13242 21833 15 7676.0 0.69 36.66 76.40 141. 058 10.777 0.013 15280 25193 17 7678.0 1.25 55.94 83.18 162.666 13.531 0.021 10428 17194 19 7680.0 1.40 69.38 103.60 166.490 17.248 0.035 11773 19411 21 7682.0 0.89 59.24 89.10 136.704 12.180 0.031 12954 21359 23 7684.0 0.40 37.99 83.81 101. 876 8.538 0.032 20228 33353 25 7686.0 1. 02 54.77 84.53 161.668 13.666 0.020 12978 21398 27 7688.0 1.14 59.98 89.27 272.026 24.284 0.111 19941 32878 29 7690.0 1. 03 57.34 87.30 161. 482 14.097 0.022 13237 21826 31 7692.0 0.98 62.94 94.49 139.466 13 .178 0.020 13023 21473 33 7694.0 0.90 64.42 98.02 151.118 14.813 0.030 15863 26156 35 7696.0 1.28 63.76 95.37 158.581 15.124 0.021 11447 18873 37 7698.0 0.94 55.68 83.62 182.228 15.238 0.030 15617 25749 39 7700.0 1.29 65.67 98.90 169.389 16.753 0.031 12475 20569 41 7702.0 1. 00 54.92 82.70 167.005 13.811 0.017 13458 22189 43 7704.0 1.29 63.50 95.53 167.014 15.955 0.021 12004 19791 45 7706.0 1.16 63.96 96.67 167.905 16.231 0.023 13590 22407 47 7708.0 1.26 64.20 96.95 170.331 16.514 0.029 12613 20796 49 7710.0 1. 08 70.98 106.55 208.415 22.207 0.022 20288 33451 51 7712.0 1. 06 63.15 94.76 186.324 17.656 0.019 16337 26937 53 7714.0 1.13 61. 96 99.73 184.237 18.374 0.013 16046 26457 * based upon Iodide mud invasion numbers ------------------- ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 - 104084CP API No. : 50 - 103 - 20477 Core Lab Tracer - Chloride Analysis ~ Avg CI in Mud = 33,980 mg/L Smpl Depth DS Water Rock Wt. DJ. Watel CIConcen CI Mass Mud Vol' Corr CI Equiv NaCI (cc) (g) (cc) (mg/L) (mg) (cc) (ppm) TDS(ppm) 55 7716.0 1.21 58.86 89.88 185.233 16.649 0.017 13466 22203 57 7718.0 0.66 63.78 96.82 223.238 21. 614 0.017 32716 53943 59 7720.0 0.69 35.94 86.75 119.158 10.337 0.012 14639 24137 61 7722.0 0.71 38.36 82.49 153.048 12.625 0.015 17439 28754 63 7724.0 0.58 25.11 86.70 86.671 7.514 0.009 12607 20787 65 7726.0 1. 39 68.82 119.33 185.346 22.117 0.018 15670 25837 67 7728.0 0.80 38.89 81.36 161.124 13.109 0.016 16035 26439 69 7730.0 1.10 62.27 93.93 199.079 18.699 0.013 16791 27685 71 7732.0 1.30 64.94 97.71 217.151 21.218 0.021 16025 26422 73 7734.0 1.13 59.64 89.34 197.848 17.676 0.015 15393 25380 75 7736.0 0.64 59.16 89.42 180.389 16.130 0.025 24852 40976 77 7738.0 1. 00 60.11 90.14 163.761 14.761 0.028 14203 23419 79 7740.0 1. 00 59.05 88.17 168.910 14.893 0.021 14486 23884 81 7742.0 0.55 49.64 76.16 180.174 13.722 0.019 24633 40615 83 7744.0 0.59 29.72 61.77 124.376 7.683 0.013 12561 20711 85 7746.0 0.60 49.26 74.48 195.901 14.591 0.021 23972 39525 87 7748.0 0.31 44.71 72 .57 164.503 11.938 0.020 38826 64016 89 7750.0 0.39 56.03 84.80 163.199 13.839 0.017 35555 58623 91 7751. 9 0.99 60.82 87.15 179.013 15.601 0.020 15380 25359 Average 27,254 * based upon Iodide mud invasion numbers I I I I I I I I I I I I I I I I I I I BRINE PERM CALCULATION SHEET CLIENT SAMPLE 04021-CT LENGTH 112 AREA 3.847 11. 424 TEMP VIS. AMB 0.9829 TIME Pob Pp RATE DELTA P PERM 5 1850 200 2.0 0.098 1654.9 10 1850 200 2.0 0.097 1672.0 15 1850 200 3.0 0.148 1643.8 20 1850 200 3.0 0.148 1647.1 25 1850 200 4.0 0.198 1642.4 30 1850 200 4.0 0.199 1630.0 1648.4. CLIENT SAMPLE 04021-CT LENGTH 117 AREA 4.218 11. 353 TEMP VIS. AMB 0.9829 TIME Pob Pp RATE DELTA P PERM 5 1850 200 2.0 0.067 2670.7 10 1850 200 2.0 0.067 2670.7 15 1850 200 3.0 0.102 2631.4 20 1850 200 3.0 0.103 2605.9 25 1850 200 4.0 0.138 2593.3 30 1850 200 4.0 0.142 2529.2 2616.9 CLIENT SAMPLE 04021-CT LENGTH 122 AREA 5.169 11.181 TEMP VIS. AMB 0.9829 TIME Pob Pp RATE DELTA P PERM 5 1850 200 2.0 0.064 3479.0 10 1850 200 2.0 0.062 3591.2 15 1850 200 3.0 0.094 3553.0 20 1850 200 3.0 0.095 3515.6 25 1850 200 4.0 0.122 3650.1 30 1850 200 4.0 0.124 3591. 2 3563.3 CLIENT SAMPLE 04021-CT LENGTH 128 AREA 5.172 11.371 TEMP VIS. AMB 0.9829 TIME Pob Pp RATE DELTA P PERM 5 1850 200 2.0 1. 650 132.8 10 1850 200 2.0 1.655 132.4 15 1850 200 3.0 2.483 132.3 20 1850 200 3.0 2.471 133.0 25 1850 200 4.0 3.285 133.4 30 1850 200 4.0 3.300 132.8 132.8 ----------- ------- - ConocoPhillips Alaska Inc File No. : 57111 - 104084CP Scout #1 API No. : 50 - 103 - 20477 Core Lab Colville River Field Tracer Analysis Sample # Depth Pore Water Tracer Concentration Lab Volume Volume Iodide Chloride Swi cc cc ppm 0/0 Blank H2O nd nd na 1 7662.0 3.45 1.30 64.550 64.50 96.52 nd 187.302 37.6 3 7664.0 3.44 1.42 66.288 66.19 100.140 nd 179.800 41.3 5 7666.0 3.07 1.36 60.237 60.16 90.73 0.173 177.580 44.3 7 7668.0 2.74 1.23 54.377 54.20 81.70 0.200 189.881 44.9 9 7670.0 3.63 1.19 58.647 58.52 87.76 0.114 177.617 32.8 11 7672.0 3.55 1.39 63.172 62.92 93.84 0.149 192 . 854 39.2 13 7674.0 2.97 1.14 54.331 54.27 80.92 0.148 190.959 38.4 15 7676.0 1. 70 0.69 36.744 36.66 76.40 0.114 141. 058 40.6 17 7678.0 2.65 1.25 56.069 55.94 83.18 0.176 162.666 47.2 19 7680.0 3.03 1.40 69.471 69.38 103.60 0.232 166.490 46.1 21 7682.0 3.63 0.89 59.306 59.24 89.10 0.242 136.704 24.5 23 7684.0 2.74 0.40 38.046 37.99 83.81 0.270 101. 876 14.6 25 7686.0 3.07 1. 02 54.876 54.77 84.53 0.168 161. 668 33.2 27 7688.0 4.48 1.14 60.040 59.98 89.27 0.862 272.026 25.4 29 7690.0 3.07 1. 03 57.460 57.34 87.30 0.178 161. 482 33.6 31 7692.0 4.36 0.98 63.021 62.94 94.49 0.146 139.466 22.5 33 7694.0 4.04 0.90 64.565 64.42 98.02 0.210 151.118 22.3 35 7696.0 3.37 1.28 63.957 63.76 95.37 0.153 158.581 38.0 37 7698.0 5.09 0.94 55.803 55.68 83.62 0.253 182.228 18.5 39 7700.0 3.29 1.29 65.840 65.67 98.90 0.216 169.389 39.2 41 7702.0 3.27 1. 00 55.105 54.92 82.70 0.145 167.005 30.6 43 7704.0 3.30 1.29 63.643 63.50 95.53 0.156 167.014 39.1 45 7706.0 3.71 1.16 64.048 63.96 96.67 0.165 167.905 31.3 47 7708.0 3.73 1.26 64.351 64.20 96.95 0.209 170.331 33.8 49 7710.0 4.36 1. 08 71.191 70.98 106.55 0.141 208.415 24.8 51 7712.0 3.58 1. 06 63.284 63.15 94.76 0.141 186.324 29.6 53 7714.0 3.37 1.13 62.076 61. 96 99.73 0.094 184.237 33.5 55 7716.0 2.50 1.21 59.080 58.86 89.88 0.134 185.233 48.3 ------------------- ConocoPhillips Alaska Inc File No. : 57111 - 104084CP Scout #1 API No. : 50 - 103 - 20477 Core Lab Colville River Field Tracer Analysis Sample # Depth Pore Water Tracer Concentration Lab Volume Volume Iodide Chloride Swi cc cc pm ppm % 57 7718.0 2.45 0.66 64.025 63.78 96.82 0.120 223.238 26.9 59 7720.0 1.43 0.69 36.132 35.94 86.75 0.098 119.158 48.4 61 7722.0 1. 73 0.71 38.504 38.36 82.49 0.124 153.048 41.0 63 7724.0 0.75 0.58 25.241 25.11 86.70 0.076 86.671 77 .9 65 7726.0 2.68 1.39 69.074 68.82 119.33 0.107 185.346 51. 9 67 7728.0 1.33 0.80 39.001 38.89 81. 36 0.134 161.124 60.1 69 7730.0 3.16 1.10 62.377 62.27 93.93 0.099 199.079 34.8 71 7732.0 2.61 1. 30 65.045 64.94 97.71 0.153 217.151 49.8 73 7734.0 2.71 1.13 59.714 59.64 89.34 0.118 197.848 41. 8 75 7736.0 2.70 0.64 59.240 59.16 89.42 0.192 180.389 23.7 77 7738.0 3.10 1. 00 60.179 60.11 90.14 0.218 163.761 32.3 79 7740.0 3.00 1. 00 59.145 59.05 88.17 0.165 168.910 33.4 81 77 42 . 0 2.33 0.55 49.779 49.64 76.16 0.170 180.174 23.6 83 7744.0 0.94 0.59 29.939 29.72 61. 77 0.143 124.376 62.9 85 7746.0 1. 94 0.60 49.401 49.26 74.48 0.194 195.901 31.0 87 7748.0 1. 66 0.31 44.837 44.71 72.57 0.194 164.503 18.6 89 7750.0 2.64 0.39 56.053 56.03 84.80 0.141 163.199 14.8 91 7751.9 3.02 0.99 60.839 60.82 87.15 0.161 179.013 32.8 ------------------- A..........~..........'..~.. êl&;,f{ .;:::.. It~ Core Lab ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 . 104084CP APINo.:50·103·20477 Density of Mud Sample Extracts . Location 881-96 Scout #1 M 1 7662.0 Suction pit 779.301 36151. 508 1. 033 881-97 Scout #1 M 2 7663.0 Flowline 703.133 36010.652 1. 037 881-98 Scout #1 M 3 7677.0 Flowline 682.260 38769.922 1. 022 881-99 Scout #1 M 4 7692.0 Flowline 740.703 32317.447 1. 020 881-100 Scout #1 M 5 7707.0 Flowline 629.249 32442.426 1. 021 881-101 Scout #1 M 6 7722.0 Flowline 849.343 32873.227 1. 014 881-102 Scout #1 M 7 7737.0 Flowline 589.540 30598.900 1.019 881-103 Scout #1 M 8 7752.0 Flowline 573.703 29533.096 1. 017 881-104 Scout #1 M 9 7752.0 Suction Pit 585.332 30538.264 1. 015 Averages 681. 396 33248.382 1.022 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 - 104084CP API No. : 50 -103-20479 Date: March 23, 2004 Bulk Core Inventory 1 7662.0 - 7665.0 17 7710.0 - 7713.0 2 7665.0 - 7668.0 18 7713.0 - 7716.0 3 7668.0 - 7671.0 19 7716.0 - 7719.0 4 7671.0 - 7674.0 20 7719.0 - 7722.0 5 7674.0 - 7677.0 21 7722.0 - 7725.0 6 7677.0 - 7680.0 22 7725.0 - 7728.0 7 7680.0 - 7683.0 23 7728.0 - 7731.0 8 7683.0 - 7686.0 24 7731.0 - 7734.0 9 7686.0 - 7689.0 25 7734.0 - 7737.0 10 7689.0 - 7692.0 26 7737.0 - 7740.0 11 7692.0 - 7695.0 27 7740.0 - 7743.0 12 7695.0 - 7698.0 28 7743.0 - 7746.0 13 7698.0 - 7701.0 29 7746.0 - 7749.0 14 7701.0 - 7704.0 30 7749.0 - 7752.0 15 7704.0 - 7707.0 31 7752.0 - 7752.7 16 7707.0 - 7710.0 I I I I I I I I I I I I I I I I I I I [ore Lab ConocoPhillips Alaska Inc Scout #1 Colville River Field Slabbed Core Inventory 1 7662.0 - 7674.0 2 7674.0 - 7686.0 3 7686.0 - 7696.4 4 7696.4 - 7708.4 5 7708.4 - 7720.4 6 7720.4 - 7726.5 7 7726.5 - 7735.5 8 7735.5 - 7744.5 9 7744.5 - 7752.7 File No. : 57111 . 104084CP API No. : 50 - 103 - 20479 Date: March 23, 2004 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc File No. : 57111 - 104084CP Scout #1 API No. : 50 -103 - 20479 Core Lab Colville River Field Date: March 23, 2004 Horizontal Sample Inventory 1 7662.30 26 7687.30 51 7712.30 76 7737.30 2 7663.30 27 7688.30 52 7713.30 77 7738.40 3 7664.30 28 7689.30 53 7714.30 78 7739.30 4 7665.40 29 7690.30 54 7715.30 79 7740.30 . 5 7666.30 30 7691.30 55 7716.30 80 7741.40 6 7667.30 31 7692.30 56 7717.30 81 7742.30 7 7668.30 32 7693.30 57 7718.30 82 7743.30 8 7669.30 33 7694.30 58 7719.30 83 7744.40 9 7670.30 34 7695.30 59 7720.30 84 7745.30 10 7671.40 35 7696.30 60 7721.25 85 7746.30 11 7672.30 36 7697.30 61 7722.30 86 7747.40 12 7673.30 37 7698.30 62 7723.40 87 7748.30 13 7674.20 38 769!l30 63 7724.30 88 7749.30 14 7675.30 39 7700.30 64 7725.40 89 7750.30 15 7676.20 40 7701.30 65 7726.40 90 7751.70 16 7677.30 41 7702.30 66 7727.30 91 7752.60 17 7678.40 42 7703.30 67 7728.30 18 7679.30 43 7704.30 68 7729.40 19 7680.40 44 7705.60 69 7730.30 20 7681.40 45 7706.30 70 7731.40 21 7682.30 46 7707.30 71 7732.40 22 7683.30 47 7708.30 72 7733.25 23 7684.30 48 7709.30 73 7734.30 24 7685.30 49 7710.30 74 7735.30 25 7686.30 50 7711.30 75 7736.30 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc File No. : 57111 - 104084CP Scout #1 API No. : 50 . 103 - 20479 [ore Lab Colville River Field Date: March 23, 2004 Vertical Sample Inventory TR denotes samples selected for tracer extraction 1 7662.0 TR 25 7686.0 TR 49 7710.0 TR 73 7734.0 TR 2 7663.0 26 7687.0 50 7711.0 74 7735.0 3 7664.0 TR 27 7688.0 TR 51 7712.0 TR 75 7736.0 TR 4 7665.0 28 7689.0 52 7713.0 76 7737.0 5 7666.0 TR 29 7690.0 TR 53 7714.0 TR 77 7738.0 TR 6 7667.0 30 7691.0 54 7715.0 78 7739.0' 7 7668.0 TR 31 7692.0 TR 55 7716.0 TR 79 7740.0 TR 8 7669.0 32 7693.0 56 7717.0 80 7741.0 9 7670.0 TR 33 7694.0 TR 57 7718.0 TR 81 7742.0 TR 10 7671.0 34 7695.0 58 7719.0 82 7743.0 11 7672.0 TR 35 7696.0 TR 59 7720.0 TR 83 7744.0 TR 12 7673.0 36 7697.0 60 7720.9 84 7745.0 13 7674.1 TR 37 7698.0 TR 61 7722.0 TR 85 7746.0 TR 14 7675.0 38 7699.0 62 7723.0 86 7747.0 15 7676.0 TR 39 7700.0 TR 63 7724.0 TR 87 7748.0 TR 16 7677.0 40 7701.0 64 7725.0 88 7749.0 17 7678.0 TR 41 7702.0 TR 65 7726.0 TR 89 7750.0 TR 18 7679.0 42 7703.0 66 7727.0 90 7751.0 19 7680.0 TR 43 7704.0 TR 67 7728.0 TR 91 7751.9 TR 20 7681.0 44 7705.1 68 7729.0 21 7682.0 TR 45 7706.0 TR 69 7730.0 TR 22 7683.0 46 7707.0 70 7731.0 23 7684.0 TR 47 7708.0 TR 71 7732.0 TR 24 7685.0 48 7709.0 72 7733.0 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc File No. : 57111 - 104084CP Scout #1 API No. : 50-103-20479 Core Lab Colville River Field Date: March 23, 2004 Alaska State Samples 1 7662.0 26 7687.0 51 7712.0 76 7737.0 2 7663.0 27 7688.0 52 7713.0 77 7738.0 3 7664.0 28 7689.0 53 7714.0 78 7739.0 4 7665.0 29 7690.0 54 7715.0 79 7740.0 5 7666.0 30 7691.0 55 7716.0 80 7741.0 6 7667.0 31 7692.0 56 7717.0 81 7742.0 7 7668.0 32 7693.0 57 7718.0 82 7743.0 8 7669.0 33 7694.0 58 7719.0 83 7744.0 9 7670.0 34 7695.0 59 7720.0 84 7745.0 10 7671.0 35 7696.0 60 7721.0 85 7746.0 11 7672.0 36 7697.0 61 7722.0 86 7747.0 12 7673.0 37 7698.0 62 7723.0 87 7748.0 13 7674.0 38 7699.0 63 7724.0 88 7749.0 14 7675.0 39 7700.0 64 7725.0 89 7750.0 15 7676.0 40 7701.0 65 7726.0 90 7751.0 16 7677.0 41 7702.0 66 7727.0 91 7752.0 17 7678.0 42 7703.0 67 7728.0 18 7679.0 43 7704.0 68 7729.0 19 7680.0 44 7705.0 69 7730.0 20 7681.0 45 7706.0 70 7731.0 21 7682.0 46 7707.0 71 7732.0 22 7683.0 47 7708.0 72 7733.0 23 7684.0 48 7709.0 73 7734.0 24 7685.0 49 7710.0 74 7735.0 25 7686.0 50 7711.0 75 7736.0 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc File No. : 57111 - 104084CP Scout #1 API No. : 50 -103-20479 Core Lab Colville River Field Date: March 23, 2004 Preserve Inventory 1 7662.40 - 7663.00 31 7692.30 - 7693.00 61 7722.40 - 7723.00 2 7663.40 - 7664.00 32 7693.40 - 7694.00 62 7723.50 - 7724.00 3 7664.40 - 7665.00 33 7694.40 - 7695.00 63 7724.40 - 7725.00 4 7665.50 - 7666.00 34 7695.40 - 7696.00 64 7725.50 - 7726.00. 5 7666.40 - 7667.00 35 7696.40 - 7697.00 65 7726.50 - 7727.00 6 7667.40 - 7668.00 36 7697.40 - 7698.00 66 7727.40 - 7728.00 7 7668.40 - 7669.00 37 7698.40 - 7699.00 67 7728.40 - 7729.00 8 7669.40 - 7670.00 38 7699.40 - 7700.00 68 7729.50 - 7730.00 9 7670.40 - 7671.00 39 7700.40 - 7701.00 69 7730.40 - 7731.00 10 7671.50 - 7672.00 40 7701.40 - 7702.00 70 7731.50 - 7732.00 11 7672.40 - 7673.00 41 7702.40 - 7703.00 71 7732.50 - 7733.00 12 7673.40 - 7674.00 42 7703.40 - 7704.00 72 7733.35 - 7734.00 13 7674.30 - 7675.00 43 7704.40 - 7705.10 73 7734.40 - 7735.00 14 7675.40 - 7676.00 44 7705.70 - 7706.00 74 7735.40 - 7736.00 15 7676.30 - 7677.00 45 7706.40 - 7707.00 75 7736.40 - 7737.00 16 7677.40 - 7678.00 46 7707.40 - 7708.00 76 7737.40 - 7738.00 17 7678.50 - 7679.00 47 7708.40 - 7709.00 77 7738.50 - 7739.00 18 7679.50 - 7680.00 48 7709.40 - 7710.00 78 7739.40 - 7740.00 19 7680.50 - 7681.00 49 7710.40 - 7711.00 79 7740.40 - 7741.00 20 7681.40 - 7682.00 50 7711.40 - 7712.00 80 7741.50 - 7742.00 21 7682.40 - 7683.00 51 7712.40 - 7713.00 81 7742.40 - 7743.00 22 7683.40 - 7684.00 52 7713.40 - 7714.00 82 7743.40 - 7744.00 23 7684.40 - 7685.00 53 7714.40 - 7715.00 83 7744.50 - 7745.00 24 7685.40 - 7686.00 54 7715.40 - 7716.00 84 7745.40 - 7746.00 25 7686.40 - 7687.00 55 7716.40 - 7717.00 85 7746.40 - 7747.00 26 7687.40 - 7688.00 56 7717.40 - 7718.00 86 7747.50 - 7748.00 27 7688.40 - 7689.00 57 7718.40 - 7719.00 87 7748.40 - 7749.00 28 7689.40 - 7690.00 58 7719.40 - 7720.00 88 7749.40 - 7750.00 29 7690.40 - 7691.00 59 7720.40 - 7720.90 89 7750.40 - 7751.00 30 7691.40 - 7692.00 60 7721.50 - 7722.00 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Scout #1 Colville River Field File No. : 57111 -104084CP API No. : 50 - 103 - 20479 Date: March 23, 2004 Geochem Sample Inventory 1 7748.4 2 7749.4 3 7750.4 4 7751.4 5 7752.4