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205-123
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-20 KUPARUK RIV UNIT 1C-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-20 50-029-23273-00-00 205-123-0 W SPT 6540 2051230 1635 2529 2533 2530 2523 393 420 421 422 4YRTST P Matt Herrera 5/17/2022 MIT-IA Performed to 1900 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-20 Inspection Date: Tubing OA Packer Depth 730 1890 1860 1860IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518152916 BBL Pumped:2.1 BBL Returned:2 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 14:10:11 -08'00' Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760 fax Delivered to: / ADGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 205123 TRANSMITTAL DATE - TRANSMITTAL N �Cr7�Jiii•L�iJ♦ 1C•20 1H-04 2A-25 1H-105 1R-34 ,. 50-029-23273-00 50-029-20770-00 50-103.20239.00 50-029-20727.01 50-029-22534-00 ORDER EDEA -00011 E118-00096 EOSH-00086 EOSH-00087 EOSH-00088 FIELD KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUKRIVER KUPARUK RIVER • Memory WL WL WL WL r • ]PROF IPROF Caliper IPROF LDL-WFL r. D D I =FIELD30-Aug-19 r. • r 2-Aug-19 27 -Aug -19 28 -Aug -19 29 -Aug -19 30-Aug•19 r 1 1 1 1 1 2A -27A 50-103.20604-01 EOSH-00090 KUPARUK RIVER WL [PROF 2 -Sep -19 1 1J -156L2 1H-115 50-029.23311-61 50.029-23605.00 EDEA -00019 EOSH-00094 KUPARUK RIVER KUPARUK RIVER Memory WL (PROF IPROF FINAL FIELD FINAL FIELD 5 -Sep -19 5 -Sep -19 1 1 8 A Transmittal Receipt signature confirms that a package (box, l V / nvelope, etc.) has been received and the contents of the X 111 4/ package have been verified to match the media noted above. Print Na Signature Date The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to hl berger and CPAI. point. Schlumberger -Private VS -11. ProActive Diagnostic Services, Inc. WELL LO TRANSM1 TAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed : Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Pcisa nc h o raa e(doem orvloa.com 11 -Aug -19 1C-20 CD 205123 31140 RECEIVED AUG 2 9 2019 AOGCC 50-029-23273-00 Date: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEO-MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM Mips readcasedholemyshwepointco persomUdiane williams rmdcasedhole com/DocumentsD Drive/Achives ste,TempiatcFileiTemplates/Distributio¢TransmittaISheetvCono.Phillips_Transmit docx MEMORAND • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Rp P.I. I PSupervisor �'visor �)�'1 r`g SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-20 FROM: Austin McLeod KUPARUK RIV UNIT 1C-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-20 API Well Number 50-029-23273-00-00 Inspector Name: Austin McLeod Permit Number: 205-123-0 Inspection Date: 5/13/2018 Insp Num: mitSAM180514080917 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-20 Type Inj G 'TVD 6540 " Tubing 1 3660 3656 3653 ' 3645 ' PTD 2051230 Type Test SPT Test psi 1635 - IA 1180 - 1900 1870 ` 1865 - BBL Pumped: 1.5 - [BBL Returned: 1.4 - OA 240 246 s 11 246 - 246 - Interval 4YRTST P/F P Notes: MIT-IA SCONEp JUN 0 12018 Wednesday,May 16,2018 Page 1 of 1 STATE OF ALASKA • RECEIVED A•KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT 2 4 201/ 1.Operations Abandon 0 Plug Perforations fl Fracture Stimulate E Pull Tubing 0 Operations shutdown 0 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Program ElPlug for Redrill ❑ srforate New Pool 1=1Repair Well ❑ Re-enter Susp Well ❑ At=el mel Trtmnt E 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. ment Develo Exploratory❑ P lorato ry ❑ 205-123 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑r 6.API Number: 99510 50-029-23273-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1C-20 ADL 25649,ADL 28242,ADL28243,ADL 28244 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 21,081 feet Plugs measured None feet true vertical 6,659 feet Junk measured None feet Effective Depth measured 20,927 feet Packer measured 0 feet true vertical 6,643 feet true vertical 0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 53 feet 19" 80' MD 80'TVD SURFACE 11,073 feet 10-3/4" 11,114'MD 4570'TVD INTERMEDIATE 17,674 feet 7-5/8" 17,714' MD 6586'TVD LINER 3,414 feet 4-1/2" 20,927' MD 6643'TVD Perforation depth Measured Depth 17720'-20899' MD feet slotted liner . - • True Vertical Depth 6587'-6640'TVD feet slotted liner's , ' - • Tubing(size,grade,measured and true vertical depth) 4.5" L-80 17560' MD 6552'TVD Packers and SSSV(type,measured and true vertical depth) HRD ZXP LINER TOP PACKER • 17513' MD 6540'TVD • SSSV-NONE - - 12.Stimulation or cement squeeze summary: Intervals treated(measured): . 1'7720;-20899'MD ' • 5CAP4N• DEC 1 8 2017 Treatment descriptions including volumes used and final pressure . . • 12823 bbls Marcit.gel liurnped - 13. . , •' - , Representative Daily Average Production or Injection Data - . • -oil-Bbl-•.. • . Gas-kA,ef' • - Water-Bbl Casing Pressure Tubing Pressure Prior to well operations • •b . • • 0, 5058 2350 1277 Subsequent to operatiorf: - . • -0 • : ' ' 0 - ' , • 1950 . 2322 251 14.Attachments(required per 20 AAC 25.070,25.071,4 25.283) 15.Well Class after work: Daily Report of Well Operations '„.1:1.. . •Exploratory ❑ Development ❑ Service E Stratigraphic ❑ Copies of Logs and Surveys Run Q 16.Welr$tatus after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ . • GSTOR ❑ WINJ ❑ WAG ❑., GINJ ❑ SUSP❑ SPLUG ❑ 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: 317-318 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke©cop.com Authorized Title: Staff Wells Engineer .....�.---- in '3-1 Contact Phone: (907)265-6097 Authorized Signature: .-e,-, -.-- Date: ! G Form 10-404 Revised 4/2017 7-ji RBD IS ij, OL T r, 26'17 Submit Original Only KUP Ail • 1C-20 ConocoPhillips °' Well Attrib Max Angle&MD TD AI(ISkA,Diu. Wellbore API/UWI Field Name Wellbore Status ncl Cl MD(ftKB) Act Btrn(ftKB) Conoccphinips 500292327300 KUPARUK RIVER UNIT INJ 95.06 18,034.95 21,081.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1C-20,10/18/20175:23:29 PM SSSV:NIPPLE Last WO: 46.91 1/28/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 17,660.0 5/27/2007 Rev Reason'GLV C/O hipshkf 5/7/2015 Casing Strings HANGER:W.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 19 29.062 26.7 80.0 80.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 40.3 11,113.6 4,570.3 45.50 L-80 Buttress INTEg MEDT PTE (in)7 5/5 ID(in)3.958 To 1 3.1 Set Depth 7 4 Set Depth(TVD)... WEL 12(60 Grade Top Thread ID To Casing P(ftKB) P (ftKB) P ( 1 L-80 BTC-M Casio Descri tion ODIn DescriptionpDepthDepth ... en ... (in) 6.875 39.4 Set 17,713.5 Set6,586.2 29.70 Grade 'Top Thread ,r, I,LINER 4 1/2L-80 Liner Details Nominal ID M�Opt/DUCTS/R.;287-60.0>b.anr/ .., Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 17,513.1 6,539.7 74.93 PACKER HRD ZXP LINER TOP PACKER 4.960 NIPPLE;515.5 13 17,532.1 6,544.7 74.92 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.870 17,535.0 6,545.4 74.91 HANGER FLEX-LOCK LINER HANGER 4.840 17,544.7 6,548.0 74.91 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17,838.7 6,599.6 87.83 Swell Packer SWELL PACKER w/TORQUE RING 3.958 18,053.0 6,589.3 94.90 Swell Packer SWELL PACKER w/TORQUE RING 3.958 GAS LIFT;4,600.8 F�C 18,390.0 6,584.7 89.22 Swell Packer SWELL PACKER w/TORQUE RING 3.958 -S 18,726.0 Swell Packer SWELL PACKER w/TORQUE RING 3.958 19,757,6 Swell Packer SWELL PACKER w/TORQUE RING 1958 20,002.3 Swell Packer SWELL PACKER w/TORQUE RING 3.958 20,491.6 Swell Packer SWELL PACKER w/TORQUE RING 3.958 SURFACE',40.3-11,113.6 ..• e Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/2 3.958 36.3 17,575.0 6,555.9 12.60 L-80 IBT MOD Completion Details SLEEVE-C,16,710.2 1J Ifi Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 36.3 36.3 0.00 HANGER FMC TUBING HANGER 3.900 515.4 514.5 8.51 NIPPLE CAMCO'DB'NIPPLE w/NO GO PROFILE 3.875 16,710.2 6,317.1 71.20 SLEEVE-C BAKER CMU SLIDING SLEEVE w/3.813 BX PROFILE- 3.813 I CLOSED 17,535.4 6,545.5 74.91 LOCATOR BAKER LOCATOR 3.880 17,560.2 6,552.0 74.89 SEAL ASSY BAKER BONDED SEAL ASSEMBLY 3.880 LOCATOR:17.535.4 Perforations&Slots Shot Top(ND) Btm(ND) ss (hots/ ens ft) Type Corn Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 17,720.0 17,801.0 6,567.3 6,597.6 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring SEAL ASSY;17,560.2 18,110.0 18,352.0 6,584.7 6,583.9 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring 1 18,783.0 19,719.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring 20,060.0 20,426.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank INTERMEDIATE;39.4-17713.5 pipe w/torque ring 20,577.0 20,697.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank SLOTS;17,720.0-17,801.0 1 1 Ipipe w/torque ring lir 20,814.0 20,899.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring Sri I Mandrel Inserts St SLOTS;18,110.0-18,352.0 1 ati I t on Top(ND) Valve Latch Port Size TRO Run WITop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 4,600.8 2,533.7 CAMCO 1R RBG-2- 1 GAS LIFT DMY BK 0.000 0.0 5/5/20)5 Iiiii- Notes:General&Safety End Date Annotation SLOTS,10703.0-19119,0 I I 1/7/2009 NOTE:View Schematic w/Alaska Schematic9.0 -I h Jul SLOTS',20.060.0-20,426.0 I 1 I r SLOTS;20.5770.20E4I 1 [ SLOTS;20,814.0-20,899.0 LINER:17.513.1-20,927.4 i • • 1C-20 Start Date End Date Job Typ Last 24hr Sum 9/25/17 9/28/17 MISC RES SURV During the execution of 1C-20 Marcit treatment we pumped a total of 12,823 Bbls of Gel in the following stages:2,500 Bbls of 3,000 ppm with a stage net pressure increase of 200 psi;followed by 8,529 Bbls of 5,000 ppm gel with a stage net pressure increase of 125 psi; followed by 1309 Bbls of 7,000 ppm with a stage net pressure increase of 110 psi;and finally 466 Bbls of 10,000 ppm with a stage net pressure increase of 65 psi. Total net pressure increase was 500 psi as planned from injectivity test. All offset production well samples were negative for polymer breakthrough. 9/24/17 9/24/17 MISC RES SURV Completed a step rate test on 1C-20 on Sunday 9/24. Rates and pressures are as follows: 2000 BWPD pressure stabilized around 2045 psi. 3000 BWPD pressure stabilized around 2110 psi 4000 BWPD pressure stabilized around 2175 psi 5000 BWPD pressure stabilized around 2230 psi after long shutdown. OF T1 • • w\A77;, � THE STATE Alaska Oil and Gas ALAsKA Conservation Commission tq 333 West Seventh Avenue ..,. iiirMartur GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r'> Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer SCANNED , U 3 12U 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-20 Permit to Drill Number: 205-123 Sundry Number: 317-318 Dear Mr. Burke: 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 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, Hollis S. French Chair DATED this T day of July, 2017. RBDMS C L JUL 2 7 2017 • • • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 12017 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations El Fracture Stimulate El 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 0 Other: MARCIT GEL TRTMTEl 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development ❑ 205-123 3.Address: Stratigraphic ❑ Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23273-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' KRU 1C-20 • Will planned perforations require a spacing exception? Yes ❑ No CI 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649,ADL 28242,ADL 28243,ADL 28244 - Kuparuk River Field/Kuparuk River Oil.Pool 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): 21,081' - 6,659' • 20927 6643,• 2740 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 53' 19" 80' 80' Surface 11,073' 10.75 11,114' 4,570' Intermediate 17,674' 7.625 17,714' 6,586' Liner 3,414' 4.5 20,927' 6,643' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 17720-20899. 6587-6640 4.500" L-80 17,560' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=HRD ZXP LINER TOP PACKER • 17513 MD and 6540 TVD SSSV" = NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic E '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service I] ' 14.Estimated Date for 8/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG CI ' GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned El 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com ` Contact Phone: (907)265-6097 Authorized Signature: / Date: / COM ISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \-7- 3 \% Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Ll Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No I/ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: `d O 7 RBDMS .. 'JUL L 7 2017 APPROVED BY I �y it Approved by: ta3CCL. y COMMISSIONER THE COMMISSION Date: oar /NI 7/14/17- Ti"1ORjpJatcil!'valid - SubmitForm and Form 10-403 Revised 4/2017 for 12 months from the date of approval. Attachments in Duplicate ' 7/ 7;1? • • Proposed 1C-20 MARCIT Gel Treatment 1C-20 is a single lateral injector in the C sand. This well breached 8 faults while drilling and has had very high injectivity (> 4.5 bwpd/psi) from the beginning. The 2014 injection profile reached 18,550' and indicated that majority of the injected produced water went below 18,550'. 1C-20 appears to be strongly interacting with 1 C-28(which had also intercepted multiple faults)as fluids from 1 C-20 appears to be reaching 1 C-28 in 1 to 2 weeks(possibly through a void space conduit). 1C-20 is also strongly interacting with 1C-12. The well has a slotted liner completion and does not have any known mechanical issues. Objective of the proposed conformance treatment for 1C-20 is to partially fill the void space conduit with a full bore Marcit gel treatment. / Procedure 1. Perform MIT-T and MIT-IA on tubing and inner annulus to confirm integrity. 2. Conduct a step rate injection test to set a baseline before job execution to compare against the job rates and pressure. a. Start at an injection rate of—S 2000 BPD or— 1.39 BPM and establish stable conditions for 4hrs. b. Step injection rate up to - 3000 BPD or—2.08 BPM and establish stable conditions for 4hrs. c. Step injection rate up to —4000 BPD or—2.78 BPM and establish stable conditions for 4hrs. d. Step injection rate up to — 5000 BPD or—3.47 BPM and establish stable conditions for 4hrs. 3. Pressure up inner annulus to 500 psi. 4. Start injecting produced water until gel is mixed. 5. Once a stable rate and pressure has been reached and the gel is ready for pumping, start gel pumping as shown below at the desired concentrations and rates in stages. Final two stages (7,000 ppm and 10,000 ppm polymer concentrations) of polymer injection will need to be with seawater. Keep polymer concentrations as stable as possible and provide pump rate and pressure data. Monitor changes in pressure as this may be an indication regarding the nature of the void space conduit. Target Concentration Design Volume Treatment Rate Total Treatment Rate Target Polymer PU24 Polymer Concentration (ppm) (bbl) (bpd) (bpm) (#/day) (ppm) Days 3000 12000 4500 3.13 4720 5400 2.7 5000 7500 4500 3.13 7867 9000 1.7 7000 5000 2500 1.74 6119 7000 2.0 10000 2500 2500 1.74 8741 10000 1.0 Total 25000 7.3 6. Evaluate pressure changes over time to target final pump rate and pressure 7. After pumping the gel, displace the final stage of Marcit gel with 230 bbls of produced water and then 38 bbls of diesel for surface freeze protection. 8. Once gel has been displaced, monitor the pressure for— 1 hour. • • • 9. Leave the well shut in and wait for gel to cure—4 days to allow the polymer to cross link. 10. Bring the well online (start from 25%of target rate) and gradually increase the rate. KUP II 1C-20 ConocoPhillips :; a Well Attribut Max Angle . D TD AlSska,lno.. Wellbore API/UWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(ftKB) x cocopttilhlx- 500292327300 KUPARUK RIVER UNIT !NJ 95.06 18,034.95 21,081.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-20,7/6/2017 11 53 11 AM SSSV:NIPPLE Last WO: 46.91 1/28/2006 Vertical schematic(actual). 4 Annotation Depth(ftKB) End Date Annotation Last Mad By End Date Last Tag:SLM 17,660.0 5/27/2007 Rev Reason:GLV C/O hipshkf 5/7/2015 Casing Strings HANGER;36.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread `"- CONDUCTOR 19 29.062 26.7 80.0 80.0 62.50 H-40 WELDED II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...-Grade Top Thread SURFACE 103/4 9.950 40.3 11,113.6 4,570.3_ 45.50 L-80 Buttress Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 39.4 17,713.5 6,586.2 29.70 L-80 BTC-M Casing Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 17,513.1 20,927.4 12.60 L-80 Liner Details Nominal ID -,....e.....LO[{DDLCTOR:25,7$0.. - Top(ftKB) Top(ND)(ftKB) Top Inci C) Item Des Com • (in) 17,513.1 6,539.7 74.93 PACKER HRD ZXP LINER TOP PACKER 4.960 NIPPLE;515.5 C' 17,532.1 6,544.7 74.92 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.870 17,535.0 6,545.4 74.91 HANGER FLEX-LOCK LINER HANGER 4.840 17,544.7 6,548.0 74.91 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17,838.7 6,599.6 87.83 Swell Packer SWELL PACKER w/TORQUE RING 3.958 18,053.0 6,589.3 94.90 Swell Packer SWELL PACKER w/TORQUE RING 3.958 . II GAS LFT;4,600. a,_ 18,390.0 6,584.7 89.22 Swell Packer SWELL PACKER w/TORQUE RING 3.958 on 18,726.0 Swell Packer SWELL PACKER w/TORQUE RING 3.958 19,757.6 Swell Packer SWELL PACKER w/TORQUE RING 3.958 I 1. 20,002.3 Swell Packer SWELL PACKER w/TORQUE RING 1 3.958 20,491.6 Swell Packer SWELL PACKER w/TORQUE RING 3.958 suRFACE;4o.3-11,113. Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/2 3.958 36.3 17,575.0 6,555.9 12.60 L-80 IBT MOD Completion Details SLEEVE-C;18,710.2 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 36.3 36.3 0.00 HANGER FMC TUBING HANGER 3.900 515.4 514.5 8.51 NIPPLE CAMCO'DB'NIPPLE w/NO GO PROFILE 3.875 16,7102 6,317.1 71.20 SLEEVE-C BAKER CMU SLIDING SLEEVE w/3.813 BX PROFILE- ' 3.813 CLOSED 17,535.4 6,545.5 74.91 LOCATOR BAKER LOCATOR 3.880 17.560.2 6,552.0 74.89 SEAL ASSY BAKER BONDED SEAL ASSEMBLY 3.880 LOCATOR;17,535.4 . Perforations&Slots Shot } Top(ND) Btm(ND) (sDhotn( AEI Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 17,720.0 17,801.0 6,587.3 6,597.6 C-4.1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank '::�.;f pipe w/torque ring SEAL ASSY,17,560.2 ea..: 18,110.0 18,352.0' 6,584.7 6,583.9 C-4.1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring 18,783.0 19,719.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring 20,060.0' 20,426.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank INTERMEDIATE,394-17,713.5 ' pipe w/torque ring 20,577.0 20,697.0- C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank SLOTS;17,720.0-17,801.0 pipe w/torque ring lit 20,814.0 20,899.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring lir _ Mandrel Inserts St SLOTS;18,110.0-18,352.0 ab on Top(ND) Valve Latch Port Size TRO Run Tit N Top(ftKB) (ftKB) Make Model 00(in) Sery Type Type (in) (psi) Run Date Com 1L 4,600.8 2,533.7 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 5/5/2015 1R lir Notes:General&Safety End Date Annotation sLors,1e,7/30.19,7190 i 1/7/2009 NOTE.View Schematic w/Alaska Schematic9.0 J r Sr SLOTS:20,060.0-20,426.0 SLOTS;20,577.0-20,697.0 SLOTS;20,814.040,898.0 -. LINER;17,513.1-20,927.4 A STATE OF ALASKA 1.. 3KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon Repair w ell Injection Test r P r Rug Perforations r Perforate r" Other d Alter Casing r Pull Tubing r Stimulate- Frac r` Waiver r Time Extension r Ma r��tCzc I Change Approved Program r-Operat. Shutdown r" Stimulate-Other r" Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205-123 3.Address: 6.API Number: Stratigraphic r Service Ft P. O. Box 100360,Anchorage,Alaska 99510 50-029-23273-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 28242,25649,28243,28244 KRU 1C-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 21081 feet Plugs(measured) none true vertical 6659 feet Junk(measured) none Effective Depth measured 20927 feet Packer(measured) 17513 true vertical 6643 feet (true vertical) 6540 Casing Length Size MD TVD Burst Collapse CONDUCTOR 53 19 80 80 SURFACE 11073 10.75 11114 4570 INTERMEDIATE 17674 7.625 17714 6586 LINER 3414 4.5 20927 6643 RECEIVED APR 1 6 2015/ Perforation depth: Measured depth: slotted liner from 17720-20899 True Vertical Depth: 6587-6640 SCONE 0 MA 1 2 2.015 AOGCC Tubing(size,grade,MD,and TVD) 4.5, L-80, 17575 MD,6552 TVD Packers&SSSV(type,MD,and TVD) PACKER-HRD ZXP LINER TOP PACKER @ 17513 MD and 6540 ND NIPPLE-CAMCO'DS' NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 17720'-20899' Treatment descriptions including volumes used and final pressure: 10,524 bbls of gelled polymer placed in perforated interval 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3990 2080 Subsequent to operation 2442 1980 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r" Development fl Service ' 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 John Braden (a,263-4635 Email John.C.Bradenaconocophillips.com Printed Name John aden Title Staff Engineer Signature C7 Phone 263-4536 Date /5 /prj i 1 '— 5/ii//5— RBDMS 'k APR 1 8 2015 ,lit Form 10-404 Revised 10/2012 Submit Original Only f KUP INJ 1C-20 ConocoPhillips 2 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status lInci(3 MD(ftKB) Act Btm(ftKB) [LneCcifthm x 50029232/300 KUPARUK RIVER UNIT INJ 95.06 18,034.95 21,081.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1C-20,9/1620137:26:19 AM SSSV:NIPPLE Last WO: 46.91 1/28/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 17,660.0 5/27/2007 Rev Reason:WELL REVIEW osborl 9/16/2013 Casing Strings Casing Description OD(i n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread HANGER:36.3--{=_-__:--41. CONDUCTOR 19 29.062 26.7 80.0 80.0 62.50 H-40 WELDED Casing Description OD(in) ID(ie) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 40.3 11,113.6 4,570.3 45.50 L-80 Buttress Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' �„ INTERMEDIATE 75/8 6.875 39.4 17,713.5 6,586.3 29.70 L-80 BTC-M ti -,, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 4 12 3.958 17,513.0 20,927.4 12.60 L-80 Liner Details I To ftKB Top(TVD)(ftKB) Top tncl P) Item Des Com (in) Nominal ID ,/�A CONDUCTOR;26.7-80.0 - I r P( I 17,513.0 6,539.7 74.93 PACKER HRD ZXP LINER TOP PACKER 4.960 NIPPLE;515.5 I.E. 17,532.1 6,544.7 74.92 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.870 I 17,534.9 17,544.7 6,545.4 74.91 HANGER FLEX-LOCK LINER HANGER 4.840 6,548.0 74.91 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17,838.6 6,599.6 87.83 Swell Packer SWELL PACKER w/TORQUE RING 3.958 18,052.9 6,5893 94.90 Swell Packer SWELL PACKER w/TORQUE RING 3.958 GAS LIFT;4.600.8 18,389.9 6,584.7 89.22 Swell Packer SWELL PACKER w/TORQUE RING 3.958 18,725.9 Swell Packer SWELL PACKER w/TORQUE RING 3.958 19,757.5 Swell Packer SWELL PACKER w/TORQUE RING 3.958 • • 20,0022 Swell Packer SWELL PACKER w/TORQUE RING 3.958 • 20,491.5 1 Swell Packer SWELL PACKER w/TORQUE RING 3.958 SURFACE;40.3.11,113.6 a c Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 36.3 17,575.0 6,555.9 12.60 L-80 IBT MOD Completion Details SLEEVE-C;16.710.2 -_1I. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl('I Item Des Cont (in) 36.3 36.3 0.00 HANGER FMC TUBING HANGER 3.900 515.4 514.5 8.51 NIPPLE CAMCO DB'NIPPLE wM0 GO PROFILE 3.875 16,710.2 6,317.1- 71.20 SLEEVE-C BAKER CMU SLIDING SLEEVE 9//3.813 BX PROFILE- 3.813 CLOSED 17,535.4 6,545.5 74.91 LOCATOR BAKER LOCATOR 3.880 17,560.2 6,552.0- 74.89 SEAL ASSY BAKER BONDED SEAL ASSEMBLY 3.880 i LOCATOR;t7,535.4 Perforations&S1013537:531 lots 1 Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) i (ftKB) (ftKB) Zone Date t) Type Com 1/,/70.0 17,801.0 6,587.3 6,597.6 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring SEAL ASSY;1],560.2 18.1100 18.352.0 6,584.7 6,583.9 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe Morgue ring 18,/83.0 19719.0- C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe w/torque ring • INTERMEDIATE:39.5.17,713.5- a - 20,060.0 20,426.0 C-4,1C-20 1/23/2006 40.0 SLOTS Alternating slotted/blank pipe Morgue ring SLOTS;17.720.0.17,901.0 20,577.0 20,697.0 C-4,1C-20 1/232006 40.0 SLOTS Alternating slotted/blank pipe Morgue ring iffiF 20,814.0 20,899.0 C-4,1C-20 123/2006 ' 40.0 SLOTS Alternating slotted/blank pipe w/torque ring Mandrel Details St ati C SLOTS;18,110.0-18,352.0 on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Or 1 4,600.8 2,533.7 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 10/25/2006 SI 1R I Notes:General&Safety End Date Annotation 1:72009 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;15783.0-19,719.0 I iiir iii SLOTS;20,060.0.20,426.0 SLOTS;20577.0-20.697.0 SLOTS;20,814,0-20.899.0 LINER;17,513.0.20,927.4 KRU 1C-20 Conformance Polymer Treatment PTD: 205-123 API: 50-029-23273-00 The KRU 1C-20 conformance polymer treatment terminated prior to completion because of equipment problems. Below is a daily summary of the treatment. 10/23/2014 to Rig up for conformance polymer treatment. 11/3/2014 11/4/2014 Begin filling upright tanks to clean produced water by diesel-washing and settling. 11/5/2014 Initiate step-rate test with water to refine treating schedule. 11/6/2014 Generator went down. Troubleshooting problem. 11/7/2014 to Shut down for Phase II weather conditions and 11/8/2014 subsequent snow removal. 11/9/2014 to Troubleshooting generator problem. Rig down 11/11/2014 equipment to allow rig 7ES movement on the pad. 11/12/2014 to Equipment de-mobed. Waiting on 7ES rig to move 11/14/2014 onto the pad. 11/15/2014 to Re-mobing onto pad after 7ES rig move. 11/18/2014 11/19/2014 to Troubleshooting equipment problems 11/20/2014 to Shut down for Phase III weather and subsequent 11/24/2014 snow removal and equipment thaw. 11/25/2014 to Inject water into 1C-20 to test equipment function. 11/26/2014 11/27/2014 Started conformance polymer treatment. New injection schedule, based on the step-rate test (11/5/2014) is as follows: • 4000 bbl of clean PW with 3000 ppm gel • 3000 bbl of clean PW with 5000 ppm gel • 2000 bbl of clean PW with 7000 ppm gel • 1000 bbl of clean PW with 10000 ppm gel 11/28/2014 A total of 4211 bbls of clean PW with 3000 ppm gel pumped down 1C-20. 11/29/2014 Pumping gel. Switched from 3000 ppm to 5000 ppm at 07:41. Cumulative pumped to date is: • 5009 bbl clean PW with 3000 ppm gel • 1690 bbl clean PW with 5000 ppm gel 11/30/2014 Pumping gel. Cumulative pumped to date is: • 5009 bbl clean PW with 3000 ppm gel • 3621 bbl clean PW with 5000 ppm gel 12/1/2014 Pumping gel until equipment failure. Cumulative pumped to date is: • 5009 bbl clean PW with 3000 ppm gel • 4979 bbl clean PW with 5000 ppm gel 12/2/2014 to Trouble-shooting equipment problems. Injection 12/3/2014 equipment and 1C-20 freeze protected. 12/4/2014 Equipment issue resolved. Pumping clean PW to test the injection equipment. 12/5/2014 Resume conformance polymer treatment from the beginning of the gel injection schedule. 12/6/2014 Pumping gel. Cumulative pumped to date is: as follows: Second attempt: • 1894 bbl clean PW with 3000 ppm gel First attempt: • 5009 bbl clean PW with 3000 ppm gel • 3621 bbl clean PW with 5000 ppm gel 12/7/2014 to Rig down and move out KRU 1C-20 conformance 12/12/2014 polymer injection equipment. . TiORCO • A NALCO 8,STEPAN COMPANY 2452 South Trenton Way•Suite M•Denver,CO 80231•(303)923-6440(Office) Company Name: ConocoPhillips Alaska Field Name: Kuparuk Well Name: 1C-20 MARCIT Polymer Gel Treatment Well Type: Injection Location:North Slope,Alaska Treatment Summary and Charts Portable Unit#: 24 Report Date: 12/07/14 Date Time Date Time Polymer Gel WHP(psi) BHP(psi) Pump Rate(bpd) Comments Stage Begin Begin End End ppm bbls Begin End Begin End Begin End 1 12/06/14 9:17 AM 12/6/14 9:39 AM' 0 39 1,528 1,689 2,500 2,500 Stage Nt Water Flush 2 12/6/14 9:39 AM 12/6/14 3,000 1,689 2,500 2,500 Stage 82:3,000 ppm Totals 39 Injection Rate,Pressure,and Concentration 3,000 - 12,000 11,000 2,500 -------- --- 10,000 9.000 2,000 r'.... L 8,000 c 7,000 0 i cis t' 0 1,500 6,000 ( o- c oo U °•' - 5,000 E ivcc2 'E' 1,000 __ — 4,000 — 3,000 500 2,000 'I1 — 1,000 I 0— — 0 00 00 00 0•0 00 00 00 00 0 00 00 ti0 0.0 60 00 00 ti0 A0 600 00 00 Cumulative BBLS.Injected , ,Inj.Rate(BPD) . .WHP(psi) viiiiiiv.Polymer Conc.Actual(ppm) —Polymer Conc.SP(ppm) .. ,. Hall Slope and PSI/SWI .. 2,500,000 3.00 250 2.000,000 __. - - .use" _._.._ _... a - 200 a 0 1.500.000 __... ... _.... a m 1.ii : O -Ti i a 1,000.000 E 5 c.� 500,000 ppiiir 0.50 0 0.00 O `19 ACC' 600660 O60 ry60 b00 6Q0 660 OcP Cumulative BBLS.Injected Hall Plot . .PSI/BWI 5.0 Injectivity 4.5- ____. ..... __. - __.. _...... . -..... . ,_. ........ _. _.__ 4.0. .. . 1 _ .... --__. _. _ _... :=;.., 9 - . A n--- .....::d-.r, e'4,s ,.. - _ _ _ ..., »,. w•a...,.,:a # a ,�. TI0Rc0 . A NALCO&STEPAN COMPANY 2452 South Trenton Way•Suite M•Denver,CO 80231•(303)923-6440(Office) Company Name: ConocoPhillips Alaska Field Name: Kuparuk Well Name: 1C-20 MARCIT Polymer Gel Treatment Well Type: Injection Location: North Slope,Alaska Treatment Summary and Charts Portable Unit#: 24 Report Date: 12/01/14 Date Time Date Time Polymer Gel WHP(psi) BHP(psi) Pump Rate(bpd) Comments Stage Begin Begin End End ppm bb's Begin End Begin End Begin End 1 11/27/14 4:29 AM 11/27/14 5:10 AM 0 152 1.272 1.384 1,112_ 2,018 Stage#1 Water Flush 2 11/27/14 5:10 AM 11/29/14 7:40 AM. 3,000 4,984 1,384 1.681 2.018 2.500 Stage#2.3,000 ppm 3 11/29/14 7:40 AM 5,000 1.681 I 2,500 Stage#3.5,000 ppm Totals 5,136 Injection Rate,Pressure,and Concentration 8,000 12,000 — 11,000 7,000 - _. — 10,000 6,000 --— 9,000 y n — 8,000 e 5 5,000 a B — 7,000 oo a 18 at t a 4,000 - _... _... ____ _... — 6,000 8 Q_ ) m o U °-' — 5,000 `m mNMI a E 3,000 - i 0>, 4,000 a •rh k 1111 2,000 —3,000 4r , —2,000 1,000 1 — 1,000 i 0 — - 0 O O O O O O O O O O o O. 00' 000• 000• 000• 000' 000 000• 000• 000' 000' ^ qy, O, a, y. c3 1, 0, 0, ^0. Cumulative BBLS.Injected ilnj.Rate(BPD) ........WHP(psi) —Polymer Conc.Actual(ppm) —Polymer Conc.SP(ppm) Hall Slope and PSI/BWI T 3. :::: . .. .-.. .._... 7,000,000 __ °,°1' n. .. _....... — _o c 6,000,000-.._ .:,. . a " aG :.., 5,000,000 0 w - :! 1 0 _ a 4,000,000 __. _... ___ E 0 U 3,000,000 ____ -- -. _. . - _ L _... _ 1.00 2,000,000 ..4111 —0.50 1,000,000 n _. _... 0 0.00 O ^000 000 000 OOO 000 000 000 000 000 000 rl,. .�, p g 0. 1, 0, 0' �0. Cumulative BBLS.Injected Hall Plot MPSI/BWI 5.0 11 Injectivity 4.s 4.0 __.... _.... ._._. -__.. 35 Y! SI. 3 p _... _.. • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - 1 c~,3 Well History File Identifier Organizing (done) \ ~ Two-sided II I II'I II It ~l (ll ll~ ^ Rescan Needed If (fl ~{ (I 1~ i l (I l 111 RESCAN DIGITAL DATA OVERSIZED (Scannable) ~( Color Items: ^ Diskettes, No. ^ Maps: VVV ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: !s/ Project Proofing III (I'lll IIIII II III BY: Maria Date: D V /s! Scanning Preparation _~ x 30 = ~U ~ + ~ =TOTAL PAGES ` ' (Count does not include cover sheet) f /~~ BY: Maria Date: , ~ ~ a~ ~ /s/ / I L Production Scanning Stage 1 Page Count from Scanned File: ~ ~ (Count does include cover sheet) Page Count Matches Number in Scanni/n~g Preparation: YES NO BY: Maria Date: ~' /~ / ~ V /s/ tl~,"`~~~"""yYY ~ 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /sl Scanning is complete at this point unless rescanning is required. III (I'III III II I I III ReScanned II I II II II I I III I ~ III BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc MEM RANDUM ~ State of Alaska O Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 To: Jim Regg ~p~~ ~,~~~I10 P.I. Supervisor (~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-20 FROM: John Crisp xuPAxux Rrv UNIT ]c-zo Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT IC-20 API Well Number: 50-029-23273-00-00 Insp Num: mitJCr100524061238 Permit Number: 205-123-0 Rel Insp Num: Inspector Name: John Crisp Inspection Date: 5/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ]c-zo --- T pe In'.~T W'' TVD 6540 ~ Y J I ~ IA~so ~ z7ao / z6so z67o P.T.D~ 2051230 _ TYpe7'eSt SPT 'l'est pSl ~ 1635 i QA 400 643 629 626 Interval 4YRTST P~F P ~ TUbing i 2130 2142 2146 2146 - Notes: 3.7 bbls pumped for test. No problems witnessed. ~p T ! `~ ~~,~=: r.. Tuesday, May 25, 2010 Page 1 of 1 ~* ~.»``' `~ ~' ,*,. ~' ~. ";;;». ~Li k t ~~+` F r~ ~ t ~ ~+ ~. ~~L. R....:. ~'.... Y....'v R'f~ AA MICROFILMED 6!30/201 ~ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~e DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051230 Well Name/No. KUPARUK RIV UNIT 1C-20 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23273-00-00 MD 21080 TVD 6659 Gompletion Date 1/28/2006 Completion Status 1-OIL Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Logs Run: GR /RES, DENS / NEU, SCMT WeII Log Information: Log! Electr Data Digital Dataset Typ Med/Frmt Number ame D C Lis 15318 Gamma Ray Reservoir Saturation ' t E ti C l ~9 emen on va ua ~I`ED C Lis 13885~hnduction/Resistivity C Lis 13885~Induction/Resistivity Log C Li Pressure 15319 /G R s amma ay I~ 15318 •LIS Verification Rpt 15319 LIS Verification Weli Cores/Samples Information: Log Log Run Scale Media No 5 Blu 1 5 Blu 1 5 Blu 1 (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 3446 21081 Open 8/3/2007 LIS Veri, GR, ROP, FET, NPHI, NCNT, RHOB w/Graphics EMF and PDF = POR and EWR 17225 17738 Open 2/20/2007 RST, WFL w/Temp 12-Feb- 2007 0 17713 Case 1!24/2006 Memory Cement Bond Log GR/CCL/SCMT 3446 21009 5/10/2006 GR, ROP, NPHI, NCNT, RHOB 3446 18611 5/10/2006 PB 1 GR, ROP, NPHI, NCNT, RHOB 17298 17698 Open 7/25/2006 FBHP Surrey, Pres, Temp 14-Jul-2006 3446 18683 Open 8/3/2007 PB1 LIS Veri, GR, ROP, FET, NPHI, NCNT, RHOB w/Graphics EMF and PDF = POR and EWR 3446 21081 Open 8/3/2007 LIS Veri, GR, ROP, FET, NPHI, NCNT, RHOB w/Graphics EMF and PDF = POR and EWR 3446 18683 Open 8/3/2007 P61 LIS Veri, GR, ROP, FET, NPHI, NCNT, RHOB w/Graphics EMF and PDF = POR and EWR Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051230 Well Name/No. KUPARUK RIV UNIT 1C-20 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23273-00-00 MD 21080 TVD 6659 Completion Date 1/28/2006 Completion Status 1-OIL Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y /,rv , Chips Received? l`P`~'-NUJ Analysis l~-Hd" Received? Daily History Received? `'!"N Formation Tops ~/ N Comments: Compliance Reviewed By: _ _ _ _ __ _ __ _ _ __ _ Date: . ~ Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, March 07, 2008 3:52 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 10-404 converting a well to injector without packer MD Attachments. 1C-20.pd ~ `J-102.pdf; 1J-156.pdf; 1J-170.pdf; 1J-127.pdf; 1J-184.pdf .~°J~ a~ Jim, Here are the schematics of the motherbores for the list of wefts below. Let me know if you need any additional data or if the 10-404's need to be earrected and resubmitted. MJ Loveland ConocoPhillips Welf Integrity Project Supervisor 659-7043 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 1:58 PM To: NSK Problem Well Supv Cc: Fleckenstein, Robert J (DOA) Subject: FW: 10-404 converting a well to injector without packer MD Martin - West Sak wells have some unique approvals as you are no doubt aware. We discussed the exemption from packer requirements (20 AAC 25.200) - I am still looking into whether that is a welt by well approval or some blanket authorizationlpool rule. West Sak injectors are, I believe, also completed packerless but do have a seal bore assembly and a liner top packer for the tieback string isolating the injection formation from the tubing-casing annulus. Below is a list of wells from a search of our well files that do not show a packer depth on the well completion report (10-407) or report of sundry operations (10- 404). Pfease provide the MD and ND of the uppermost liner top packer/seal bore assembly. Also, please remind those submitting the 404's and 407's of the uniqueness for these West Sak completions Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Fleckenstein, Robert J (DOA) Sent: Monday, March 03, 2008 1:06 PM To: Regg, James B (DOA) Subject: 10-404 converting a well to injector without packer MD Jim, The following wells have 10-404 submitted converting them from producers to injectors and have "none" or "no packer" in the packer MD data block: 2061100 WSAK 1 J-102 2060670 WSAK 1 J-156 3/12/2008 2060620 WSAK 1J-170 • 2060470 WSAK 1J-127 2060440 WSAK 1J-184 2051230 KRU 1 C-20 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 *:('Iease Ttcit~ ~~e~~~ crn~il aclJress l~oh#lcckc:n5tc~n~u alasla_gc~~_ Page 2 of 2 3/12/2008 ~' KRU 1 C-20 ~~ ~ ~ Cor~ocaPhillips Alaska, tnc. 1 c-2o TUBING API: 500292327300 Well T e: PROD (0-17575, ~ ~ SSSV T e: NIPPLE Ori Com letion: 1/28/2006 OD:4.5o0, Annular Fluid: Last W/O: ID:3.958) ~ ~ Reference L : 40.3' RKB Ref L Date: Last Ta TD: 21081 ftK6 Last Tac,~Date: _ Max Hole Angle: -96 derma 18296 SEAL (17537-17561, OD:4.750) _i I ~:. - ~ ~ - i. I ..- i i I- ~ _. r~ _ , -~ ", ~~~ I i - __. ~ ~ _ ~_,. ~~- _.-aa I = I = I, ~' .~::. -; ~, ' -- __ I _. -- ,~:: ~i ~CiL I Casing_String _ ALL STRINGS Grade Thread 5LX-42 Seamles L-80 BTC L-80 BTCM LINER ~ - - - - 4.500 I 17513 ~ 2Q927 6F43 12.60 ~ L-80 BTC Tubiug String -TUBING Size Top ~ Bottom ~ TVD ~ Wt ~ Grade ~ Thread 4.500 0 - _._ 17575 6556 12.60 L-80 IBTM spl clr cplq Perforations Summer Interval ND Zone Status Ft SPF Date T e Comment 17720 -17801 6587 - 6597 C-4 81 40 1/23/2006 Slots Alternating slottedlblank pipe w/tor ue rin 18110 -18352 6601 - 6583 C-4 242 40 1/23/2006 Slots Alternating slotted/blank pipe w/tor ue rin 18783 -19719 6588 - 6584 C-4 936 40 1/23/2006 Slots Alternating slotted/blank pipe w/tor ue rin 20060 - 20426 6595 - 6608 C-4 366 40 1/23/2006 Slots Alternating slotted/blank pipe wttor ue rin 20577 - 20697 6613 - 6621 C-4 120 40 1/23/2006 Slots Alternating slotted/blank pipe w/tor ue rin 20814 - 20899 6633 - 6640 C-4 85 40 1/23/2006 Slots Altemating slotted/blank pipe w/tor ue rin___ __ _ _ Gas Lift MandrelsNalves - - StTMD TVD Man Man Type V Mfr V Type V OD Latc ~ h Po ._ rt TRO Date Run Viv Mfr ~ I I I I Cmnt 1 4601 2534 CAMCO KBG-2-1 R OV 1.0 BK 0.251 0 I _ 0__ 19/26/20_ Other (plugs, equip., et c.) -COMPLETION JEWELRY De th TVD T e Descri tion ID 36 36 HANGER 2.5" FMC TUBING HANGER 3.900 515 514 NIP CAMCO 'DB' NIPPLE w/3.875" NO GO PROFILE 3.875 16710 6317 SLEEVE-C BAKER CMU SLIDING SLEEVE 3.813" BX PROFILE -CLOSED 3.813 17535 6545 LOCATOR BAKER LOCATOR 3.970 17537 -_ OtherS 6546 SEAL plugsTe ui ., et BAKER BONDED SEAL ASSEMBLY w/17' OF SEALS w/BAKER SEAL 3.880 SPACER PIPE ABOVE SEAL _ _ c. -LINER JEWELRY _ De th TVD T e Descri tion ID 17513 6540 PACKER 'HRD' ZXP LINER TOP PACKER 4.960 17532 6545 NIP 'RS' PACKOFF SEAL NIPPLE 4.870 17535 6545 HANGER FLEXLOCK LINER HANGER 4.840 17545 6548 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17564 6553 XO 3.940 17839 6599 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 18053 6601 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 18390 6580 PACKER L-80 SWELL PACKER #6 wlfOROUE RING 3.958 18726 6586 PACKER L-80 SWELL PACKER #6 wITOROUE RING 3.958 19758 6584 PACKER L-80 SWELL PACKER #6 wlTOROUE RING 3.958 20002 6595 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 20492 6611 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 20926. Genera Date 6643. SHOE 4.5" RAY OIL TOOLS SILV_ERBULL_ET GUIDE SHOE _ _ __ 0.000 -_ __- - - l Notes __ Note __ _ 1/26/2006 TREE: W KM G5, 4.5" X 5M TREE CAP CONNECTION: OTIS 7" WELL LOG TRANSMITTAL To: State of Alaska June 26, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1 C-20 & PB 1 AK-MW-4046666 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1C-20: Digital Log Images 50-029-23273-00,70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 m ,. _ ,~ '~ _ '. ~ ; ~ ~ Date: °' ~ ° Signed: ,~a3 ~ ~ S3~~f u~~- # ~s"3~9 R~: KRU 1G20 (205-123) subject: RE: KRU 1 G20 (205-123) From: "Johnstone, Sam" <Sam.Johnstone@conocophillips.com> Date: Tuc, 06 Mar 2007 13:20:02 -0900 To: ThomasMaunder <tom_n~aunc~er~~admin.state.ak.us~ Tom, in fallow-up to the recent 1 C-20 conversion to injection, a Water Flow l,og (WFl-} was run in the 1 C-20 on February 12, 2007 to identify flaw behind pipe above the slatted liner. The results of the log confirm no flow above the slotted liner. I am sending you a copy of the WF1W far your records. Below, I have included comments from Robin Smyth with Schlumberger regarding the interpretation of the WFl_. Please let me knave if you have any questions nr concerns. --Sam Sam Johnstone Office (907) 263-4617 Home (907) 746-5809 ___--Original Message_____ From: Robin Smyth [mailto:rsmyth(c~anchora~e.oilfield.slb.comJ Sent: Monday, March 05, 2007 3:50 PM To: Tarac, Gar-y Cc: Douglas Hupp Subject: 1 G - 20 WFL Gary, After due examination of the ac#ual decay log \ls Time for file ~# 56 allegedly taken at 17586' i can see no evidence to suggest that there is actual flow behind the pipe. It appears as though somehow the auto detection has malfunctioned. There was a repeat station made # 57 and this does not record any flow in the summary sheet, but the decay log was not presented. A good example of a legitimate decay curve signalling flow can be seen at 17738 Ft f# 069, which is well inside the liner. l hope this helps, If l can be of any further assistance, please let me know. 3/6/2007 l :59 PM 02/16/07 chl~mh~rg~r Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth a ~ ~, ~ ~ s~ ~ a d ' t ~. ~~P a 4~1 ~- _ -. ~. ~~~ UrC ~~S -r Well Job # Log Description NO. 4142 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1D-111, 11638816 INJECTION PROFILE 01/24107 1 1N-19 ' 11663824 INJECTION PROFILE 01/25/07 1 2T-30 11663825 PRODUCTION PROFILE 01/26/07 1 2K-02 11663829 PRODUCTION PROFILE 01/30/07 1 3J-02 11632653 INJECTION PROFILE 01/30/07 1 3J-08 11632657 INJECTION PROFILE 02103/07 1 2M-05 11632658 SBHP SURVEY 02104107 1 1A-19 11632660 PRODUCTION PROFILE 02105107 1 3J-04 11628963 INJECTION PROFILE 02/08/07 1 1C-09 • 11638818 INJECTION PROFILE 02/09/07 1 2M-26 11638819 INJECTION PROFILE 02110/07 1 1 D-03 11628967 PRODUCTION PROFILE 02111107 1 1C-20 NIA RST/VUFL 02/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. /~/ MEMORANDUM TO: Jim Retry ~ 7 P.L Supervisor ~ '~~ ~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 02, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC I C-20 KUPARUKRIV UNIT 1C-20 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv' Comm Well Name: KUPARUK RIV UNIT 1C-20 Insp Num: mitJJ0612211 t4l>"6 Rel Insp Num API Well Number 50-029-23273-00-00 Permit Number: 205-123-0 Inspector Name: Jeff Jones Inspection Date: 12/21/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCII ~ 1C-20 iType n~ l~ W ~VD ~ 6540 ~ IA ~~ 933 1970 ~ ~ 1960 ~ 1960 ~ ~ I P.T ~ 201230 ~TypeTest I SPT~est pSl I j 163> ~ QA ~'I ~ 337 I 460 ~~ 4 0 485 _ _ Interval INITAL p~ P / _ ~/ TUbing' 830 830 I 83~_ 830 I Notes 1 BBL diesel pumped. 1 well house inspected; no exceptions noted. v ,. Tuesday, January 02, 2007 Page I of t °~~~-~°- KRU 1 C-20 ~:~ ConocoPhillips Alaska, Inc. TUBING (Q17575, OD:4.500, ID:3.958) SEAL (17537-17561, OD:4.750) I ~ ~ ~ ~ I 1 1 I I ~ ' ~ 1 C-20 API: 500292327300 Well T e: PROD An le TS: 79 d 17680 SSSV T : NIPPLE Ori Com letion: 1/28/2006 An le TD: 83 d 21081 Annular Fluid: Last W/O: Rev Reason: GLV C/O Reference L : 40.3' RKB Ref L Date: Last U date: 9/27/2006 Last Ta : TD: 21081 ftK6 Last T Date: Max Hole An le: 96 d 18296 Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 164.90 5LX-42 Seamless ' SURFACE ' 10.750 0 ~ 11113 4570 45.50 L-80 BTC INTERMEDIATE 7.625 0 17713 6586 29.70 L-80 BTCM ' LINER 4.500 17513 20927 6643 12.60 L-80 BTC Tubin Strin -TUBING ' Size To Bottom TVD Wt G rade Thread 4.500 0 17575 6556 12.60 L-80 IBTM s l clr c l Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 17720 - 17801 6587 - 6597 C-4 81 40 1/23/2006 Slots Alternating slotted/blank pipe w/tor ue rin 18110 - 18352 6601 - 6583 C-4 242 40 1/23/2006 Slots Alternating slotted/blank pipe ~ w/tor ue rin 18783 - 19719 6588 - 6584 C-4 936 40 1!2312006 Slots Alternating slotted/blank pipe w/tor ue rin 20060 - 20426 ~ 6595 - 6608 C-4 366 40 1/23/2006 Slots Alternating slotted/blank pipe i, w/tor ue rin ' 20577 - 20697 6613 - 6621 ~ C-4 120 40 1/23/2006 Slots Alternating slottedlblank pipe w/tor ue rin 20814 - 20899 6633 - 6640 ~ C-4 85 40 1/23/2006 Slots Alternating sbtted/blank pipe w/tor ue rin Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD latch Port TRO Date Run Vlv Cmnt 1 4601 2534 CAMCO KBG-2-1R OV 1.0 BK 0.250 0 9/26/2006 Other lu s, ui ., etc. -COMPLETION JEWELRY De th ND T e Descri tion ID 36 36 HANGER 2.5" FMC TUBING HANGER 3.900 515 514 NIP CAMCO 'DB' NIPPLE w/3.875" NO GO PROFILE 3.875 16710 6317 SLEEVE-C BAKER CMU SLIDING SLEEVE 3.813" BX PROFILE -CLOSED 3.813 17535 6545 LOCATOR BAKER LOCATOR 3.970 17537 6546 SEAL BAKER BONDED SEAL ASSEMBLY w/17' OF SEALS w/BAKER SEAL SPACER PIPE ABOVE SEAL 3.880 Other lu s, a ui ., etc. -LINER JEWELRY De th ND T e Descri tion ID 17513 6540 PACKER 'HRD' ZXP LINER TOP PACKER 4.960 17532 6545 NIP 'RS' PACKOFF SEAL NIPPLE 4.870 17535 6545 HANGER FLEXLOCK LINER HANGER 4.840 17545 6548 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17564 6553 XO 3.940 17839 6599 PACKER L-80 SW ELL PACKER ?I6 w/TORQUE RING 3.958 18053 6601 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 18390 6580 PACKER L-80 SWELL PACKER #16 w/TORQUE RING 3.958 18726 6586 PACKER L-80 SWELL PACKER #6 wlTOROUE RING 3.958 19758 6584 PACKER L-80 SWELL PACKER t!6 w/TORQUE RING 3.958 20002 6595 PACKER L-80 SW ELL PACKER ff6 w/TORQUE RING 3.958 20492 6611 PACKER L-80 SWELL PACKER #/6 w/TOROUE RING 3.958 20926 6643 SHOE 4.5" RAY OIL TOOLS SILVERBULLET GUIDE SHOE ~ 0.000 General Notes Date Note ~ 1/26/2 i i ; I i i 006 TREE: WKM G5, 4.5" X 5M TREE CAP CONNECTION: OTIS 7" I i ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 1 C DATE: 12/21!06 OPERATOR REP: Rogers /Noble /Ives AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-20 Type tnj. W ND 6,540' Tubing 830 830 830 830 Interval I P.T.D. 2051230 Type test P Test psi 1635 Casing 933 1970 1960 1960 P!F P Notes: OA 337 460 470 485 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 1C-20 12-21-06.x1s RECEIVED STATE OF ALASKA N Q U 2 ~ 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIC Oil b Gas Cons. Cornmissian 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ~ Prod to WAG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended. Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConoCOPhllllps Alaska, lnC. Development ^ Exploratory ^ 205-123 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number:. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23273-00 7. KB Elevation (ft): 9. Wel! Name and Number: RKB 101' 1 C-20 8. Property Designation: 10. Field/Pool(s): ADL 28242, 25649, 28243, 28244 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 21081' feet - true vertical 6659' feet Plugs (measured) Effective Depth measured 2092T feet Junk (measured) true vertical 6643' feet Casing Length Size _ . MD = - _ .> TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 11012' 10-3/4" 11113' 4570' INTERMEDIATE 17612' 7-5/8" 17713' 6586' LINER 3414' 4-1/2" 2092T -6643' Perforation depth: Measured depth: Alternating Slotted/So lid Pipe 17720' - 20899' true vertical depth: 6587 - 6641' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 17575' MD. Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 515' 12. Stimulation or cement squeeze summary: 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 Casin Pressure Tubin Pressure Prior to well operation 149. 119 205 633 226 Subsequent to operation 4304 771 59 14. Attachments 15. Well Class after proposed work; Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations ~X 16. Well Status after proposed work: Oil^ Gas^ 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: 306-338 Contact Sob Christensen t Bob Suchhoiz Printed Name Ro D istensen Title Production Engineering Technician Signature Phone 659-7535 Date ~/ /~ O~ Form 10-404 Revised 04!2004 1 i K ~ t -7 ~ ! \f ~ ~ ~ '~~k~-`'s ~ F1I"fir .Submit Ori final Ont ~.! t ~ v II YVV ,~ ~ ~ ~ ~pOh . _ ~ y 1 C-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/15/06 Commenced Injection Service • FRANK H. MURKOWSKI, GOVERNOR f 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Buchholz ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 C-20 Sundry Number: 306-338 Dear Mr. Buchholz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As .provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2006 Encl. aob - (a3 Sincerely. ~ FtE~E{VEt~ ~°/ 1~co STATE OF ALASKA ~`1 OCT 0 2 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Alaska oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram Producer to g pp p g ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~eveiopment ~ • Exploratory ^ 205-123 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23273-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO Q 1C-20 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 28242, 25649; 28243, 28244 RKB 101' Kuparuk River Field !Kuparuk Oil Pool 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): 21081' ~ 6659' - 20927' 6643' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 11012' 10-3/4" 11113' 4570' INTERMEDIATE 17612' 7-5/8" 17713' 6586' LINER 3414' 4-1 /2" 20927' 6643' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Alternating Slotted/Solid Pipe 17720' - 2osss' s5s7' - ssa~' 4-1 /2" L-80 17575' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 515' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 20, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician Signature ~~ Phone 659-7535 Date ~ Z ~ d~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: W ~ ~~ -4-~i~~Q~TJC'C `Ct3 ~v~t`\~h~h. ~~ ~G~S V~ S~'C).1~~~~t'1~~~- Subsequent Form Required: y© ~ ~~~._, QCi Q ~ 2~~6 APPROVED BY - I D Approved by: COMMISSIONER THE COMMISSION Date: !0 Form 10-403 Revised 06/2006 Submit/in, Duplicate t~r~ /-N1 ~,,3.o L • l~ r .~ Cr~~c~c~~'~~~t~ps ~,~~s~c~, ~rr~, ~c-2o TUBING APL 50029232 (0-17575, SSSV T e: NIPPLE DD:4.500, Annular Fluid: Ip:3.958) Reference Loa: 40.3' RKE I SEAL (17537-17561, OD:4.750) _ 1 t. F:::%° ,_' - F /i basin Strom -ALL STRINGS • KRU 1C-20 PROD An le TS: 79 de 17680 1/28!2006 An le TD: 83 de 21081 Rev Reason: GLV CIO Last U date: 9/27/2006 21081 ftKB 96 deq (rD 18296 Descri tion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 80 80 164.90 SLX-42 Seamless SURFACE 10.750 0 11113 4570 45.50 L-80 BTG INTERMEDIATE 7.625 0 17713 6586 29.70 L-80 BTCM LINER 4.500 17513 20927 6643 12.60 L-80 BTC Tubing String -TUBING _ _ _ _ Size To Bottom ND Wt Grade Thread 4.500_ 0 _17575 6556 12,60 L-80 _ IBTM spl clr cplg _ 'Perforations Summar~r _ Interval ND Zone Status Ft SPF Date T e Comment 17720 - 17801 6587 - 6597 C-4 81 40 1!23/2006 Slots ARernating slotted/blank pipe wttor ue rin 18110 - 18352 6601 - 6583 C-4 242 40 1/23/2006 Slots ARernating slotted/blank pipe w/tor ue ring 18783 - 19719 6588 - 6584 C-4 936 40 1/23/2006 Slots ARernating slotted/blank pipe w/tor ue rin 20060 - 20426 6595 - 6608 C-4 366 40 1/23/2006 Slots ARernating slotted/blank pipe w/tor ue rin 20577 - 20697 6613 - 6621 C-4 120 40 1/23/2006 Slots ARernating slotted/blank pipe w/tor ue rin 20814 - 20899 6633 - 6640 C-4 85 40 1/23/2006 Slots ARernating slotted/blank pipe ___-_ ~ _ wttorque rin Gas Lift Mandrels/Valves _ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 4601 2534 CAMCO -~ KBG-2-1R OV 1.0 BK 0.250 0 9126!2006 - Other (plu~cs, equip., et - - - - c. COMPLETION JEWELRY ~_ - - - De th ND T e Descri tion ID 36 36 HANGER 2.5" FMC TUBING HANGER 3.900 515 514 NIP CAMCO'DB' NIPPLE w/3.875" NO GO PROFILE 3.875 16710 6317 SLEEVE-C BAKER CMU SLIDING SLEEVE 3.813" BX PROFILE -CLOSED 3.813 17535 6545 LOCATOR BAKER LOCATOR 3.970 17537 6546 SEAL BAKER BONDED SEAL ASSEMBLYw/17' OF SEALS w(BAKER SEAL 3.880 - -- SPACER PIPE ABOVE SEAL Other ( plugs, - equip., et c.) -LINER JEWELRY _ _ _ _ ~Depth~ ND ~ Type ~ Description ID~ 17513 6540 PACKER 'HRD' ZXP LINER TOP PACKER 4.960 17532 6545 NIP 'RS' PACKOFF SEAL NIPPLE 4.870 17535 6545 HANGER FLEXLOCK LINER HANGER 4.840 17545 6548 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17564 6553 XO 3.940 17839 6599 PACKER L-80 SWELL PACKER #6 w/TORQUE RING 3.958 18053 6601 PACKER L-80 SWELL PACKER #6 w/TORQUE RING 3.958 18390 6580 PACKER L-80 SWELL PACKER #6w/TORQUE RING 3.958 18726 6586 PACKER L-80 SWELL PACKER #6 w/TORQUE RING 3.958 19758 6584 PACKER L-80 SWELL PACKER #6 w/TORQUE RING 3.958 20002 6595 PACKER L-80 SWELL PACKER #6w/TORQUE RING 3.958 20492 6611 PACKER L-80 SWELL PACKER #6 w/TORQU E RING 3.958 20926 _ Gener 6643 SHOE 4.5" RAY OIL TOOLS SILVERBULLET GUIDE SHOE 0.000 _ - - - - al Notes _ _ Date _ _ Note 1l26I2006 TREE: WKM G5, 4.5" X SM TREE CAP CONNECTION: OTIS 7" • 1 C-20 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Alternating Gas (WAG) Injection service in Kuparuk Well 1 C-20. This well was pre-produced starting in late March 2006. Well 1C-20 will provide pressure support to offset producers. The 10-3/4" Surface casing (11114' and / 4570' tvd) was cemented with 1306 sx AS Lite followed by 680 sx LiteCrete. The 7-5/8" Intermediate casing (17714' and / 6586' tvd) was cemented with 255 sx Class G. The injection tubing/casing annulus is isolated via "HRD" ZXP 5-1/2" x 7-5l8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 17513' and / 6540' tvd. This well also contains several BTCM 4-1/2" L-80 Swell Packers with Torque Ring starting @ 17839' and / 6600' tvd. The top of Kuparuk C sand was found at 19921' and / 6591' tvd. The WFL and Temperature Log will be submitted after a three month injection period. This three month injection period will be reduced if we experience higher injection rates. • ~ a~~-~~ I~'C:iANICAL INTEGRITY REPORT ~ - _?UD L:.:~ : llf,~C._C~S-- OPER ~ FIELD ~'~Q,-~ `~~~ =..G r..~~~.,5. ~l~-SS'U ~ i,~LL NiRiTER `C."~C~ n~LL DATt TD: ~117~.?~.. ~o~oSC(TVD; PBTD: aOoi~~ ?ID G~f~'1~j TVD ~~~ Shoe : ~`1`l~~ t-ID ~S~ TVD ; DV : NA ?~ '1.)L~ T~`Di Casing: -=:~e= . ~~p~c~ Shoe. ~0~`Z. ~ 6G~-t3 T_VD ~ T^vP . ~"~.5~3 ~-~ I~SyC~ _';~ .:b'.: ~--L.S ~~Pacicer ~t1~(3 `~ TVD; Set et ~'lS'Z~~ ~ ~i o1e S~~e tt~~`_ and ~ ~~$ Perfs S~n~+c to t~~c~- ~~ ".'~ t ~ - ~p ~-~ S '~C'r'.~?~=C~ ~, I~TTEGR?TY - PA.KT # ~ ~nnu~us Press Test: _? 15 nin ~0 min Coc-~ents '~'CH~NIC~.i, ~ NTEGRIT T _ PART # Z ~ S3b~,~S . Cement Volt~es :~ r~~t. Liner ~{~-- Csg ~~~5~ DV '~~. C~.t -rol to cover oeTs ~-.~©~ ~S ~~4-S~ 5~.;%~~~~~ _ ~ ~vc~ ~~~~ 0~~5 5©C~ ~ tr~~Mp~,w~c tc c~.~~s ~ 1~'~ -~A M„- ~co- ~ _ =eoretical TOC ~° ~0~, ~c5 i ~ = ~~~~ Cement Bond Log (Y'es or No) ~~S _; In AOGCC Filed-S CBL Evaluation, gone above perfs ~~E rea~c Production Log: Type CONCLJS~ONS: Part #1: Evaluation YJ~N Re: KRU IC-20 (205-123) • Subject: Re: KRU 1C-20 (205-123) • From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 04 Oct 2006 14:39:58'-0800. To: ".lolu~ston~., Sa~t~" ~=-Sam..~~,hi~stonelu?.coi~ocoptzillips.cum:> CC: NSK 1'rc>d 1-:n~~r Tech <n 1 1 ~~~ ~i;conc~cophillih~.com>, i~'SK ~~'~:11 Integrity Proj =-N 1 ~7~lcuconoco;~hillips.co~T1= Sam, Thanks for your message. I concur with your pick for TOC and the range of the amplitude readings. Collars are pretty evident in the shallower portions of the log. As one goes deeper, although the collars still show it appears that the amplitude correlates with the formation changes evidenced by changes in the GR. There also appear to be formation signatures in the VDL. I concur with what the operations summary reported. It appears that the operations went very well considering the casing shoe was at 17700'. Regardless, your plan for the follow-up logs is appropriate. I will finish processing the sundry and move it forward for signature. Call or message with any questions. Tom Maunder, PE AOGCC Johnstone, Sam wrote, On 10/4/2006 2:04 PM: Tom, Schlumberger performed a "Free Pipe" calibration by applying a Fluid Correction Factor to the CBL curve to correct the free pipe value to the expected value of 60 mV. {The log is attached}. After calibrating the free pipe; the log still indicates poor cement quality across the interval. The CBL curve indicates free pipe is present down to ~15695' {>50 mV} and then fluctuates between 20 to 40 mV over the remaining log interval dawn to 17528' {likely less than 30% bond}. Although the CBL suggests a poor cement job, all signs while and after pumping the the cement job indicafie that the cement was properly place (good centralization, 100°lo returns, circulating pressure increase front 100 psi to 600 psi after displacing mud, cement was not green when drilled out, etc..). Additionally, the log was only performed down to 17528" prior to drilling out the cement down to the casing shoe at 17713' {this interval is now also covered by the 4-112" liner). 1Ne did not see anything while pre-producing the well that gave us an indication of cement quality, but all analyses of 1 C-20 water samples were "consistent" with other eastern 1 C area water sample analyses. Please let me know of any additional questions or concerns. --Sam -----Original Message----- From: Thomas Maunder [mailto:tom maunder a~admin.state.ak.us] Sent: Wednesday, October 04, 2006 9:53 AM To: Johnstone, Sam Cc: NSK Prod Engr Tech; NSK Well Integrity Proj Subject: Re: KRU 1C-20 (205-123) 1 of 4 10!4/2006 2:41 PM Re: KRU IC-20 (205-123) • Sam, Here are the series of messages we exchanged on this well. I have received a sundry from the slope to convert 1 C-20 to injection. Attached is a copy of the proposal sent with the sundry. There isn't a discussion of the cement quality, although the future logging plans are outlined. In order to assist my evaluation of the request and the well, could you please respond to my questions regarding the cement quality and whether Schlumberger has reprocessed the log? Tom Maunder, PE AOGCC Thomas Maunder wrote, On 5/1!2006 3:37 PM: Sam, Thanks for the information. That gives mean idea of the potential schedule. Is it possible that the production information will give some idea regarding the cement quality? Once converted, replacing the voidage does seem appropriate. I will look forward to seeing the sundry. I can't think of a need to discuss things further right now. Only question I have is has Schlumberger reprocessed the bond log to see if any enhancement is possible? Call or message with any questions. Tom Maunder, PE Johnstone, Sam wrote, On 5/1/2006 3:16 PM: Tom, We estimated up to three months injection prior to running the WFL and temperature log to allow time for fillup and repressuring of the C-sand interval after the 6-month pre-production period. (I would prefer to log the well under stabilized injection rates and bottomhole pressures to get a clear indication of where the injectant is going under representative long-term injection conditions.) The injection period prior to running the logs could be less if we see higher injection rates than expected. The well was put on production late March 2006, so I don't anticipate converting the well to injection prior to late September 2006. Prior to converting the well, we will file the sundry and discuss the interpretation of the bond log results and our logging plans as outlined below. Thank you for your feedback and let me know if you wish to discuss the injection period (prior to running the planned logs) any further. --Sam Sam Johnstone Office (907) 263-4617 Home (907) 746-5809 -----Original Message----- From: Thomas Maunder [mailto:tom maui:dcr~~admin.state.ak Sent: Friday, April 28, 2006 7:47 AM To: Johnstone, Sam Cc: Billingsley, Tim A; Harris, Marvin L. Subject: Re: KRU 1C-20 Sam, Tim and Marvin, In general, your plan seems appropriate. The only questionJconcern I us ] 2 of 4 10/4!2006 2:41 PM Re: KRU 1 C-20 (205-123} have is the duration of the injection period. Up to 3 months seems a little long. When do you plan to initiate injection? Since the well has been completed as a producer, someone over there will need to submit a sundry. It would be appropriate to discuss the interpretation of the bond log and include you plans as outlined below. Call or message with any questions. Tom Maunder, PE AOGCC Johnstone, Sam wrote, On 4/27/2006 4:31 PM: Tom, To verify that 1C-20 injection is isolated to the intended C-sand interval after the well is converted to injection, we recommend running a RST / Water Flow Log (WFL) with a temperature log as follows: 1) Inject into well until injection rate and pressure have stabilized (approximately 2 to 3 months) 2) Shut in the well 3) Run the RST / WFL log with temperature in the hole (utilizing a tractor if necessary) to establish a temperature baseline 4) While injecting, record WFL stations to look for flow out of the intended zone 5) SI the well, then perform a temperature log while coming out of the hole for comparison to the baseline temperature. Give me a call if you wish to discuss. Thanks, Sam Sam Johnstone Office (907) 263-4617 Home (907) 746-5809 ----Original Message----- ~\'~c~y ~~~~~- Fro Seitz, Brian L Sent: ursday, April 20, 2006 4:09 PM To: 'Thom Maunder' Cc: Billings Tim A; Johnstone, Sam; Harris, Ma zn L. Subject: RE: KR 1C-20 Tom- Sorry about not getting back t ou sooner on this one. I have asked Schlumberger for their reco nda ns for logging the well to provide assurance that we have a quate isol 'on. I expect we will recommend running either a temp ature log or wat flow log within a few months of the well being t on injection (we are rrently pre-producing the well). We wil dvise you shortly of our reco ended plan of action and we can then discuss whether that plan is sufficient. I've moved onto a new job, so Sam Johnstone will likely be the one who follows up with you. Sam can be reached at 263-4617. 3 of 4 10/4/2006 2:41 PM r COIl000~11~~1p5 Alaska P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 , -~ ~ u.-• ---. .~ __ August 6, 2006 _ _ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1C-20 (PTD 205-123), and 1E-04 (PTD 180-057). The reports record the addition of inhibited casing filler in the conductor tops. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. Sincerely, s~ i~'~ MJ oveland Problem Well Supervisor Attachments `~ ~~" I~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ECE~VED AUG 0 ~9 2006 REPORT OF SUNDRY WELL OPERATIAD~IS~-) b Gas Cons. Cammistinn 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ ot~ehoragi~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 205-123 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23273-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1 C-20 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 21081' - feet true vertical 6659' - feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 11012' 10-3/4" 11113' 4570' INTERMEDIATE 17612' 7-5/8" 17713' 6586' LINER 3414' 4-1/2" 20927 6643' Pertoration depth: Measured depth: 17720-17801',18110-1 8352',18783-19719',20060-20426',20814-20899' true vertical depth: 6587-6597',6601-6583',6588-6584',6595-6608',6613-6621',6633-6640' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 17575' MD. Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 740 1120 285 1250 348 Subsequent to operation 740 1120 ~ 285 1250 348 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 Gas^ 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: NA contact McConnel/Klein @ 659-7224 Printed Name Marie cConn I /ferry Klei~ Title Problem Well Supervisor Signature - ~ Phone Date ~~~J~ Pre aced b Sha Allsu Drake 263-4612 Form 10-404 Revised 04/2004 ORIGINAL ~~ 06 ~(~O Submit final nl ~~ 1 C-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/21/2006 Patched conductor circ ports with belzona. Top off conductor with RG 2401 inhibitor. T/I/0=280/750/300. TOC at ~6" below conductor top (at bottom of flutes on mandrel. hanger). Chipped cmt from cut off circ ports approximately 2' below conductor top. Patched circ ports with marine belzona 1111 (ceramic metal) to same thickness as conductor casing wall. Topped off conductor top with 1 gal of RG 2401 inhibitor and lazed mandrel hanger. 4 07/24/06 Sca~erger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth L~ ~~ i ~~~ NO. 3887 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 1E-102 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE 05/20/06 1 1E-105L1 11213766 INJECTION PROFILE 06/20/06 1 1 B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE WIDEFT O6I26I06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE WIDEFT 07/16/06 1 1C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-2~2 11249925 LDL O6/06/O6 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1H-04~ 11320991 INJECTION PROFILE 07!03106 1 1D-10'1 N/A INJECTION PROFILE O6/27/O6 1 2Z-13~ 11249930 LDL 07/11/06 1 1 D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28106 1 1J-101 40012836 MD 8~ TVD VISION RESISTIVITY 12/20/05 2 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ConocoPhillips June 15, 2006 Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 RECEIVED Commissioner JUN 2 0 2006 State of Alaska Alaska Oil & Gas Conservation Commission A~tlce 0i1 & Gas Cons. Gor-missioo 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 C-20 (APD # 205-123) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 C-20. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ~~ ~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~ECEIV~D REPORT OF SUNDRY WELL OPERATIC ,~ ~;~ & Gaa Conn. CornnrssioA 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^Q ~ OtheA~lTit'~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 205-1231 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23273-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 40' 1 C-20 8. j?rope ignatio~t~ L.zp •b(o ~~ + 10. Field/Pool(s): pS~DL~„~ 564~ 28243, 28244 " Kuparuk River Field i Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 21081' ~ feet true vertical 6659' feet Plugs (measured) Effective Depth measured 20927' feet Junk (measured) true vertical 6643' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 120' 120' SURFACE 11073' 10-3/4" 11113' 4570' INTERMEDIATE 17673' 7-5/8" 17713' 6586' LINER 3414' 4-1/2" 20927' 6643' Perforation depth: Measured depth: slotted liner from 17719'- 20895' true vertical depth: 6587'-6640' $ ~F~ JUN ~ 3 20D~ Tubing (size, grade, and measured depth) 4-112" , L-80, 17575' MD. Packers & SSSV (type & measured depth) HRD' zXP liner @ 17513' Camco'DB' nipple @ 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 20775'-17700' and Treatment descriptions including volumes used and final pressure : 100 bblS 12% HCI 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 543 862 428 -- 310 Subsequent to operation 1145 1601 539 -- 343 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature Phone Date ~/1~~~ Pre ar d b Sha on Allsu -Drake 263-4612 Form 10-404 Revised 04/2004 OKIGINAL '~F- t~ I a~ ~~ ~ Z~~ ~ Submit iginalOnly ~~~1~ Gont~~c~Philips Ala ka, Inc» 1c-2o API: 500292: TUBING ', SSSV Type: NIPPLE (0-17575, OD:4.500, ID:3.958) Annular Fluid: SEAL ;17537-17561, OD:4.750) Nell T e: PROD Orig 1/28/2006 ~m letion: Last W/O: An le TS: 79 de 17680 Angle @ TD: 83 deg @ 21081 Rev Reason: GLV C/O Last Uodate: 3/28/2006 Last Ta : TD: 21081 ftKB T ~__ _ ` Last Ta Date: Max Hole An le: 96 de 18296 Casing String -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 164.90 5LX-42 Seamless I SURFACE 10.750 0 11113 4570 45.50 L-80 BTC ~ INTERMEDIATE 7.625 0 17713 6586 29.70 L-80 BTCM ~ LINER 4.500 17513 20927 6643 12.60 L-80 BTC Tubing String.-TUBING Size I Top I Bottom _ TVD Wt Grade Thread ~ 17575 6556 12.60 L-80 IBTM spl clr cplg 4.500 __ 0 _ :Perforations Summary. _ Interval TVD Zone Status Ft SPF Date T e Comment 17720 - 17801 6587 - 6597 C-4 81 40 1/23/2006 Slots Alternating slotted/blank i w/tor ue rin > 18110 - 18352 6601 - 6583 C-4 242 40 1/23/2006 Slots Alternating slotted/blank I - ~ i r~1 ~a~ - I = - ~ ~ r~==«w r - I ~ ~ - -+ -~rt = I ~ ~ - = I - ~ ~ - ~.- • KRU 1C-20 10/OJ- IA/ iJ VJOO- VJOY l./-Y .7JV YV 1/GJ/LVVV JIVW Al1C111Q111 RJ. JIVLIGII/VIOI11~ i w/tor ue rin 20060 - 20426 6595 - 6608 C-4 366 40 1/23/2006 Slots Alternating slotted/blank i w/tor ue rin 20577 - 20697 6613 - 6621 C-4 120 40 1/23/2006 Slots Alternating slotted/blank LUtS14 - LUtSyy 6633 - 6640 ~ L-4 2Sb 4U l/Y3/ZUU6 JIOtS Hlternating SIOILeO/DIanK pipe w/torque ring Gas Lift MandrelsNalves _ _ ___ St~MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Cmnt ~ f ~ 1 1 4601 2534 CAM CO KBG-2-1 R OV 1.0 0.250 /22/20 Other lu s, equip.,. etc. -COMPLETION JEWELRY De th TVD T e Descri lion ID 36 36 HANGER 2.5" FMC TUBING HANGER 3.900 515 514 NIP CAMCO'DB' NIPPLE w/3.875" NO GO PROFILE 3.875 16710 6317 SLEEVE-C BAKER CMU SLIDING SLEEVE 3.813" BX PROFILE -CLOSED 3.813 17535 6545 LOCATOR BAKER LOCATOR 3.970 17537 6546 SEAL BAKER BONDED SEAL ASSEMBLY wl17' OF SEALS wlBAKER SEAL SPACER PIPE ABOVE SEAL 3.880 _ Other lu s, e quip.,_etc.) - LINER JEWELRY De th TVD T e Descri lion ID 17513 6540 PACKER 'HRD' ZXP LINER TOP PACKER 4.960 17532 6545 NIP 'RS' PACKOFF SEAL NIPPLE 4.870 17535 6545 HANGER FLEXLOCK LINER HANGER 4.840 17545 6548 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17564 6553 XO 3.940 17839 6599 PACKER L-80 SWELL PACKER #l6 w/TOROUE RING 3.958 18053 6601 PACKER L-80 SWELL PACKER #!6 w/TOROUE RING 3.958 18390 6580 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 18726 6586 PACKER L-80 SWELL PACKER f!6 wlTOROUE RING 3.958 19758 6584 PACKER L-80 SWELL PACKER #16 w/TOROUE RING 3.958 20002 6595 PACKER L-80 SWELL PACKER #t6 w/TOROUE RING 3.958 20492 6611 PACKER L-80 SWELL PACKER #6 w/TOROUE RING 3.958 20926 6643 SHOE LS SILVERBULLET GUIDE SHOE 4.5" RAY O IL T O O 0.000 _ __ _ __ _ General Notes --- _ _ - Date Note 1/26/2006 TREE: WKM G5, 4.5" X 5M TREE CAP CONNECTION: OTIS 7" 1 C-20 Well Events Summary DATE Summary 06/11/06 LAY IN 100 BBLS 12% HCL FROM 20775' TO 17700', POOH PUMPING DIESEL. NO FLUID RETURNS THROUGHOUT JOB. RIG BACK COIL TUBING UNIT AND TURN OVER TO TEST SEPARATOR CREW TO FLOW BACK. RE: KRU 1C-20 i ~ Sub,~ect: RE: KRU 1C-?0 _ From:"Seitz, Brian" <-Brian.Seitircr~,co~ocophillips.com> ~-~ ~ ~~~~ Date; 't'hu,20 Apr?OC~~> 16:Ob:~G -©800 To: 'l~lwmas ~~~~launder ~ =tom_maunc~cr(uailmin.stat~.ak.us='- ~C: "E3illin~~~lev. ~[~im A" <Tiny.:4.Billin~~sleti~~u?conoco~~hillips.com~=, ".lohnstone, Sam" <Sam..Iohn5lon~~a?ronocophilli]~s.com~~° "[{arris, tilarvin L." <=~~1ar~~in.L.Harrisrci'conocophilli~s.c.om> Tom- Sorry about not getting back to you sooner on this one. I have asked Schlumberger for their recommendations for logging the well to provide assurance that we have adequate isolation. I expect we will recommend running either a temperature log or water flow log within a few months of the well being put on injection (we are currently pre-producing the well}. We will advise you shortly of our recommended plan of action and we can then discuss whether that plan is sufficient. I've moved onto a new job, so Sam Johnstone will likely be the one who follows up with you. Sam can be reached at 263-4617. Regards, Brian 265-6961 -----Original Message----- From: Thomas Maunder [mailto:tom maznder:~admin.state.ak.us] Sent: Monday, April 10, 2006 11:09 AM To: Billingsley, Tim A; Seitz, Brian Subject: KRU 1C-20 Tim and Brian, I just had an opportunity to review the operations summary submitted with the completion report for 1C-20. What an ordeal!!! You all prevailed and got the well to TD and got pipe run. I also looked at the Christmas bond log and our message exchange around that time. The summary would indicate that operationally things went well, but the bond assessment is not as good as one would have expected. The well has been completed as a producer, but I would imagine that in the not too distant future that it will be converted. Do you all have a "new/different/better" assessment on the well's isolation. What appears to be the TOC comes in as expected around 16700. It is indicated that there is cement there, but qualitatively the log is pessimistic. I would appreciate hearing what you all's assessments are. Thanks. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 4/21/2006 8:05 AM ,. ~ 13 ~~ 5~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska e~ ~. oi`- l 7- 3 Apri105, 2006 RE: MWD Formation Evaluation Logs 1 C-20 PB 1, AK-MW-4046666 1 LDWG formatted Disc with verification listing. API#: 50-029-23273-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: ~ ~ 3 ~ 3 ~sfSS~ ass-J,~'' 4 ~ ~Sr WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska Apri105, 2006 RE: MWD Formation Evaluation Logs 1C-20, AK-MW-4046666 1 LDWG formatted Disc with verification listing. API#: 50-029-23273-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:_~~ Signed: /~ J ~33Y5~ aas'-1.I~' IR.E~EIVED 4 006 STATE OF ALASKA A P R Q 2 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSAtasks i3il & Gas Cons. Commission ®nrhnranp 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other 0 Pre Production Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: GonocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-123 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23273-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1 C-20 8. Property Designation: 10. Field/Pool(s): ADL 28242, 25649, 28243, 28244 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 21081' feet true vertical 6659' feet Plugs (measured) Effective Depth measured 21081 feet Junk (measured) true vertical 6659 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 11012' 10-3/4" 11113' 4570' INTERMEDIATE 17612' 7-5/8" 17713' 6586' PROD. CASING 3414' 4-1/2" 20927' 6643' Perforation depth: Measured depth: 17720-17801; 18110-18352; 18783-19719; 20060-20426; 20577-20697; 20814-20899 true vertical depth: 6587-6597; 6601-6583; 6588-6584; 6595-6608; 66 13-6621; 6633-6640 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 17575' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 515' 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-Bbi Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 340 ~ 228 547 1385 162 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OifO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the besYof my knowledge. sundry Number or N/A if C.O. Exempt: contact Robert D. Christensen Printed Name Title Production Engineering Technician Signature ~~ '------.-- Phone 5 -753 Date ,~~ ~P Form 10-404 Revised 04/2004 Q R i G ~ N A L ~~ Submit Original Only /f 1 C-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 3/3/2006 Well brought online for pre production phase • ConocoPhillips March 31, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Mq W~ ~ R AA~~~ ~' ~~ ;f~~ ~ I ~~46 ~~~> Subject: Well Completion Report for 1 C-20 (APD 205-123) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 C-20. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. Sincerely, r-....-. --......__ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_XX_Pre-producedlnjector 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: January 28, 2006 ` 12. Permit to Drill Number: 205-123 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 21, 2005 ~ 13. API Number: 50-029-23273-00 4a. Location of Well (Governmental Section): Surface: 1617' FNL, 1214' FWL, Sec. 12, T11N, R10E, UM / 7. Date TD Reached: January 9, 2006 ~ 14. Well Name and Number: 1C-20 At Top Productive Horizon: 444' FSL, 1515' FEL, Sec. 17, T11 N, R11 E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 372' FSL, 3410' FEL, Sec. 16, T11N, R11E, UM 9. Plug Back Depth (MD + TVD): 20927' MD / 6643' TVD Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562222 y- 5968622 ~ Zone- 4 10. Total Depth (MD + TVD): 21080' MD / 6659' TVD ~ 16. Property Designation: ADL 28242, 25649, 28243, 28244r TPI: x- 575074 y- 5960240 Zone- 4 Total Depth: x- 578459 ' - 5960203 ' Zone- 4 11. Depth where SSSV set:. Camco nipple @ 515' 17. Land Use Permit: ALK 2292, 3814, 2293 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3400' MD 2L Logs Run: ~,/~' GR/Res, Dens/Neu, SCMT ~•S'O 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# B 42' 120' 42' 120' 42" 685 sx AS I 10.75" 45.5# L-80 42' 11114' 42' 4570' 13.5" 1306 sx AS Lite, 680 sx LiteCrete 7-5/8" 29.7# L-80 42' 17714' 42' 6586' 9-7/8" 255 sx Class G 4.5" 12.6# L-80 17513' 20927' 6540' 6643' 6.75" slotted liner 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 4.5" 17575' 17513' slotted liner from 17719' - 20895' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) F TERIAL USED n/a _. _ . ,~ . ;` ~. t rv. •'°,. ,..,,~~ ,.,fig d° - 26. PRODUCTION TEST ° ~ -' Date First Production March 3, 2006 Method of Operation (Flowing, gas lift, etc.) pre-produced injector Date of Test 3/29/2006 Hours Tested 4.0 Production for Test Period --> OIL-BBL 136 GAS-MCF 274 WATER-BBL 206 CHOKE SIZE 100% GAS-OIL RATIO 2289 Flow Tubing press. 334 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 750 GAS-MCF 1716 WATER-BBL 1225 OIL GRAVITY -API (corn) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". S ;~~ss~ ~ r i~(~ t s L' I ~ ~jC NONE ~ f ~ I' _~ .- ~F..~n...._ _.,-.,,......~..rM.-4.,.F- ~~ ~~~ ~ APR 71006 Form 10-407 Revised 12/2003 ''? J CONTINUED ON REVERSE 2s. zs. 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". 1 C-20 Top Kuparuk C 19920' 6591' C-4 17680' 6580' N/A 1 C-20PB1 TD 18683' 6586' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 Printed Name Rand Thomas Title: Greater Kuparuk Area Drilling Team Leader S `3 f ''!® Signature ~`. v ~:>-----__P.t~e ~.4 5 E ~ s~, Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing 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 12/2003 Con'ocoPhillips Alaska Page ~ of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To I Hours Code II ' Phase , C ode 11!17!2005 I~ 0 12.00 ~ RIGMNT _ RGRP ~ MOVE 11 /18/2005 00:00 - 01 :30 1.50 RIGMNT RGRP I MOVE 01:30 - 02:00 0.50 MOVE SFTY MOVE 02:00 - 03:00 i 1.00 RIGMNT RGRP MOVE 03:00 - 04:30 1.50 MOVE ~ DMOB MOVE 04:30 - 06:30 2.00 MOVE - MOB MOVE 06:30 - 10:00 3.50 ; MOVE MOB MOVE 10:00 - 12:00 2.00 MOVE MOB ~ MOVE 12:00 - 15:00 3.00 MOVE MOB ~ MOVE 15:00 - 16:15 , 1.25 MOVE I MOB MOVE 16:15 - 18:00 ~ 1.75 MOVE j MOB MOVE 18:00 - 22:30 I 4.50 i MOVE I RURD I MOVE 22:30 - 00:00 1.50 MOVE RURD MOVE 11/19/2005 00:00 - 03:00 3.00 WELCT NUND RIGUP 03:00 - 03:30 0.50 MOVE I RURD RIGUP 03:30 - 06:00 2.50 DRILL I PULD RIGUP 06:00 - 08:45 I 2.75 i DRILL I PULD I RIGUP 08:45 - 09:15 0.501 DRILL SFTY RIGUP 09:15 - 13:30 4.25 i RIGMNT; RGRP RIGUP 13:30 - 14:15 0.75 ~ WELCTL~ BOPE RIGUP 14:15 - 18:00 3.75 RIGMNT RGRP ;RIGUP 18:00 - 00:00 6.00 DRILL PULD RIGUP 11/20/2005 ~ 00:00 - 02:30 2.50 DRILL PULD RIGUP 02:30 - 05:30 3.00 RIGMNTI RGRP RIGUP 05:30 - 13:30 8.00 i DRILL ~ PULD RIGUP 13:30 - 15:30 2.001 DRILL PULD , SURFAC 15:30 - 16:15 0.75 DRILL PULD j SURFAC 16:15 - 16:30 0.25 DRILL SFTY I SURFAC 16:30 - 17:00 ~ 0.50 DRILL SFTY SURFAC 17:00 - 18:45 ~ 1.75 DRILL PULD SURFAC 18:45 - 19:15 0.50 DRILL ' PULD SURFAC 19:15 - 20:15 1.00 DRILL ~ CIRC SURFAC 20:15 - 00:00 3.75 ~ RIGMNT RGRP SURFAC Description of Operations Repair 399 Cat engine. Working on 399 Cat engines /blown head gasket. 03:00 Fixed. Start move. Fire up 399 Cat check for leaks and inspect. Pre job safety meeting for moving rig. Rig repair: Electrical problem on moving system. Jack up rig and move rig of mats. Move off mats and move mats to new location. Set herculite and prepare location for rig. Set well head equipment aroung well. PJSM: Spot sub over well on 1 C-20 Preload back feet on sub. Work on alignment of back doors in cellar. Move pit complex and spot. PJSM: Prepare rig floor and skid into place. Hook up steam, water,air, flow lines, gas buster, and panic line. Install roof caps and hand on sub base. Berm up around cellar and hook up mud lines between rig and pits. Continue to rig up over well. Berm rock washer, organize cellar, hook up air to rig floor, etc. Rig up diverter and bell nipple. Order out water to fill pits. Continue nipplig up diverter, bell nipplem flowline and load drill pipe into pipe shed. Remove all 4' equipment from rig floor Set beaver slide and pin Fill pits with 290 bbl of water. Put screens on shakers and continue loading pipe shed with drill pipe. Continue to load pie shed with 5"drill pipe. Remove SRI's from stabbing board, beaver slide and from under rig floor to be sent infor inspection. Install mouse hole and check all lines. Start mixing spud mud. Pre job safety meeting on picking up drillpipe. Pick up 1 joints of drill pipe and stand back in derrick Work on skate pull chain Test diverter system and accumulator. Tests witnessed by John Spaulding, AOGCC rep. Continue to repair skate Repair skate Pick up 50 joints of drill pipe and stand back in derrick. Drift with 3.0" rabbit Continue to pick up 5" drill pipe and drift with 3" rabbit. Work on rig floor hydraulic power unit. 5 gallon spill called into security and PIR sent. All spill contained to secondary containment. Continue to pick up 5" drill pipe and stand back in derrick. Pick up 5" HWDP, jars and stand back in derrick. Remove mouse hole. Pick up handling tools and pick up BHA. Diverter drill 1 minute 25 seconds with evacuation drill 4 minutes. PJSM: Rig up gyro and E-line. Pick up BHA Bit, Motor, Stab, and MWD. Up load MWD tool. Load system and lines, check for leaks and prepare rig to drill. Top drilve will not rotate. Change out SCR board and trouble shoot. Change hydraulic oil filter on top drive and use heater to warm up top drive. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To 'Hours Code Sub ,Phase 11/21/2005 100:00 - 01:45 ~ 01:45 - 02:45 02:45 - 06:00 06:00 - 10:30 10:30 - 11:00 11:00 - 11:45 ;11:45 - 12:00 12:00 - 13:00 113:00 - 18:00 i 18:00 - 20:00 20:00 - 21:00 21:00 - 21:15 21:15 - 22:30 22:30 - 00:00 11 /22/2005 00:00 - 06:00 06:00 - 12:00 12:00 - 18:00 1.75 1.00 3.25 4.50 0.50 0.75 0.25 1.00 5.00 2.00 1.00 0.25 1.25 1.50 6.00 6.00 6.00 Code1 DRILL DRLG SURFAC DRILL PULD DRILL DRLG RIGMNT RGRP SURFAC SURFAC Start: 11 /18/2005 Rig Release: 1/28/2006 Rig Number: 15 Page 2 of 57 Spud Date: 11/21/2005 End: 1 /28/2006 Group: Description of Operations 'Spud in with Bit, mtr. mwd, ubho, hwdp. 550 gpm 1150 psi. Pick up weight = 85,000#: Slack off weight = 85,000# POH to change BHA and pick up NMFDC. Drill from 250 to 353 feet Pick up weight = 90,000# Slack off weight = 90,000# Rotating weight = 90,000# SURFAC DRILL I TRIP SURFAC DRILL TRIP SURFAC DRILL DRLG SURFAC DRILL ' TRIP SURFAC RIGMNT RGRP I SURFAC RIGMNT RGRP SURFAC RIGMNT RGRP .SURFAC RIGMNT RGRP SURFAC DRILL DRLG SURFAC DRILL ~ DRLG ;SURFAC DRILL I DRLG DRILL DRLG SURFAC SURFAC DRILL DRLG SURFAC POOH 3 stands and trouble shoot top drive problems. PJSM to trip in hole. Trip in hole to 353 and break circulation. Drill 353 to 368 feet 500 gpm = 1300 psi. Top drive still not working right. POOH to surface and work on top drive. Trouble shoot top drive and change out decoder and repair cable. Continue to trouble shoot top drive., isolate shield on wires and repair service loop wiring. Function test top drive. Function make up and break out. Rotate and work top drive through derrick. PJSM to trip in hole and drill surface. Trip in hole with BHA Drill from 368' to 529' AST = 1.32 hours bit hours = 3.47 hrs//jar hours = 99.5. Flowing @ 500 gpm 1300 psi on bottom drilling. ROP 100 - 200 fph. pick up weight - 90,000# // Slack off weigh = 90,000# // Rotating weight = 90,000# Taking shots with gyro every 200'. MWD MTF looks clear and tracks gyro too{face. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f/ 529'- 1002' (975' TVD) (473') ART .84 hrs AST 2.07 hrs., Total hrs on bit = 6.38 hrs., Total hrs on jars = 102.38 hrs, 20-30 k WOB, 60 rpm's, 130-136 motor rpm, 500-523 gpm, 8.6-9.0 ppg mw, on bottom pressure 1476-1500 psi, off bottom pressure 1070-1300 psi, on bottom torque 5-6k fUlb, off bottom torque 2-3k ft/Ib, PU wt 95-112k, SO wt 98-112k, Rot wt 110-1,12 k. Background gas 20-40' units Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f/ 1002'- 1513' (1401' TVD) (511') ART 1.79 hrs AST 1.75 hrs., Total hrs on bit = 9.92 hrs., Tota{ hrs on jars = 105.92 hrs, 15-30 k WOB, 60 rpm's, 136-149 motor rpm, 523-574 gpm, 9.0-9.6 ppg mw, on bottom pressure 1500-1750 psi, off bottom pressure 1300-1700 psi, on bottom torque 5-8k ft/Ib, off bottom torque 2-5k ft/Ib, PU wt 112-122k, SO wt 112k, Rot wt 112 k. Note: Hydrates @ 1200'. Background gas was 20-40 units. After encountering hydrates, background 120-140 then up to 160-180 units. Max gas 280 units @ 1265' @l Q950 hrs. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f/ 1513'- 2047' (1726' TVD) (534') ART 1.39 hrs AST 2.96 hrs., Total hrs on bit = 14.27 hrs., Total hrs on jars = 110.27 hrs, 25-30 k WOB, 60 rpm's, 136-149 motor rpm, 574-500 gpm, 9.6 ppg mw, on bottom pressure 1800-1600 psi, off bottom pressure 1600-1500 psi, on bottom torque 6-8k fUlb, off bottom torque 4-6k ft/Ib, PU wt 121-123k, SO wt 113-110k, Rot wt 112-110 k. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 3 of 57 Opera#ions Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From`- To 'Hours ~! Code 'Sub ', phase Description of Operations Code 11 /22/2005 - __ _ __ - 12:00 - 18:00 6.00 (DRILL DRLG SURFAC 18:00 - 19:15 1.25 ~ DRILL DRLG SURFAC 19:15 - 21:00 21:00 - 22:30 22:30 - 23:00 23:00 - 00:00 11 /23/2005 ~ 00:00 - 02:00 02:00 - 06:00 06:00 - 12:00 12:00 - 16:30 1.751 DRILL I REAM I SURFAC 1.501 DRILL I DRLG I SURFAC 0.50 DRILL SURV SURFAC 1.00 DRILL REAM SURFAC 2.001 DRILL I REAM I SURFAC 4.00 DRILL DRLG SURFAC 6.00 DRILL DRLG SURFAC 4.501 DRILL i DRLG I SURFAC Avg background gas 250 units. Max 385 units @ 1670' @ 1355 hrs. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f/ 2047'- 2142' (1775' TVD) (95') ART 0 hrs AST .73 hrs., Total hrs on bit = 15.00 hrs., Total hrs on jars = 111.0 hrs, 25-35 k WOB, 60 rpm's, 136-143 motor rpm, 525-550 gpm, 9.6 ppg mw, on bottom pressure 1750-1720 psi, off bottom pressure 1625-1650 psi, 100% slide = no torque on or off bottom, PU wt 125-130k, SO wt 105-111 k, Rot wt 114k. Avg background gas 250 units. Max 351 units @ 2130' @ 1905 hrs.. Stand back a stand. Ream. and wash f12942' to 2050' to drop angle. Avg background gas 250 units. Max gas while reaming 425 units Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f/ 2142'- 2334' (1875' TVD) (192') ART .20 hrs AST .88 hrs., Total hrs on bit = 16.08 hrs., Total hrs on jars = 112.08 hrs, 10-20 k WOB, 60 rpm's, 136 motor rpm, 524-528 gpm, 9.6 ppg mw, on bottom pressure 1625-1680 psi, off bottom pressure 1550-1570 psi, on bottom torque 7-8k ft/Ib, off bottom torque 4-5k ft/Ib, PU wt 125-130k, SO wt 111-105k, Rot wt 115 k. Background gas 85-1 units. Max gas 186 units. @ 2150' @ 2115 hrs Connection and survey. Stand back a stand. Ream and wash f/ 2241' to 2334' to drop angle. Pumping 600 gpm w/ 1900 psi, rotate 60 rpm.Avg backgrouruf gas 200-24U units. Max gas 285 units whiff reaming. Ream and wash f/ 2241' to 2334' to drop angle. Pumping 600 gpm w/ 1900 psi, rotate 60 rpm.Avg background gas 200-2441 utrits. RAaak gas 285 units while reaming. Note:Avg background 180 units, max gas @ 0040 hrs 285 units. Directional drill 13-1/2" hole w/Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f! 2341'- 2724' (1975' TVD) (390') ART 1.1 hrs AST 1.51 hrs., Total hrs on bit = 18.69 hrs., Total hrs on jars = 114.77 hrs, 10-30 k WOB, 60 rpm's, 136 motor rpm, 524-530 gpm, 9.6 ppg mw, on bottom pressure 1680-1800 psi, off bottom pressure 1570-1630 psi, on bottom torque 7-10k ft/Ib, off bottom torque 4-9k ft/Ib, PU wt 135-128k, SO wt 105-100k, Rot wt 115- 110k. Note: Avg background gas 160 units, max gas 353 units @ 0530 hrs @ 2680'. Directional drill 13-1/2" hole w/ Sperrydrill 4l5-5.3 stage mtr w/ 1.83 deg bend f/ 2724'- 3155' (2099' TVD) (431') ART 2.01 hrs AST 1.7 hrs., Total hrs on bit = 22.4 hrs., Total hrs on jars = 118.48 hrs, 10-30 k WOB, 60 rpm's, 127-163 motor rpm, 489-628 gpm, 9.6 ppg mw, on bottom pressure 1800-1990 psi, off bottom pressure 1600-1890 psi, on bottom torque 6-10k ft/Ib, off bottom torque 6-10k ft/Ib, PU wt 128-132k, SO wt 100-98k, Rot wt 111-112k. Note: Avg background. gas 200 units,' max gas 410 units @0925 hrs @ 2915'. Directional drill 13-112" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.83 deg bend f/ 3155'- 3493' (2189' TVD) (338') ART 2.52 hrs AST .42 hrs., Total hrs on bit = 25.34 hrs., Total hrs on jars = 121.42 hrs, 10-30 k WOB, 60 rpm's, 147-170 motor rpm, 565-655 gpm, 9.6 ppg mw, on bottom pressure 1990-2518 psi, off bottom pressure 1890-2480 psi, on bottom torque 7-11 k fUlb, off bottom torque 8-5k ft/Ib, PU wt 132-118k, SO wt 98-95k, Rot wt 111-105k. Note: Avg background gas 160 units, max gas 275~wstts @ 9500 hrs @ Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 11 /23/2005 11/24/2005 From - To Hours ~ Code Phase _- ~ __ _ Code1_ - 12:00 - 16:30 ~ 4.501 DRILL i DRLG SURFAC 16:30 - 18:00 1.50 ~ DRILL REAM .SURFAC ,18:00 - 21:15 3.25 i DRILL REAM SURFAC 21:15 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01:00 01:00 - 01:30 01:30 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 10:00 10:00 - 10:30 10:30 - 12:15 1.25 0.50 0.50 0.50 1.00 0.50 1.00 1.00 0.50 6.00 DRILL DRILL DRILL DRILL DRILL DRILL DRILL TRIP TRIP SFTY TRIP PULD PULD PULD PULD RSRV RGRP SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC 0.50 1.75 SFTY PULD SURFAC SURFAC DRILL RIGMNT RIGMNT DRILL DRILL 12:15 - 12:30 0.25 DRILL 12:30 - 13:30 1.00 DRILL 13:30 - 14:30 ~ 1.00 ~ DRILL 14:30 - 14:45 0.25 DRILL 14:45 - 15:30 ; 0.75 DRILL 15:30 -16:00 0.50 DRILL 16:00 - 16:30 ' 0.50' DRILL 16:30 - 16:45 0.25 DRILL 16:45 - 17:30 , 0.75 ; DRILL 17:30 - 17:45 ~ 0.251 DRILL 17:45 - 18:00 0.25' DRILL 18:00 - 19:15 1.25 ~ DRILL 19:15 - 20:15 20:15 - 21:00 PULD 'SURFAC TRIP SURFAC TRIP ,SURFAC CIRC SURFAC TRIP SURFAC TRIP SURFAC CIRC ;SURFAC OTHR SURFAC TRIP SURFAC CIRC I SURFAC CIRC ~ SURFAC CIRC ~ SURFAC 1.00 DRILL 'iOTHR 0.75; DRILL I DRLG SURFAC SURFAC Start: 11 /18/2005 Rig Release: 1/28/2006 Rig Number: 15 Page 4 of 57 Spud Date: 11/21/2005 End: 1 /28/2006 Group: Description of Operations 3400'. Backream out of hole f/ 3493' to 2812'. Pump @ 580 gpm w/ 2100 psi, 60 rpm. Backream out of hole f/ 2812' to 1576'. Pump @ 580 gpm w/ 1930 psi, 50 rpm. torque 7-9k ft/lb. Note: Max gas units while backreaming: 304 units ~ 2030 hrs: Blow down top drive. Pull out of hole on elevators f/ 1576' to HWDP @ 816'. Pull out of hole on elevators f/ 816' (5" HWDP) to 8" flex DC's @ 160'. PJSM on handling BHA # 1. Clean rig floor. UD UBHO sub and float sub. Stand back stand of 8" flex collars to 61'. PU and drain motor. Clean stab and bit #1. Clean floor. Download MWD. Fill MWD w/ water and drain. UD MWD, pressure drop sub, crossover, welded blade stabilizer, motor and bit. Clear floor. PU stand and inspect same. OK. Service top drive and rig and crown. Trouble shoot Varco TDS -8SA top drive system. Rig electrician and Quadco rep Steve Edwards. PJSM on picking up and make up of BHA #2. PU/MU BHA #2:13-1 /2" Hughes HC607SZ(ser # 7005882) (7 blades- 9jets-- 12/32's =.99 TFA), 8" SperryDrill lobe 4/5-5.3 stage motor w/ 1.5 deg bend, 12-1/4" welded blade stabilizer, crossover, Sperry 8" Gamma/Res, 8" Directional pulser, float sub, 13-1l4" interal blade stabilizer. Upload MWD tools and test same. MU stand of 8" flex collars, RIH w/jars and 5" HWDP to 836' RIH w/ Weatherford 5" dp f/ 836' to 1412'. Fill pipe, break circulation. RIH w/ Weatherford 5" dp f/ 1412' to 1564'. Install Weatherford 13-112" ghost reamer (ser # 269646). RIH w/ Weatherford 5" dp f/ 1564' to 1800'. Fill pipe, break circulation @ 1800'. Shallow test MWD. OK. Blow down top drive. Continue RIH w/ Weatherford 5" dp f/ 1800' to 3410'. PU wt @ 3410' _ 155k, SO wt = 100k. MU Varco TDS- 8SA top drive, fill pipe, break circulation. Tag bottom @ 3493'. PU wt 150k, SO wt 100k, Rot wt 120k. Break circ slow and stage pumps up to 475 gpm w! 1370 psi. Condition mud and hole to allow 700-900 gpm flow rates prior to drilling ahead. Stage pumps up f/ 475 gpm w/ 1370 psi to 900 gpm w/ 3500 psi. Condition mud and hole to allow 700-900 gpm flow rates prior to drilling ahead. Change shaker screens on scalper shaker f! 38's to 4's. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg bend f/ 3493'- 3572' (2205' TVD) (79') ART .21 hrs AST .21 hrs., Total hrs on bit =.42 hrs., Total hrs on jars = 121.84 hrs, 10-15 k WOB, 50 rpm's, 233 motor rpm, 897 gpm, 9.6 ppg mw, on bottom pressure 3550 psi, off bottom pressure 3500 psi, on bottom torque 8 k ft/Ib, off bottom torque 8 k ft/Ib, PU wt 145k, SO wt 108k, Rot wt 128k. Note: Avg background gas 250 units, max gas 339 units @3572' @ 2050 hrs. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 5 of 57 Operations Sulmrnary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours Code Code I Phase L l 11/24/2005 121:00 - 23:00 I _- -_ 2.00 RIGMNT . _ __ _ - RGRP SURFAC 23:00 - 23:15 0.25 .DRILL - TRIP ,SURFAC 23:15 - 00:00 0.75 DRILL DRLG SURFAC 11/25!2005 00:00 - 06:00 6.00' DRILL DRLG ~ SURFAC 06:00 - 12:00 6.00' DRILL DRLG SURFAC 12:00 - 18:00 6.00' DRILL DRLG SURFAC i 18:00 - 21:45 i 3.75 DRILL DRLG SURFAC 21:45 - 00:00 2.25 ~ DRILL REAM SURFAC 11/26/2005 00:00 - 02:30 ~ 2.501 DRILL REAM ~ SURFAC 102:30 - 04:30 I 2.00 DRILL REAM SURFAC 04:30 - 05:30 I 1.00 DRILL TRIP SURFAC Description of Operations Problem w/ # 2 mud pump, # 1 cylinder: Liner gasket leak. Replace ~! liner gasket, wear plate and liner. Backream f/ 3572' to 3219' while working on pump #2. Pump 105 spm w/ # 1 mud pump, backream slow. Note: avg badcgrc-und gas 190 units, max gas 299 un'Rs @ 2130 hrs. Trip in hole f/ 3219' to 3572'. Fill pipe. Ream last stand to bottom. Directional drill 13-1l2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg bend f/ 3572'- 3693' (2238' TVD) (121') ART .51 hrs AST 0.0 hrs., Total hrs on bit =.93 hrs., Total hrs on jars = 122.35 hrs, 5-10 k WOB, 90 i rpm's, 236 motor rpm, 900 gpm, 9.6 ppg mw, on bottom pressure 3500-3300 psi, off bottom pressure 3320-3180 psi, on bottom torque 7-10k ft/Ib, off bottom torque 5-9k ft/lb, Pll wt 145k, SO wt 111k, Rot wt 128k. ,Note: avg background gas. 230 units, gas 307 units @ 3675' @ 2355 hrs. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg ~ bend f/ 3693' to 4432' (2468' TVD) (739') ART 2.71 hrs AST .61 hrs., Total hrs on bit =4.25 hrs., Total hrs on jars = 124.85 hrs, 5-12 k WOB, 90 rpm's, 234 motor rpm, 900 gpm, 9.6 ppg mw, on bottom pressure 3300-3500 psi, off bottom pressure 3180-3500 psi, on bottom torque 6-10k ft/Ib, off bottom torque 6-10k ftllb, PU wt 143-150k, SO wt 111-115k, Rot wt 128-130k. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg bend f/ 4432' to 5027' (2670' TVD) (595') ART 1.62 hrs AST 1.36 hrs., Total hrs on bit =7.23 hrs., Total hrs on jars = 126.44 hrs, 5-10 k WOB, 90 rpm's, 227-203 motor rpm, 875-780 gpm, 9.6 ppg mw, on bottom pressure 3450-2891 psi, off bottom pressure 3300-2900 psi, on bottom .torque 9-13k fUlb, off bottom torque 6-12k ft/lb, PU wt 155-175k, SO wt 115-108k, Rot wt 130-132k. Directional drill 13-1 /2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg bend f/ 5027' to 5691' (2670' TVD) (664') ART 2.29 hrs AST .94 hrs., Total hrs on bit =10.46 hrs., Total hrs on jars = 128.73 hrs, 5-10 k ~WOB, 90 rpm's, 221-208 motor rpm, 850-800 gpm, 9.4 ppg mw, on bottom pressure 3000-3510 psi, off bottom pressure 2900-3260 psi, on ~, bottom torque 8-19k ftAb, off bottom torque 8-12k ft/lb, PU wt 175-190k, SO wt 108-95k, Rot wt 132-135k. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg bend f/ 5691' to 6070' (2982' TVD) (379') ART 1.31 hrs AST .65 hrs., Total hrs on bit =12.42 hrs., Total hrs on jars = 130.04 hrs, 2-10 k WOB, 90 rpm's, 208-209 motor rpm, 800-804 gpm, 9.4 ppg mw, on bottom pressure 3260-3200 psi, off bottom pressure 3080-3020 psi, on bottom torque 12-19k ft/Ib, off bottom torque 12-20k ft/lb, PU wt i 190-200k, SO wt 95-98k, Rot wt 134-138k. Backream out of hole f/ 6070' to 5020' @ midnight due to dirty hole. -Ream w/pulling speed of 20 fpm, 90 rpm, w/ 11-20 ft/Ib torque. 900 gpm w/ 3600 psi. Backream out of hole f/ 5020' to 4361' due to dirty hole. Ream w/ pulling speed of 20 fpm, 90 rpm, w/ 11-20 ft/Ib torque. 900 gpm w/ 3600 psi. Backream out of hole f/ 4361' to 4266' due to dirty hole. Ream w/ pulling speed of 4fpm, 90 rpm, w/ 8-16 ftllb torque. 900 gpm w! 3250 'psi. RIH last stand pulled, blow down top drive. Trip in f/ 4361' to 5978'. ;Clean suction screens on pumps while RIH. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page s of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 'From - To j Hours ~ Code 'Code ~ Phase ! Description of Operations 11/26/2005 05:30 - 05:45 I 0.25 ~ DRILL CIRC SURFAC MU top drive. Fill pipe. Precautionary ream last stand f/ 5978' to 6070'. 05:45 - 06:00 0.25 06:00 - 10:00 4.00 11 /27/2005 10:00 - 12:00 ' 2.00 12:00 - 18:00 6.00 18:00 - 19:30 ~ 1.50 19:30 - 21:45 21:45 - 23:00 23:00 - 00:00 00:00 - 01:45 01:45 - 02:00 02:00 - 03:00 03:00 - 03:15 03:15 - 03:45 03:45 - 04:30 04:30 - 05:00 2.25 1.25 1.00 1.75 0.25 1.00 0.25 0.50 0.75 0.50 05:00 - 06:00 1.00 as:oo - oa;oo 2.00 08:00 - 08:15 ~ 0.25 No problems. DRILL DRLG ,SURFAC ,Directional dri{I 13-1l2" hole w/ Sperrydrill 415-5.3 stage mtr w/ 1.50 deg bend f/ 6070' to 6104' (2993' TVD) (34') ART .27 hrs AST 0 hrs., Total hrs on bit =12.69 hrs., Total hrs on jars = 130.31 hrs, 5-10 k WOB, 90 j rpm's, 234 motor rpm, 900 gpm, 9.4 ppg mw, on bottom pressure 4120 i psi, off bottom pressure 3850 psi, on bottom torque 12-19k ft/Ib, off bottom torque 10-19k fUlb, PU wt 200k, SO wt 98k, Rot wt 138k. DRILL DRLG SURFAC i Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.50 deg ;bend f/ 6104' to 6370' (3088' TVD) (266') ART .87 hrs AST .68 hrs., ' Total hrs on bit =14.24 hrs., Total hrs on jars = 131.18 hrs, 8-11 k WOB, 90 rpm's, 234-208 motor rpm, 900-800 gpm, 9.4 ppg mw, on bottom pressure 3910-3750 psi, off bottom pressure 3810-3620 psi, on bottom torque 12-20k ft/Ib, off bottom torque 12-20k fUlb, PU wt 200k, SO wt 95k, Rot wt 141 k. DRILL REAM SURFAC Backream out of hole f/ 6370' to 6100' due to high pump pressure (plugged nozzles??). Ream w/ pulling speed of 30-40 fpm, 90 rpm, w/ 15-22 ft/Ib torque. 600 gpm w! 3100 psi. DRILL REAM SURFAC 'Backream out of hole f/ 6100' to 3886' due to high pump pressure (plugged nozzles??). Ream w/ pulling speed of 30-40 fpm, 90 rpm, w/ 10-22 ft/Ib torque. 600 gpm w/ 3100-2800 psi. PU wt 165k, SO wt 100k ' @ 3886 DRILL REAM SURFAC Backream out of hole f/ 3886' to 3316' due to high pump pressure ' (plugged nozzles??). Ream w/pulling speed of 25 fpm, 90 rpm, w/ 10k fUlb torque. 640 gpm w/ 3085 psi. DRILL REAM SURFAC Backream out of hole f/ 3316' to 3029' @ 640 gpm w/ 3085 psi. ' Backream 2-3' per min (30-45 fUhr) w/ 90 rpm and 10k ft/Ib torque. DRILL TRIP SURFAC Blow down top drive, attempt to pull on elevators, swabbing. MU top drive, pump out of hole f/ 3029' to 2173' @ 325 gpm w/ 1000 psi. DRILL TRIP SURFAC Blow down top drvie. Pull out of hole f/ 2173' to 1406'. DRILL I TRIP SURFAC ~ Swabbing: Make up top drive. Pump out of hole f/ 1406' to 1026' w/ 524 DRILL ,TRIP SURFAC ,,gpm and 1900 psi. Pull out of hole from 1026' to 836' to BHA. DRILL TRIP SURFAC Pull out of hole from 836' to 180' (all HWDP out of hole). Removed corrosion ring f! jars. DRILL SFTY SURFAC ~ PJSM w/ Sperry Sun MWD and Sperry Sun directional drillers, and co DRILL OTHR SURFAC rep w/drilling crew on handling BHA # 2. Clean rig floor DRILL TRIP SURFAC POOH one stand 8" flex collars, break and remove 13-1/4" stab, make stand back up to float sub, break float sub and stand back stand. DRILL TRIP SURFAC Pull Sperry sun MWDlLWD tools, crossover, 12-1/4" welded blade stabilizer, 8" SperryDrill lobe 4/5-5.3 stage motor (ser # 800441) and Hughes 13-1/2" type HC607SZ (ser # 7005882) bit. ' 'Note: 12-1/4" stab has a ring grooved near top side of stab. Also top of " " bit body has a groove. Pictures will be posted to x drive folder. DRILL PULD SURFAC i Download Sperry Sun MWD/LWD tools @ 81' DRILL PULD SURFAC : UD Sperry Sun MWD, pulser, 8" Gamma/lRes, crossover, 12-1/4" welded blade stab, 8" SperryDrill motor(ser # 800441) w/ 1.5 deg bend, break hughes 13-1/2" PDC (HC607SZ) (ser # 7005882). i Note: Hughes bit #2 had 6 nozzles plugged w/ rubber f/ Sperry Sun motor. Bit showed showed signs of ringout on top side of guage ` .protection. Some chipped cutters. DRILL j SFTY SURFAC PJSM w/ Sperry Sun MWD and Sperry Sun directional drillers, and co Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operatiolns Summary Report.... Legal Well Name: 1C-20 Common Well Name: 1C-20 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To 'Hours ' Code Code1 Phase 11/27/2005 08:00 - 08:15 ! 0.25 ~ DRILL SFTY SURFAC 08:15 - 10:00 I, 1.75 ~ DRILL i PULD ~ SURFAC 10:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 13:45 13:45 - 14:45 14:45 - 15:45 15:45 - 16:15 16:15 - 16:45 16:45 - 17:30 0.50 1.50 1.00 0.75 1.00 1.00 0.50 0.50 0.75 17:30 - 18:00 ' 0.50 18:00 - 23:00 : 5.00 23:00 - 23:15 0.25 23:15 - 23:30 0.25 23:30 - 00:00 0.50 11128!2005 00:00 - 01:00 01:00 - 01:45 01:45 - 03:15 ~ 03:15 - 03:45 1.00 0.75 1.50 DRILL PULD SURFAC DRILL TRIP SURFAC DRILL TRIP SURFAC DRILL ~ CIRC SURFAC DRILL TRIP 'SURFAC DRILL CIRC SURFAC DRILL TRIP SURFAC DRILL REAM SURFAC DRILL CIRC SURFAC DRILL ;DRLG !SURFAC DRILL I REAM I SURFAC DRILL I TRIP I SURFAC DRILL I TRIP I SURFAC DRILL I REAM I SURFAC DRILL I REAM I SURFAC DRILL TRIP SURFAC DRILL DRLG SURFAC 0.501 DRILL I TRIP I SURFAC 03:45 - 04:30 ! 0.75 i DRILL i TRIP I SURFAC Page 7 of 57 Spud Date: 11/21/2005 Start: 11/18/2005 End: 1/28!2006 Rig Release: 1/28/2006 Group: Rig Number: 15 Description of Operations rep w/drilling crew on handling BHA # 3. Install stab sleeve on 8" SperryDrill Lobe 415-5.3 stage motor (ser # 800440) w/ 1.15 deg bend ,torque bit #3 (13-1 /2" Smith MA89PX ser # JT1702), install 12" Welded blade stabilizer, crossover, Sperry Sun 8" Gamma//Res, 8" Sperry MWD and pulser, crossover float sub to 81'. Upload MWD/LWD tools. MU stand of 8" flex collars, jars and 11 jts Weatherford 5" HWDP f/ derrick to 554'. RIH w/ BHA #3 on Weatherford 5" dp f! 554' to 1472' then install Weathertord 13-1/2" ghost reamer, con't RIH to 2533'. Fill pipe, break circ. Test Sperry Sun MWD. Circ and condition mud while running 15-20 bph of H2O. Circ @ 613 gpm w/ 1780 psi. Blow down top drive. RIH w/ Weatherford 5" dp f! 2533' to 4434'. Circulate and condition mud and hole. Pump @ 630 gpm w/ 2150 psi. Adding water @ 15-20 bph. Blow down top drive and mud line. Trip in hole w/ BHA #3 w/ Weathertord 5" dp f/ 4434' to 6363'. Fill pipe. Precautionary ream last stand f/ 6268' to 6363'. No problems. Circulate and condition mud and hole while working string f/ 6268' to 6363'. Pumping 700 gpm w/ 2570 psi. Rotate @ 90 rpm w/ 12-19 ft/Ibs of torque. Directional drill 13-1 /2" hole w! Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 6370' to 6455' (3114' TVD) (83') ART .37 hrs AST 0.0 hrs., Total hrs on bit =.37 hrs., TotaV firs on jars = 136.03 hrs, 5-10 k WOB, 120 rpm's, 234-208 motor rpm, 850 gpm, 9.4 ppg mw, on bottom pressure 3800 psi, off bottom pressure 3620 psi, on bottom torque 15-19k ft/Ib, off bottom torque 12-18k ft/Ib, PU wt 200k, SO wt 100k, Rot wt 140k. Backream out of hole f/ 6455' to 6078' (5-10 fpm). Pumping 400 gpm #1 mud pump) w/ 1200 psi. Rotate 75 rpm w/ 15-19k torque. Working on pressure relief valve on # 2 mud pump. RIH f/ 6078' to 6370'. Try both pumps on hole. With 900 gpm pressure was 3985 psi and pressure relief valve of #2 mp opened. POOH f/ 6370' to 6078'. Will work on #2 mud pump pressure relief valve. Backream f/ 6078' to 5985' (5-10 fpm). Pumping 400 gpm w/ # 1 mp, 1200 gpm. Rotate 75 rpm, torque 15-19k ft/lb torque. Working on # 2 mud pump pressure relief valve. Backream f/ 5985' to 5887' (5-10 fpm). Pumping 400 gpm w/ # 1 mp, 1200 gpm. Rotate 75 rpm, torque 15-19k fUlb torque. Working on # 2 mud pump pressure relief valve. Trip in hole f/ 5887' to 6455'. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 6455' to 6562' (3149' TVD) (109') ART .54 hrs AST .11 hrs., Total hrs on bit =1.02 hrs., Total hrs on jars = 136.68 hrs, 5-10 k WOB, 120 rpm's, 234-208 motor rpm, 850 gpm, 9.4 ppg mw, on bottom pressure 3420 psi, off bottom pressure 3400 psi, on bottom torque 16-18k ft/1b, off bottom torque 16-18k ff/Ib, PU wt 200k, SO wt 90k, Rot wt 136k. Pump pressure spiked to 4952 psi on totco system, no PRV released the pressure. Will work on change out of #2 PRV. Pull out of hole f/ 6562' to 5887'. Put both pumps on line. 838 gpm off bottom w/ 3170 psi. RIH f/ 5887' to Printed: 216/2006 4:03:41 PM CanocoPhillips Alaska Page s of 57 Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11!18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 11/28!2005 From - To 'Hours ~' Code Sub phase Code 03:45 - 04:30 0.75 DRILL TRIP SURFAC 04:30 - 06:00 1.50 DRILL DRLG SURFAC 06:00 - 11:15 I 5.251 DRILL I DRLG I SURFAC 11:15 - 13:15 2.00 13:15 - 13:30. 0.25 13:30 - 18:00 I 4.50 11/29/2005 i 00:00 - 00:15 00:15 - 01:00 01:00 - 04:00 104:00 - 05:15 0.25 0.75 3.00 18:00 - 00:00 6.00 DRILL DRLG SURFAC DRILL REAM SURFAC DRILL TRIP SURFAC DRILL ~ DRLG SURFAC DRILL DRLG ~ SURFAC i DRILL i REAM .SURFAC DRILL I REAM I SURFAC 1.251 DRILL iTRIP SURFAC Description of-Operations 6562' Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f! 6562' to 6579' (3152' TVD} (17') ART .05 hrs AST .18 hrs., Total hrs on bit =1.25 hrs., Totaf hrs on jars = 136.91 hrs, 5-10 k WOB, 120 rpm's, 221 motor rpm, 850 gpm, 9.4 ppg mw, on bottom pressure 3380 psi, off bottom pressure 3400 psi, on bottom torque 18k ft/Ib, off bottom torque 18k fUlb, PU wt 200k, SO wt 100k, Rot wt 140k. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f! 6579' to 7123' (3311' TVD) (544') ART 2.13 hrs AST 1.5 hrs., Total hrs on bit =4.88 hrs., Total hrs on jars = 140.53 hrs, 2-10 k WOB, 120 rpm's, 214-221 motor rpm, 824-850 gpm, 9.4 ppg mw, on bottom pressure 3450-3250 psi, off bottom pressure 3362-3150 psi, on bottom torque 20-16k ftllb, off bottom torque 20-16k ft/Ib, PU wt 200-190k, SO wt 108-102k, Rot wt 140k. Note: Avg background gas 110 units, max gas 290 units ~ 0930 hrs while drilling @ 6935'. Backream while change out liner gasket #1 mp. Backream 3-5 fpm f/ 7123' to 6933'. Rotate 75 rpm w! 14k ft Ib torque. Pumping w/ #2 mud pump 426 gpm w/ 1210 psi. RIH f/ 6933' to 7123'. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 7123' to 7618' (3311' TVD) (495') ART 2.63 hrs AST .17 hrs., Total hrs on bit =7.68 hrs., Total hrs on jars = 143.34 hrs, 5-10 k WOB, 120 rpm's, 221-215 motor rpm, 850-826 gpm, 9.4 ppg mw, on bottom pressure 3450-3310 psi, off bottom pressure 3360-3325 psi, on bottom torque 15-17k ft/Ib, off bottom torque 13-17k ft/Ib, PU wt 200-210k, SO wt 100-105k, Rot wt 140-142k. Note: Avg background des 100 units, max gas 194 ~ t530 hrs while drilling @ 7325'. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 7618' to 8067' (3640' TVD) (449') ART 1.54 hrs AST 1.56 hrs., Total hrs on bit =10.78 hrs., Total hrs on jars = 146.44 hrs, 2-10 k WOB, 120 rpm's, 216-218 motor rpm, 830-840 gpm, 9.4 ppg mw, on bottom pressure 3420-3500 psi, off bottom pressure 3340-3400 psi, on bottom torque 15-18k ft/Ib, off bottom torque 13-18k ft/Ib, PU wt 205-210k, SO wt 105k, Rot wt 142-145k. Note: avg baccgrourat gas 1 f0 units, max gas 172 units ~ 2245 hrs while drilling @ 7960' Directional drill 13-1/2" hole w! Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 8067' to 8073' (3643' TVD) (6') ART 0.0 hrs AST .05 hrs., Total hrs on bit =10.83 hrs., Total hrs on jars = 146.49 hrs, 2-10 k WOB, 0 rpm's, 216 motor rpm, 833 gpm, 9.4 ppg mw, on bottom pressure 3500 psi, off bottom pressure 3405 psi, on bottom torque 16-18k ft/Ib, off bottom torque 15-18k ft/Ib, PU wt 200k, SO wt 105k, Rot wt 145k. Note: Avg t~dcground gas 30 units, max gas 50 units. While change out PRV on # 1 mud pump and Gean suction screens --Backream 5-10 fpm f/ 8073' to 7885'. Rotate 75 rpm w/ 12-17k tt Ib torque. Pumping w/ #2 mud pump 428 gpm w/ 1360 psi. Note: Avg background gas 30 units, max gas 56 units. Backream 30 fpm f/ 7885' to 6744'. Rotate 75 rpm wl 14-15k ff Ib torque. Pumping w/ #2 & # 1 mud pump 832 gpm w/ 3400 psi. Note: Avg background gas 45 units, max gas 89 units. Trip in hole, record PU & SP wts every 5 stands. Wash last stand down Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-20 1 C-20 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Date' From'- To 'Hours ' Code ! Sub Phase 'Code 11/29/2005 04:00 - 05:15 1.25 DRILL 'TRIP SURFAC 05:15 - 06:00 0.75 i DRILL DRLG SURFAC 06:00 - 11:45 5 75 DR1LL DRLG SURFAC . . i i 11:45 - 14:15 2.50. I RIGMNT RGRP SURFAC I i 14:15 - 18:00 3.75 ~ DRILL DRLG i SURFAC 18:00 - 19:00 1.00 DRILL ,DRLG SURFAC , 'i 19:00 - 19:45 0.751 ' j DRILL ' OTHR ~ SURFAC 19:45 - 20:00 I 0.25 DRILL .DRLG i i SURFAC I 20:00 - 00:00 ~ 4.00 DRILL ! CIRC; SURFAC Start: 11 /18/2005 Rig Release: 1/28/2006 Rig Number: 15 Page 9 of 57 Spud Date: 11!21/2005 End: 1 /28/2006 Group: Description of Operations to 8073'. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 8073' to 8092' (3651' TVD) (19) ART 0.0 hrs AST .31 hrs., Total hrs on bit =11.14 hrs., Total hrs on jars = 146.8 hrs, 10 k WOB, rpm's, 208-187 motor rpm, 800-720 gpm, 9.5ppg mw, on bottom pressure 3400-2800 psi, off bottom pressure 3350-2700 psi, on bottom torque --k fUlb, off bottom torque 15-18k ft/Ib, PU wt 220k, SO wt 100k, Rot wt 145k. Note: Avg background gas 80 units, max gas 99 units. Directional drill 13-1 /2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 8092' to 8452' (3749' TVD) (360') ART .91 hrs AST 1.99 hrs., Total hrs on bit =14.04 hrs., Total hrs on jars = 149.7 hrs, 2-15 k WOB, 0-120 rpm's, 185-208 motor rpm, 710-800 gpm, 9.4 ppg mw, on bottom pressure 2800-3440 psi, off bottom pressure 2700-3200 psi, on bottom torque 16-21 k fUlb, off bottom torque 15-18k ft/Ib, PU wt 210-225k, SO wt 100-108k, Rot wt 145-150k. Avg background gas 100 units, max gas 155 units @ 1130 hrs while drilling @ 8440'. Repair #1 mud pump. Replace liner wear plate. Circ and work pipe. Circ w! # 2 mud pump @ 422 gpm wJ 1400 psi. Note: Avg background gas 90 units, max gas 113 units. Directional drill 13-112" hole w! Sperrydrill 4/5-5.3 stage mtr wl 1.15 deg bend f/ 8452' to 8834' (3749' TVD) (360') ART 1.63 hrs AST .87 hrs., Total hrs on bit =16.54 hrs., Total hrs on jars = 152.2 hrs, 5-12 k WOB, 120 rpm's, 209-205 motor rpm, 804-790 gpm, 9.4 ppg mw, on bottom pressure 3440-3620 psi, off bottom pressure 3200-3400 psi, on bottom torque 16-18k ft/Ib, off bottom torque 13-18k ft/Ib, PU wt 225-220k, SO wt 108-112k, Rot wt 150k. Note: avg background gas 120 units, max gas 168 units @ while drilling @ 8675'. Directional drill 13-1/2" hole w! Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f! 8834' to 8928' (3877' TVD) (94') ART .53 hrs AST 0.0 hrs., Total hrs on bit =17.07 hrs., Total hrs on jars = 152.73 hrs, 10-12 k WOB, 120 rpm's, 208 motor rpm, 800 gpm, 9.4 ppg mw, on bottom pressure 3700 psi, off bottom pressure 3480 psi, on bottom torque 19k fUlb, off bottom torque 14-19k ft/Ib, PU wt 210k, SO wt 112k, Rot wt 150k. Note: avg background gas 100 units, max gas 162 units @ 1815 hrs w/ drilling @ 8845'. Ghange out pressure relief valve on #2 mud pump. Clean suction screen. Circ and work pipe. Circ w/ # 1 mud pump @ 422 gpm w/ 1400 psi. Note: avg background gas 60 units, max gas 103 units. Directional drill 13-1/2" hole w/Sperrydrill 4/5-5.3 stage mtr w! 1.15 deg bend f/ 8928' to 8985' (3894' TVD) (57') ART .31 hrs AST 0.0 hrs., Total hrs on bit =17.38 hrs., Total hrs on jars = 153.04 hrs, 10-12 k WOB, 120 rpm's, 208 motor rpm, 800 gpm, 9.4 ppg mw, on bottom pressure 3700 psi, off bottom pressure 3480 psi, on bottom torque 19k fUlb, off bottom torque 14-19k ft/Ib, PU wt 210k, SO wt 112k, Rot wt 150k. Note: Avg background gas 90 units, max gas 114 units @ 1945 hrs while drilling @ 8960' Circ and condition mud and hole @ 8985' (3894' TVD). Increase mud Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Page 10 of 57 Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date -From - To Hours ~ Code ''Sub Phase Code 11!29/2005 120:00 - 00:00 11/30/2005 100:00-01:30 01:30 - 02:00 02:00 - 06:00 06:00 - 11:00 11:00 - 13:00 13:00 - 18:00 18:00 - 00:00 4.00 DRILL ~ i CIRC I SURFAC 1.50 ~ DRILL CIRC i SURFAC 0.50 DRILL TRIP SURFAC 4.00; DRILL i DRLG SURFAC 5.00 DRILL ~ DRLG SURFAC i 2.00 RIGMNT RSRV SURFAC 5.00 DRILL i 'DRLG SURFAC 6.00; DRILL DRLG ~ SURFAC 12/1/2005 100:00 - 04:15 I 4.251 DRILL i DRLG ISURFAC Description of Operations weight f/ 9.5 ppg to 10.00 ppg. Circ @ 800 gpm w/ 3500 psi. Rotate @ 100 rpm w/ 16-17k ft Ib torque. Backreaming @ 2-3 fpm, setting back a stand every hr f! 8985' to 8710' @ midnight. Note: avg background gas 40 units, max gas 97 units. Continue to Circ and condition mud and hole @ 8985' (3894' TVD). Increase mud weight f/ 9.9 ppg to 10.00 ppg. Circ @ 800 gpm w/ 3500 psi. Rotate @ 100 rpm w/ 16-17k ft Ib torque. Backreaming @ 2-3 fpm, setting back a stand every hr f! 8710' to 8580'. Note: avg background gas 40-45 units, max gas 67 units. Trip in hole f/ 8580' to 8895'. Made up top drive and precautionary ream +/-60' f/ 8836' to 8895. Grease Swivel packing. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 8895' to 9292' (3989' TVD) (397') ART 1.09 hrs AST 1.45 hrs., Total hrs on bit =19.92 hrs., Total hrs on jars = 155.58 hrs, 4-12 k WOB, 120 rpm's, 208 motor rpm, 800 gpm, 10.0 ppg mw, on bottom pressure 3850-3620 psi, off bottom pressure 3400-3650 psi, on bottom torque 16-19k ft/Ib, off bottom torque 13-19k ft/Ib, PU wt 220-210k, SO wt 110-118k, Rot wt 150-152k. Note: avg background gas 40-45 units, max gas 142 units @ 0230 hrs while drilling @ 9035'. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 9292' to 9847' (4166' TVD) (555') ART 2.88 hrs AST .31 hrs., Total hrs on bit =23.11 hrs., Total hrs on jars = 158.77hrs, 12-16 k WOB, 120 rpm's, 208-204 motor rpm, 800-784 gpm, 10.0 ppg mw, on bottom pressure 3860-3890 psi, off bottom pressure 3650-3680 psi, on bottom torque 17-20k ft/Ib, off bottom torque 14-16k ft/Ib, PU wt 215-230k, SO wt 118k, Rot wt 152-158k. Note: avg background gas 40 units, max gas 97 units @ 1045 am while drilling @ 9820'. Prepare to change washpipe on top drive. POOH f/ 9847' to 9780'. Repair wash pipe packing while circulating with head pin @ 220 gpm w/ 780 psi. Work pipe every 10 minutes. RIH f! 9780' to 9847'. Directional drill 13-1 /2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 9847' to 10333' (4326' TVD) (486') ART 2.80 hrs AST .67 hrs., Total hrs on bit =26.58 hrs., Total hrs on jars = 162.24hrs, 5-15 k WOB, 120 rpm's, 203-192 motor rpm, 780-740 gpm, 10.0 ppg mw, on bottom pressure 3885-3700 psi, off bottom pressure 3680-3520 psi, on bottom torque 17-21 k ft/Ib, off bottom torque 14-18k ft/Ib, PU wt 230-240k, SO wt 118k, Rot wt 158-162k. Note: avg background gas 50 units, max gas 62 units @ 1245 hrs. Directional drill 13-1/2" hole w/ Sperrydrill 4l5-5.3 stage mtr w/ 1.15 deg bend f/ 10333' to 10804' (4473 TVD) (471') ART 2.64 hrs AST .74 hrs., Total hrs on bit =29.96 hrs., Total hrs on jars = 165.62 hrs, 8-18 k WOB, 120 rpm's, 195-190 motor rpm, 750-733- gpm, 10.1 ppg mw, on bottom pressure 3700-3900 psi, off bottom pressure 3520-3700 psi, on bottom torque 18-24k ft/Ib, off bottom torque 19-22k ft/Ib, PU wt 240-250k, SO wt 118-120k, Rot wt 162-k. Note: avg background gas 100 units, max gas 189 units while drilling @ 10640' @ 2230 hrs. Directional drill 13-1/2" hole w/ Sperrydrill 4/5-5.3 stage mtr w/ 1.15 deg bend f/ 10804' to 11130' (4574 TVD) (326') ART 2.36 hrs AST .2 hrs., Total hrs on bit =32.52 hrs., Total hrs on jars = 168.18 hrs, 12-16 k WOB, 120 rpm's, 190 motor rpm, 733-729- gpm, 10.2 ppg mw, on Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Nours i Code ~ Code Phase 12/1/2005 ~ 00:00 - 04:15 I 4.25 ~ DRILL ~~ DRLG {SURFAC 04:15 - 04:45 '; 0.501 DRILL CIRC ~ SURFAC 12!212005 04:45 - 06:00 1.251 DRILL I REAM SURFAC 06:00 - 09:45 ~ 3.75! DRILL 1 REAM SURFAC 09:45 -10:45 1.00 DRILL REAM SURFAC 10:45 - 14:30 3.75 ~ DRILL ~ WIPR SURFAC 14:30 - 16:30 2.00 DRILL WIPR SURFAC 16:30 - 18:00 ~ 1.50 DRILL OTHR SURFAC 18:00 - 20:45 ~ 2.75 DRILL WIPR SURFAC 20:45 - 21:00 0.25 DRILL CIRC SURFAC 21:00 - 23:00: 2.00 DRILL CIRC i SURFAC 23:00 - 00:00 I 1.00 RIGMNT i RGRP ~ SURFAC 00:00 - 00:45: 0.75 DRILL CIRC SURFAC 00:45 - 06:00 i 1 5.25 i DRILL CIRC SURFAC 06:00 - 10:30 4.50 DRILL I CIRC SURFAC 10:30 - 11:00 i 0.50 DRILL OTHR SURFAC 11:00 - 16:00 5.00 DRILL ' TRIP SURFAC 16:00 - 18:00 2.00 DRILL REAM SURFAC 18:00 - 19:00 I 1.00 ~ DRILL ~ REAM ;SURFAC 19:00 -19:30 0.501 DRILL OTHR ~~ SURFAC 19:30 - 20:00 0.50 DRILL TRIP I SURFAC 20:00 - 21:15 1.25 RIGMNT RGRP SURFAC 21:15 - 22:15 ' 1.00; DRILL TRIP j SURFAC 22:15 - 00:00 I 1.75 I DRILL I REAM I SURFAC Page 11 of 57 Spud Date: 11/21/2005 Start: 11/18/2005 End: 1/28/2006 Rig Release: 1128!2006 Group: Rig Number: 15 Description of Operations bottom pressure 3900-3950 psi, off bottom pressure 3700-3660 psi, on bottom torque 21-24k ft/Ib, off bottom torque 21-24k ft/Ib, PU wt 250-260k, SO wt 120-122k, Rot wt 162-165k. Note: Avg background gas 100 units, max gas 169 units while drilling @ 10830' @ 0015 hrs. Survey, UD single 5" drill pipe, circ cuttings past ghost reamer. (Ghost reamer 1473' behind bit) Backream @ 20-25 fpm f/ 11121' to 10740'. Rotate @ 120 rpm w/ 22k ft Ib torque. Circ @ max rate on bottom of 700 gpm w/ 3300 psi. Backream @ 15-20 fpm f/ 10740' to 9470'. Rotate @ 120 rpm w/ 20-23k ft Ib torque. Circ @ 715 gpm w/ 3400 psi. Backream @ 5 fpm f/ 9470' to 9290'. Rotate @ 120 rpm w/ 20-21k ft Ib torque. Circ @ 740 gpm w/ 3400 psi. PU wt 225k, SO wt 115k. POOH on elevators f/ 9290' to 6355'. Tight @ 8330', 6830' and 6650'. Pulled 30-40k. Work through two times. PU wt @ 6355' is 195k, SO wt is 95k. RIH f/ 6355' to 8355'. Fill pipe @ 8355'. Recover stripping rubbers from riser. POOH f/ 8355' to 8170'. Trip in hole f/ 8170' to 11025'. Record PU & SO wt's wevery 5 stands. MU top drive, fill pipe, wash down to 11121'. PU single 5" dp. Circ and condition mud and hole f/ 10-3/4" surf casing. Recip f/ 11130' to 11055'. 120 rpm w/ 22k ft/Ib torque. Stage pumps up f/ 300 gpm to 675 gpm wJ 3600 psi @ 675 gpm. Note: Temperature -27 deg, 17 mph winds, WC -55 deg. Top drive acting up. Repair # 2 mud pump, # 3 cylinder. Liner gasket leaking. Circ w/ # 1 mp @ 99 spm (418 gpm) w/ 1475 psi while rotating 120 rpm w/ 24k torque and working string. Repair # 2 mud pump, # 3 cylinder. Liner gasket leaking. Circ w/ # 1 mp @ 100 spm (418 gpm) w/ 1500 psi while rotating 120 rpm w/ 24k torque and working string f/ 11028' to 10930'. Note: Top drive still acting up .Temp -27, WC -55 deg. Circ and condtion mud and hole f/ casing. Stand back a stand every hour from 10930' to 10645'. Pumping 718 gpm w! 3400 psi. Rotating 120 rpm w/ 20-28k ft Ib torque. Circ and condtion mud and hole f/ casing. Stand back a stand every hour from 10930' to 10645'. Pumping 750 gpm w/ 3200 psi. Rotating 120 rpm w/ 21-25k ft Ib torque.Note: Mud properties going in are: 9.95 ppg wt, vis 68, PV 24, YP 25, 10 sec gel 11, 10 min gel 30. Monitor well, pump dry job, blow down top drive. POOH f/ 10260' to 4130'. Tight @ 4260'-4230', and 4154' to 4130'. Backream out f/ 4170' to 3860'. Work each stand without pumps, then stand back. PU wt 175k, SO wt 100k. Pumping 750 gpm w/ 2000 psi. Rotating 120 rpm w/ 11-18k ft Ib torque. Backream out f! 3860' to 3794'. Work each stand without pumps, then stand back. PU wt 175k, SO wt 100k. Pumping 750 gpm w/ 2000 psi. Rotating 120 rpm w/ 11-18k ft Ib torque. Pump dry job. Blow down top drive. POOH from 3794' to 3033'. Drawworks low drum chain broke. Remove chain f/ drawworks. POOH from 3033' to 2090'. Pull 50k over @ 2090'. Normal PU wt was 132k. Backream @ 5 fpm f/ 2177' to 2082'. Pumping 595 gpm w/ 1190 psi. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 12 of 57 operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C -20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D1 5CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 .Date From - To i Hours Code Sub j Phase 'Code Description.. of Operations 12/2/2005 22:15 - 00:00 1.75 ~ DRILL REAM SURFAC Rotating 120 rpm w/ 7-8k ft Ib torque. 12/3/2005 ' 00:00 - 03:15 3.25 DRILL REAM , SURFAC Backream @ 5 fpm f/ 2082' to 1701. Pumping 586 gpm w/ 1100 psi. Rotating 120 rpm w! 5-6k ft Ib torque. 03:15 - 03:30 0.25 DRILL WIPR SURFAC Trip in hole f/ 1701' to 2272'. 103:30 - 05:15 I 1.75 DRILL WIPR SURFAC ;POOH f/ 2272' to 1701', OK. Continue pulling to 1472', UD ghost i reamer (1/4" underguage and a 4" chunk missing on side of one blade). i . MU single and pulling up to 20k over. 05:15 - 06:00 0.75 DRILL ' REAM SURFAC Backream @ 15 fpm f/ 1410' to 1029. Pumping 535 gpm w/ 900 psi. .Rotating 100 rpm w/ 5-6k ft Ib torque. PU wt 125k, SO wt 100k, Rot wt 110k. 06:00 - 07:45 i 1.751 DRILL REAM SURFAC Backream @ 15 fpm f/ 1029' to 650'. Pumping 460 gpm w/ 900 psi. Rotating 100 rpm w/ 4-5k ft Ib torque. PU wt 108k, SO wt 108k, Rot wt 110k. 07:45 - 08:00. 0.25, DRILL TRIP SURFAC POOH two stands, blow down top drive. 08:00 - 08:30 0.50 DRILL . TRIP ; SURFAC 'POOH, stand back HWDP and 8" flex collars. 1 08:30 - 09:30 , 1.00 DRILL PULD SURFAC POOH, drain motor, break bit, UD BHA #3. ~ 'Note: calc fill 88.65 bbls, actual fill 125.3 bbls. Ran de sitter while : ~ 09:30 - 10:30 1.00 DRILL OTHR ~ SURFAC POOH, Ran 30 bbls !hr water while Circ. Clear and clean rig floor. Blow down mud pumps. 10:30 - 11:00 0.50 CASE RURD SURFAC PU casing tools to rig floor. 11:00 - 13:00 I 2.00 RIGMN T RSRV SURFAC Slip and cut 176' of 1-3/8"drilling line. Adjust brakes on drawworks. 13:00 - 13:30 I ' 0.50 ~ DRILL OTHR SURFAC .Monitor well on trip tank. Move stand of 8" flex collars and HWDP in derrick. 13:30 - 15:00 ' 1.50 CASE OTHR SURFAC !Drain riser. MU FMC hanger to landing joint. Dummy run hanger to load shoulder. Stand back hanger on off driller side of floor. 15:00 - 17:30 ' 2.50 CASE .RURD SURFAC RU to run 10-3/4" 45.5 ppf L-80 BTC casing. 17:30 - 18:00: 0.50 , CASE SFTY i SURFAC PJSM on running 10-3/4" 45.5 ppf L-80 BTC casing w/ Doyon driller KW i ~ I ~ ''Jones and his crew. 18:00 - 18:30 , 0.50 1 CASE SFTY SURFAC PU first jt of casing. ' 18:30 - 19:00 0.50 , CASE ' SFTY SURFAC PJSM on running 10-3/4" 45.5 ppf L-80 BTC casing w/ Doyon driller 19:00 - 19:45 I 0.75 ~ RIGMNT RGRP SURFAC "Eric" John Rodland and his crew. 'Repair stabbing board , . 19:45 - 00:00 4.25 CASE RUNC SURFAC Run 10-3/4" 45.5 ppf L-80 BTC casing: Weatherford mode1303 float ii ~ shoe, 3 joints of casing Weatherford Float collar, then 62 more joints. I , Total of 65 joints in hole @ midnight, to depth of 2633'. PU wt 200k, SO wt 115k @ 2633'. Installed bowspring centralizer over stop collar 10' above shoe, then over collars of jt # 1 and #2, then a stop 10' above float collar with centralizer over it as well, then on collar of jt #4. Total of 5 centralizers. Then installed 5 centralizers on jts # 50, # 51, # 52, # 53, and # 54. Total of 5 more centralizers. Baker locked u too and P 12/4/2005 00:00 - 00:15. 0.25 CASE RUNC SURFAC including pin of jt # 5. Run 10-3/4" 45.5 ppf L-80 BTC casing f/ 2633' to 2839'. ' 00:15 - 01:45 ~i 1.50 CASE CIRC SURFAC I Circ and condition mud and hole @ 2839'. Recip pipe. Stage pumps up f/ 3 bpm 240 psi, 5 bpm w/ 240psi, 7 bpm w/ 385 psi, 8 bpm w/ 470 psi. ' ~ Circ 542 total bbls. ' ' ' ' 01:45 - 06:00 4.25 CASE , RUNC SURFAC Circ casing down 7 bpm w/ 360 psi f/ 3030 to 3084 , 3165 to 3206 , i i 3287 to 3530', 3892' to 3933'. Run joint 101 in hole to 4100'. PU wt ~ 250k, SO wt 110k. Total of 101 joints in hole. Note: Calc displacement 70 bbts, actual displacement 24 bbls. 06:00 - 06:30 j 0.50 CASE ' CIRC SURFAC 'Circ casing while reciprocate @ crew change @ 4100- 4130', 7 bpm w! 355 psi. 06:30 - 12:00 j 5.50 CASE RUNC SURFAC • Run 10-3/4" 45.5 ppf L-80 BTC casing f/ 4130' to 6100'. PU wt 380 k, i SO wt 100k. Cric bottoms up @ 5680' (290 gpm, 7bpm), w/ 420 psi. Printed: 2/16!2006 4:03:41 PM ConocoPhillips Alaska Page 13 of 57 -Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date ~ From - To ~ Hours ' Code Sub Phase Description of Operations !Code 12/4/2005 ~ 06:30 - 12:00 ~ 5.50 CASE ~ RUNC SURFAC Total calc displacement 147 bbls, actual 80 bbls. ,12:00 - 18:00 6.00 ;CASE ~ RUNC .SURFAC Run 10-3/4" 45.5 ppf L-80 BTC f/ 6100' to 8660'. PU wt 460k, SO wt 18:00 - 19:15 1.25 CASE 19:15 - 20:30 ' 1.25 CASE 20:30 - 22:00 1.50 CASE 22:00 - 23:15 '; 1.25 ~ CASE 23:15 - 00:00 ' 0.75 CASE 12/5/2005 00:00 - 00:15 0.25. CASE 00:15 - 01:30 1.25 CASE 01:30 - 02:45 ~ 1.25 : CASE 02:45 - 03:00 ~ 0.25 ~ CASE 03:00 - 03:15 0.25 ~ CASE I 03:15 - 03:30 I 0.25 CASE 03:30 - 03:45 ~ 0.25 CASE 03:45 - 04:00 i 0.25 CASE 04:00 - 04:15 ~ 0.25 i CASE 04:15 - 04:45 ' 0.50 04:45 - 10:30 '~ I 5.75 I 10:30 - 11:00 ~ 0.50 11:00 - 14:00 ~ 3.00 14:00 - 17:00 3.00 115k, Blocks and elevators 75k. Circ bottoms up @ 7450' w/ 7 bpm 480 psi. Circ bottoms up @ 8660' 7 bpm w/ 480 psi. CIRC SURFAC Circ and condition mud @ 8627 to 8667. CBU @ 7 bpm w/ 480 psi. 'Circ 561 bbls. RUNC SURFAC RIH 10-3/4" casing 45.5 ppf L-80 BTC f/ 8667' to 9274'. CIRC SURFAC I Circ and condition mud @ 9274' to 9316'. CBU @ 7 bpm w/ 480 psi. Circ 550 bbls. PU wt 520k to break free, circ w/ pumps 490k initial then to 400k. Down wt 110k before circ, 130k after circ. RUNC SURFAC RIH 10-3/4" casing 45.5 ppf L-80 BTC f/ 9316' to 10118'. Jt # 251 in ,hole. CIRC SURFAC Circ and condition mud @ 10076'- 10118'. Circ 7 bpm w/ 500 psi initial pressure, final pressure 440 psi.. Circ total of 418 bbls. PU wt while circ 580-590k to break free, then when pumping 460k. When through pumping, PU wt 420 while pumping. Down wt prior to pumping 115k, after circ 140k. CIRC ; SURFAC ,Circ and condition mud @ 10118'- 10118'. Circ 7 bpm w/ 500 psi initial pressure, final pressure 440 psi.. Circ total of 418 bbls. PU wt while circ 580-590k to break free, then when pumping 460k. When through pumping, PU wt 420 while pumping. Down wt prior to pumping 115k, t after circ 140k. RUNC SURFAC MU TAM port collar after joint 251. Installed a centralizer in middle of !joint over stop ring on jt # 251 and #252. Ran casing f/ 10118' to 10828'. CIRC SURFAC Circ and condition mud @ 10828' to 10868'. Circ 7 bpm w/ 540 psi initial pressure 450 psi final. Circ total of 460 bbls. While circ, 640k to break free up, 520k after pumping 250 bbl, final PU while pumping 450k. Down wt 115 prior to pumping, 135k while pumping, after circ SO ~ ; wt 145-160k. RUNC SURFAC Run casing f/ 10868' 11031'. SO wt 130k. CIRC SURFAC Circ and txmditiw~ mud f/ 11031' to 110'7?'.Pumping 7 bpm w/ 420 psi. Circ down w/ 130k-140k SO wt. While pumping, 590-600k to break free up, then 480k PU wt while pumping. Casing shoe @ 11113' OTHR SURFAC IUD Frank's fillup tool. OTHR SURFAC ~ Blow down top drive. OTHR SURFAC PU FMC Hanger and landing joint. RUNC SURFAC Check torque on left hand thread on top of FMC hanger. RIH and land (casing @ 0415 hrs w/ 145k-160k down wt. Tri~f tQ WU cin~siring. While picking up @ about 450k PU wt, rapid overpull with 3.2' above ~ landed position. Theory of txtliar rx9 cx+nducior shoe. PULD ( SURFAC MU Dowell cement head. CIRC , SURFAC Circ @ 7 bpm w/ 350 psi. Increase to 8 bpm w/ 300 psi after and hour i of circ time. After 2 more hrs increase rate to 9 bpm w/ 340 psi. Total strokes 28675 = 2888 bbls. Total of 4 bottoms up circulated. SFTY SURFAC PJSM w/ rig team on 10-3/4" surface cement job. CO Rep, mud engr, APC drivers and pusher, Dowell, and Doyon 15 Rig crew. PUMP SURFAC Dowell pump 5 bbls CW 100, test lines to 3500 psi, follow w/ 45 bbls ,more CW100, 50 bbls mudPush 10.5 ppg w! red dye, drop bottom plug, pump 1069 bbls lead @ 10.7 ppg, follow w/ 278 bbls tail @ 12.5 ppg, !~ drop top plug, follow w/ ZO bbls water. DISP SURFAC I Displace cement w/ rig pumps w! 10 ppg mud. Displace @ 8 bpm. ;Initial pressure 645 psi. Final circ presssure 1200 psi. Max circ pressure Printed: 2!16/2006 4:03:41 PM ConocoPhiNips Alaska Operations Summary Report Page 14 of 57 Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 'Date From - To ' Hours Code ' C ~ ~~ Phase 1215!2005 ~ 14:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:15 20:15 - 22:15 22:15 - 22:30 22:30 - 00:00 12/6/2005 00:00 - 00:30 00:30 - 02:15 02:15 - 02:45 02:45 - 04:00 04:00 - 04:15 04:15 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 11:30 11:30- 12:00 12:00 - 16:00 _ oe 3.001 CEMENl~DISPSURFAC 1.00, CASE RURD SURFAC 1.00 CASE I RURD I SURFAC 1.25' CASE RURD I SURFAC 2.001 CEMEN TRIP SURFAC 0.251 CEMENTOTHR (SURFAC 1.50 CEMENT~CIRC SURFAC 0.50~CEMENI~CIRC [SURFAC 1.751 CEMEN7CIRC SURFAC 0.50 ~ CEMEN SFTY SURFAC 1.251 CEMEN ,TOPJ SURFAC 0.25CEMEN7~PULD (SURFAC 0.751 CEMENl~CIRC (SURFAC 0.50 CEMEN7~PULD SURFAC 0.50 CEMEN TRIP SURFAC 0.50 ~ CEMENl}TRIP ,SURFAC 1.00 CEMENl~RURD (SURFAC 1.50; RIGMNTILRSRV SURFAC 2.50 CEMENI~PCLR SURFAC ~i 0.50: CEMENTPULD SURFAC 4.00 ~ CEMENl~CIRC ;SURFAC 16:00 - 17:00 1.00 CEMEN CIRC I SURFAC 17:00 - 17:45 0.75 CEMEN ~ PCLR ~ SURFAC Description of Operations 1910 psi. Lost re#urna @ 8720 strokes 878 bbls displacement pumped. 1550 psi @ 315 gpm. Bumped plug @ 10350 strokes w/ 1700 psi. Hold pressure f/ 10 min. Bleed off pressure, check floats, OK. CIP @ 1615 hrs 12/4/2005. Rig down cement head and casing elevators. Back out FMC landing joint. Break pup on top of landing joint. Run in landing joint. MU left hand acme thread to hanger. Back out upper pup joint. Remove casing tools f/ rig floor. Change bales on top drive. PU~1lJ T1lrx# pmt i~Na- shifting tool. Trip in hole to 992'. MU surface lines. Locate profile of TAM port collar. 2.5' up on 10' pup joint. Test lines to 3000 psi. Bleed off pressure. Pressure string to 1000 psi, bleed down to 400 psi. Slack off and open port collar, watching pressure. Circ @ 2bpm/ 380 psi for total of 14 bbls to fill riser and get returns down flow line. Stage up to 2.5 bpm w/ 420 psi w/ 17% flow line returns. @ 58 bbls pumped increase rate to 3 bpm w/ 410 psi- flow line returns dropped to 8%. At 810 strokes(81.6 bbls pumped, zerp.~arlir~deturns on Totco. Small amount actual. Drop rate to 2bpm @ 850 strokes/ 450 psi, no Totco flow, very little actual. At 1164 strokes (117 bbls pumped, 2 bpm 350 psi, open 4" valves in cellar w/ little returns. Try 2.5 bpm @ 1480 strokes (150 bbls pumped), 390 psi, small amount of returns in cellar. Pump @ 1 bpm @ 1600 strokes (161 bbls pumped), 290 psi with small amount of returns. Of the first 183 ! ,130 btu vrere circulated atui i03 ttiMs were not returned-to surFace. Of the first 183 bbls pumped, 80 bbls were circulated and 103 bbls were not returned to surface. Continue trying to circ. Pump @ 2bpm w/ 290 psi, no returns. Slow to 1 bpm 250 psi @ 196 bbls pumped, no returns. Pump 1 bpm w/ 250 psi @ 2000 strokes pumped. (201 bbls). Pump 1 -2 barrel every 5 minutes waiting on orders. Held pre-job safety meeting for cement job. Pump 5 bbl's water and test lines to 3000 psi. Pump 100bb1's 10.7 ppg ASL cement.:pump 1 bbl water and displave to tam-port with 17.3 bbl's mud. @ 2bpm 280 pee. vim ne returns. Pick up to 108,000# close ports test to 1300 psi and check for flow back. None. Turn to right to unlatch & shear choke valve @ 2386 psi. Circulate @ 8 bpm 350 psi ans increase to 11 bpm = 790 psi. 287 total barrels pumped. Rig down cementing equipment. POOH with drill pipe standing back in derrick from 992' Break port shifting tool on rig floor, service choke sub and stand back in derrick. Clear rig floor of cementing equipment and tools. Service top drive and crown. Make up choke sub and tam-port collar shifting tool. RIH 10 stands + 1 single with 10' pup. M/U circulating"T' , TIW valve on single and cement hoses. Pick up 314" and RiG through fluted hanger to 245 feet. Make up pump in sub in 3/4" pipe. (weld on) Pump through 3/4" pipe at 245 feet .75 bpm = 190 psi, with mud. Pump through 314" line @ 245 feet with water @ 1 bpm = 250 psi. Rig up cement hose to drill pipe and drop 2" ball to fuction port tool. Up weight = 90,000# Down weight = 90,000# Printed: 2!16!2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report. Legal Well Name: 1C-20 Common Well Name: 1C-20 Event Name: ROT -DRILLING Contractor Name: D15CMr7a conocophillips.com Rig Name: Doyon 15 Date -From - To I Hours 'Code ' Sub ~ Phase 'Code, 12/6/2005 17:00 - 17:45 ~ 0.75 ~ CEMENlj PCLR ~ SURFAC 17:45 - 18:15 I, 0.50 18:15 - 20:30 ~ 2.25 i 20:30 - 00:00 ~ 3.50 12/7/2005 i 00:00 - 05:00 5.00 CIRC SURFAC CIRC SURFAC CIRC (SURFAC CIRC !SURFAC 05:00 - 05:30 0.50 CEMENl(SFTY 05:30 - 06:45 j 1.251 CEMENl~ PCLR 06:45 - 07:15 0.50 CEMEN7~PCLR 07:15 - 08:00 0.75 !CEMEN PULD 08:00 - 08:30 I 0.501 CEMEN PULD 08:30 - 09:30 j I 1.001 CEMENl ~SEQT 09:30 - 10:00 0.50 CEMEN RURD 10:00 - 11:30 1.50 CEMEN PCLR 11:30 - 12:00 0.50 WELCT NUND 12:00 - 12:30 ~ 0.50 WELC NUND 12:30 - 16:30 I 4.00 ~ T WELCT NUND 16:30 - 18:00 1.50 18:00 - 20:45 I 2.75 20:45 - 21:00 ~ 0.25 21:00 - 00:00 ! 3.00 NUND NUND SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC BOPE SURFAC NUND I SURFAC Page 15 of 57 Spud Date: 11!21/2005 Start: 11/18/2005 End: 1/28/2006 Rig Release: 1!28/2006 Group: Rig Number: 15 Description of Operations Varify latck in port collar with 112,000 up weight. Test to 1000 psi to varify bal seated in choke sub. Bleed to 500 psi. open post and lost pressure. Cirettit~e port sir at 1t} spm 20fi pat::. partial return on 1t3;bprtt to ceNar. Re~fms sla~tiy from 1t3 Fern ~ , Pump water at 1 bpm = 300 psi starting decreasing to 150 psi final. Stage up slowly to 2bpm = 200 psi. Stage up to 2.5 bpm with water. Large amount of sand coming across shakes. Pump 191 bbls water. Pump 9.6 ppg mud at 2.5 bpm @ 80 psi. staging up to 3.5 bpm = 100psi. large amount of sand across shakers Hole unloading sand as staged up flow rate. Start increasing vis from 35 to 55 sec's / qt. Continue to circulate and condition mud. stage flow rate from 2bpm tp 5 bpm = 180 psi. Increase flow rate to 6 bpm 270 psi. Sand still coming across shakers, cleaning up slowly Pump nut plug sweep to calculate hole volume. 1638 stks = 165.4 bbls total circulating volume when nut plug returns seen. 17 bbls drill pipe 148 barrels open hole - 226% excess. Shaker cleaning up. 100% returns. Held pre-job safety meeting with Doweel, rig crew, truck drivers, MI, etc. Pump 20 bbls water. test lines to 3000 psi. pump 223 barrel total cement. 288 sks Arcticset Lite III 6809 @ 4.45 ft3 / sk 10.7 ppg Cement bade to surface at 248 tsarrets. Open t~1nr up to cellar, s#isplace 3 barrels water (cement displaced to rig floor). Switchto'rig purer and displace 17.5 barrels to tam port collar. Pick up to 118,000# and shift port collar closed. Turn string 114 turn right and release from port collar. Lay down 3!4" grout sting from between conductor and 10 3/4" caing at 245' Lay down 1 jt 5" DP, circulating "T" 10' pup make up TIW and pump in sub. Pressure up to 2500 psi and shear out choke sub circulate between 5" DP and 10 3/4" surface casing @ 992 feet. Rig down circulating head &TIW valve. Blow down lines. POOH with DP and lay down port collar shifting tool. Make up 10' 10 3/4" pup joint to landing joint. Land casing in well head. Brea! out landing joint and lay down. Nipple down diverter system, flush flow lines and annular. fuction knife valve and flush. Nipple up FMC Gen 5 well head orient per FMC. Pick up and make up riser spool. Nipple up BOP, connect kill line and flow lines. N/U and prepare to test. Set riser and BOP stack. Test well head seal to 1000psi. Continue nipple up BOP, connect kill line and flow lines. N/U and prepare to test. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 16 of 5~ Operations Summary Report Legal Welf Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Sub Date From - To Hours Code ~ Code' .Phase ~ Description of Operations 12/7/2005 21:00 - 00:00 -..3.00-_ __ ~I 1- _ _ _ _._- --- _ - - _ - __ WELCTIJ NUND SURFAC Set riser and BOP stack. 12/8/2005 00:00 - 01:30 1.50; WELCT~ NUND SURFAC ~ Nipple up BOP, kill lines, choke and control lines. Hook up flow lines and prepare for BOP test. Set bell nipple and make upturn buckles. 01:30 - 03:00 1.50; WELCT~I BOPE SURFAC ~ Rig up test equipment to test BOP. Make up test plug and pump in sub. 03:00 - 03:45 0.75 03:45 - 04:30 0.75 04:30 - 08:45 i 4.25 08:45 - 10:00 1.25 10:00 - 14:30 ' 4.50 14:30 - 16:45 2.25 16:45 - 21:15 4.50 21:15 - 22:30 1.25 22:30 - 23:15 ~ , 0.75 23:15 - 00:00 12/9/2005 00:00 - 02:00 { 02:00 - 02:45 02:45 - 06:00 06:00 - 09:00 09:00 - 12:30 12:30 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 00:00 0.75 2.00 SFTY OTHR BOPE WELCT~ BOPE RIGMNT, RSRV DRILL PULD DRILL PULD DRILL (TRIP DRILL DEOT I DRILL ;TRIP DRILL TRIP SURFAC i, PJSM to test BOP's SURFAC 'Thaw out test pump line. SURFAC Test 13QP wittt Alaska state John Grisp as witness. .250 psi low test 5 minutes & 3500 psl high test 5 minutes. Accumulator draw down test :Manifold pressure 2900 psi /! 1500 psi 41 seconds to 200 psi. 4 minute build up 5 bottles @ 2450. j note: 4 minutes is the maximum allowable time. SURFAC Pull test plug, set wear ring (OD = 10.75 / ID = 9 7/8")Lay down test joint. SURFAC ;Changed out top drive saver sub . SURFAC PJSM: Lay down 11 joints 5" HWDP from derrick. Lay down jars, 3 x NMFDC's and clear rig floor. SURFAC :PJSM: Pick up 9 7/8 directional BHA, Hycalog PDC, Motor, MWD, NMFDC. Up load MWD tool and shallow hole pulse test. SURFAC i PJSM: Run in hole picking up 5" drill pipe from pipe shed (singles) SURFAC Pick up single and work past tam-port collar. Set down 3 - 5000# through as bit passed. Worked through without difficulty. Because we did see drag we ran quick test on casing to 2500 psi tool 94 strokes and held good for 5 minutes. Tam port collar and casing holding. SURFAC ;Trip in hole from 990' to 3286' picking up singles from pipe shed. SURFAC ~ Run in hole picking up 210 jts drill pipe from pipe shed. 02:30 @ 3400 feet fill pipe and float valve was not holding. Circulate to clear float and balance mud in hole. 0.75 DRILL CIRC SURFAC Circulate to clear stuck float valve and balance mud system is lighter in .drill pipe than string. Circulate hole volume at 3400 feet 308 bbls. Float holding. 3.25 DRILL TRIP ~ SURFAC Rig picking up single drill pipe from pipe shed @ 5854' 3.00 DRILL TRIP SURFAC ;Rig picking up single drill pipe from pipe shed from 5854' to 7090' 3.50 ~ DRILL TRIP ,SURFAC Trip in hole with pipe from derrick from 7090 to 14190' Weight up = 310,000# 1.00 DRILL CIRC SURFAC ~ Circulate at 168 gpm = 1000 psi Circulate tube pill 2040 stks. Up weight j= 350,000# down weight = 90,000# 1.00 RIGMNT RSRV SURFAC Rig service /top drive and work on CVUC decoder card on top drive. 0.50 DRILL TRIP SURFAC Trip in hole from 10419 to 10996' and tag up at 10996' 'Total gain during trip = 128 bbls. 2.50 DRILL CIRC SURFAC Circulate and condition mud 255 gpm = 850 psi. Up weight = 320,000# down weight = 100,000# 0.50 ~ DRILL RIRD i SURFAC ;Rig up to test casing. 1.00 DRILL DEQT SURFAC 'Test 10 3/4" surface casing to 2500 psi for 30 minutes and chart. Good test. 5.00 i RIGMNT RGRP !SURFAC ;Work on top drive. Do general house keeping, Insolate steam lines, clean suction screens on mud pumps, and peerform PM's. i Top drive rep. on location working on system. Printed: 2/16/2006 4:03:41 PM ConocoPhiliips Alaska Page 17 of 57 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 12/9/2005 ~ 19:00 - 00:00 12/10/2005 00:00 - 06:00 06:00 - 09:30 I 09:30 - 12:00 12:00 - 13:00 13:00 - 14:30 14:30 - 16:15 16:15 - 18:00 18:00 - 00:00 12/11/2005 1 C-20 1C-20 Spud Date: 11/2112005 ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Doyon 15 Rig Number: 15 !Hours Code ! Code, Phase ~' Description of Operations 5.00 1 RIGMNT RGRP SURFAC Loading 7 5/8" casing into pipe shed. 6.00 1 RIGMNT. RGRP SURFAC ,Working on top drive. Reset parameters and upload new setting. Still not able to control torque or run in normal mode. 3.501 RIGMNT' RGRP SURFAC Change out encoder and reset parameters. " Doing preventive maintenance. loading pipe shed with 7 5/8 casing Top drive working and tested in normal mode. 2.50 j DRILL REAM SURFAC Wash down to 11045' Tagged up 10984' Weight up = 270,000# Weight Dowm = 110,000# Weight rotating = :155,000# Pumping at 550 gpm = 2845 psi. Torque 21,000 ft# on bottom 24,000 1 ft# ' " 1.00 DRILL DRLG SURFAC Drill cement 11045 to 11150 : 20 new hole drilled. Shoe at 11,107 AST 0 hrs: Rot hrs = .45 .,Weight up = 270,000# Weight Down = 110,000# Weight rotating = 155,000# i Pumping at 550 gpm = 2845 psi. Torque 21,000 ft# on bottom 24,000 ~ i DRILL ' CIRC SURFAC Circulate and condition mud to preform leak off test. i 1.75; ~ DRILL FIT SURFAC Perform !mac off 1e>$t. LOT = 94.3 PRG 1f)50 PSi // Test mud weight i ~ 9.7 ppg Rump~d'ht 3 bbis eKx! captured 2.9 bbls on bleed back. 1.75 DRILL ; DRLG INTRM1 .Drill from 11,107' to 11334' Weight up = 240,000# Weight Down = 120,000# Weight rotating = 165,000# Pumping at 550 gpm = 2850 off 3100 psi on bottom. Torque 15,000 ft# l on bottom 18,000 ft# i ~ ! ECD = 10.4 ppg 6.001, DRILL ~ DRLG INTRM1 Drill from 11334' to 11728' AST -.8 hrs. ART = 3.1 hrs Total bit hours = 3.9 Weight up = 240,000# Weight Down = 120,000# Weight rotating = ' ,165,000# Pumping at 650 gpm = 2900 psi. ECD = 10.5 ppg Rotate @ 100 RPM = ;Torque 18,000 ft# On bottom 16,000 fi# off bottom. 00:00 - 06:00 06:00 - 12:00 6.00! DRILL DRLG , INTRM1 6.00 Directional drilling from 11728' MD (4764" TVD) to 12128' MD 4895'TVD) String weights: Up = 220,000# // Down = 140,000# Rotating = 170,000# Flowing 637 GPM = 3150 psi on bottom / 3050 psi off bottom 100 Top drive RPM = 13,000 ft# on bottom / 15,000 ft# off bottom WOB 20 - 25,000# 12321' MD Ghost ream will be out of casing shoe. Maximum gas units 82 Back ground gas 25 units. Bit hours 4.5 drilling hours J .8 slide hours / 3.7 rotating hours. DRILL 'DRLG ~ INTRMI I Directional drilling from 12128' MD (4895'TVD) to 12495' MD 5005'TVD) ,String weights: Up = 240,000# J/ Down = 135,000# Rotating = 170,000# 'Flowing 650 GPM = 3090 psi on bottom / 2950 psi off bottom 100 Top drive RPM = 13-15,000 ft# on bottom / 12-15,000 ft# off i bottom WOB 20 - 25,000# ECD's average 10.26 10.8 ppg max. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'From - To 12/11/2005 106:00 - 12:00 Opera#ions Summary Report .:Page 18 of 57 1 C-20 1C-20 Spud Date: 11/21/2005 ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Doyon 15 Rig Number: 15 Hours ' Code ' Sub ', Phase ~ Description of Operations Code! s.oo _ - _ __~ _ -_ -_ _ __ __ DRILL ~ DRLG INTRM1 ,12321' MD Ghost ream will be out of casing shoe. Maximum gas units 82 background gas 25 units. ' Additional slide hours = .59 !! additional rotating hours = 4.25 ~; Bit & jar drilling hours = 14.25 12:00 - 00:00 I 12.00 12/12/2005 100:00 - 06:00 DRILL DRLG INTRMI 6.001 DRILL I DRLG I INTRM1 Directional drilling from 12495' MD (5005'TVD) to 12985 (5149" ND) String weights: Up = 260,000# // Down = 130,000# Rotating = 180,000# Flowing 650 GPM = 3090 psi on bottom / 2950 psi off bottom 100 Top drive RPM = 13-15,000 ft# on bottom / 12-15,000 ft# off bottom WOB 20 - 32,000# ECD's average 10.26 to 10.8 ppg max. Maximum gas units 88 background gas 25 units. Additional slide hours = .0.0 // additional rotating hours = 4.96 Bit & jar drilling hours = 23.14 Pumped 50 bbls tube and nut plug pill @ 12989' and slightly reduced torque and incresed motor dill pressure. Continue to maintain tube to 2.5 - 3% to manage torque. Directional drilling from 12985 (5149" TVD) to 13310' (5149" TVD) String weights: Up = 250,000# // Down = 135,000# Rotating = 180,000# Flowing 650 GPM = 3550 psi on bottom ! 3350 psi off bottom 100 Top drive RPM = 19-20,000 ft# on bottom / 20,000 ft# off bottom WOB 20 - 40,000# Surface loss /Actually weight? ECD's average 10.26 to 10.8 ppg max. Maximum gas units 75 background gas 25 units. Additional slide hours = 0.0 /! additional rotating hours = 4.40 27.57 total hrs. Bit & jar drilling hours = 27.57 06:00 - 17:30 I 11.50 DRILL DRLG ' INTRM1 Directional drilling from 13310' (5149" TVD) to 13983' (5452' TVD) String weights: Up = 245,000# // Down = 140,000# Rotating = 170,000# Flowing 650 GPM = 3820 psi on bottom / 3650 psi off bottom ;100 Top drive RPM = 17-18,000 ft# on bottom / 12-13,000 ft# off bottom i WOB 20 - 40,000# Surface loss !actually weight? ~; ECD's average 10.26 to 10.8 ppg max. ' Maximum gas units 46 background gas 30 units. Bit & jar drilling hours = 36.54 17:30 - 19:00 1.50 DRILL CIRC INTRM1 Circulate to condition for short trip. 650 gpm 3600 psi Circulated 1200 bbls total. 19:00 - 20:00 1.001 DRILL OBSV ; INTRMI Monitor well before short trip. 20:00 - 20:30 0.50 DRILL WIPR INTRM1 Short trip to 12700' with 260,000# maximum up weight on elevators. ' ~ ! 135,000# SOW 20:30 - 20:45 0.251 DRILL REAM ' INTRM1 FiH pipe 1 stand off bottom and ream to bottom. Hole in good condition ' and no fill seen. 20:45 - 00:00 3.25 I' DRILL DRLG; INTRM1 ' Directional drilling from 13983' (5452' TVD) to 14000' MD (5472' TVD) String weights: Up = 240,000# // Down = 140,000# Rotating = 170,000# it I Flowing 650 GPM = 3820 psi on bottom / 3600 psi off bottom Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 19 of 57 Operations Summary Reporf Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1!28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 12/12/2005 f=rom - To Hours , Code Code ~ Phase ! Description of Operations _- - _ _ _ .- - _ _ _1__ __- _ - _ _ ~_ __ _- _ -- - 20:45 - 00:00 3.25 DRILL ~! DRLG II INTRMI ~ 100 Top drive RPM = 17-18,000 ft# on bottom / 12-13,000 ft# off bottom WOB 20 - 40,000# Surface loss !actually weight? ' ECD's average 10.26 to 10.8 ppg max. Maximum gas units 896 background gas 30 units. 2.26 ADT // 0 AST // 38.78 hours Total bit hours I Bit & jar drilling hours = 38.78 12/13/2005 100:00 - 07:15 I 7.251 DRILL I DRLG i INTRM1 07:15 - 08:30 1.25 08:30 - 08:45 ~ 0.25 08:45 - 15:30 6.75 15:30 - 16:15 0.75 16:15 - 21:00 4.75 DRILL ! CIRC INTRM1 DRILL ' OBSV I INTRM1 DRILL TRIP INTRM1 DRILL ~ PULD ! INTRM1 DRILL PULD (INTRMI 21:00 - 00:00 3.00 DRILL TRIP ' INTRM1 12/14/2005 ' 00:00 - 03:45 3.75' DRILL ' TRIP :INTRMI 03:45 - 05:45 2.00 RIGMNT RSRV ~ INTRM1 05:45 - 07:30 ' 1.751 DRILL TRIP INTRM1 07:30 - 08:00 0.50' DRILL ~ REAM ,INTRMI :08:00 - 12:00 4.00 i DRILL ; DRLG INTRM1 Directional drilling from 14000' MD (5472' TVD) to 14230" MD (5546" TVD) Pumped sap sweeps, walnut hulls, tube and combination of all with no results. String weights: Up = 255,000# // Down = 145,000# Rotating = 185,000# Flowing 650 GPM = 3780 psi on bottom / 3620 psi off bottom 100 Top drive RPM = 15-16,000 ft# on bottom / 12-13,000 ft# off bottom Note. torque is down. Pump pressure is erratic. WOB 20 - 40,000# Surface loss /actually weight? ECD's average 10.26 to 10.8 ppg max. Maximum gas units 896 background gas 30 units. Bit & jar drilling hours = 44.12 At 14010 feet while preparing to trip for obit / BHA change to improve ROP. Again the ROP increased from 12 fph to 60 fph. Lost drive chain on mud pump #1. Circulate with one mud pump and prepare and condition to come out and change out bit. 400 gpm = 1600 psi 100 rpm 12,000 ft # torque. Monitor well for well control to trip out. Trip out of hole from 14230 to 423 feet to HWDP. Hole in good condition and came on elevators with no tight spots. Stand back Jars and BHA. Clean BHA and bit. Bit balled up with 2 plugged jets. Down load MWD and change out bit and motor. Run 7" Sperry drill set at 1.22 bend. Same BHA only fresh components. Repaired Mud pump chain /ready to go. Trip in hole with new bit and BHA to 4000' Fill pipe every 25 stands. Trip in hole from derrick from 4000 to 11089' PJSM: slip and cut 120' drilling line (14 wraps) Service top drive and change out hand warmers in top drive control panne!. Trip in hole from 11089 to 14135. PU weight = 250,000# // S/O weight = 140.000# No problem seen going into open hole. Fill pipe and ream last stand down as precaution. 650 gpm 3630 psi 100 rpm 13 - 15000 ft# torque Directional drilling from 14230" MD (5546" TVD) to 14507' MD (5629' tvd) String weights: Up = 250,000# // Down = 140,000# Rotating = 175,000# WOB = 10 - 20,000# Flowing 650 GPM = 3750 psi on bottom / 3620 psi off bottom 100 Top drive RPM = 18-19,000 ft# on bottom / 12-15,000 ft# off bottom Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 20 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1 /2 812 0 0 6 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date !From - To 12/14!2005 i 08:00 - 12:00 12!15/2005 Hours ~' Code ' Sub Code _ - ,- 4.00 ~ DRILL C DRLG 12:00 - 16:00 ~ 4.00 16:00 - 16:45 I 0.75 16:45 - 20:00 3.25 DRILL DRLG Phase ~ Description of Operations INTRMI WOB 20 - 40,000# Surface loss !actually weight? ECD's average 10.26 to 10.8 ppg max. Maximum gas units 48 background gas 22 units. Bit & jar drilling hours = 46.94 2.82 total drilling hours in 4 hours with ROP of 99 fph. I NTRM 1 DRILL CIRC INTRM1 DRILL DRLG IINTRM1 20:00 - 22:00 I 2.00 DRILL ~ CIRC ., 22:00 - 00:00 j 2.00 ~ DRILL i DRLG INTRM1 INTRM1 Directional drilling from 14507' MD (5629' tvd) to 14792' MD (5723' tvd) String weights: Up = 260,000# // Down = 135,000# Rotating = 175,000# WOB = 10 - 15,000# Flowing 650 GPM = 3900 psi on bottom / 3790 psi off bottom 100 Top drive RPM = 21-23,000 ft# on bottom / 20,000 ft# off bottom ECD's average 10.7 to 10.8 ppg max. One ECD spike acting like pack off to 12.5 ppg Maximum gas units 41 background gas 21 units. Bit & jar drilling hours = 49.94 3.0 total drilling hours in 4 hours with ROP of 95 fph. Control drilling for ECD's and to aid in hole cleaning. Circulate and condition to reduce ECD's and clean up hole. Pump 140 vis sweep. Directional drilling from 14792' MD (5723' tvd) to 14983' and (5784' tvd) String weights: Up = 270,000# // Down = 150,000# Rotating = 185,000# WOB = 15 - 20,000# Flowing 650 GPM = 4000 psi on bottom / 3800 psi off bottom 100 Top drive RPM = 21-23,000 ft# on bottom ! 20,000 ft# off bottom ECD's average 11.0 to 11.3 ppg max. Maximum gas units 97 background gas 33 units. Bit & jar drilling hours = 52.19 1.21 total drilling hours in 3.25 hours with ROP of 85 fph. Control drilling for ECD's and to aid in hole cleaning. Circulate and do mud spike while repairing mud pump liner gasket. Had planned on bring mud weight up while drilling ahead but can not drill ahead with one mud pump. EECD's = 10.8 ppg after swap Directional drilling from 14983' MD (5784' TVD) to 15036' MD (5801' TVD) String weights: Up = 270,000# // Down = 150,000# Rotating = 185,000# WOB = 15 - 20,000# Flowing 650 GPM = 4000 psi on bottom / 3800 psi off bottom 100 Top drive RPM = 21-23,000 ft# on bottom / 20,000 ft# off bottom ECD's average 11.0 to 11.3 ppg max. Maximum gas units 97 background gas 33 units. Bit i~ jar drilling hours = 53.12 1.23 total drilling hours in 4 hours with ROP of 45 fph. Control drilling to clean up hole and allow shakers to clean up. 15002' Hole packed off and stalled top drive. Worked free. Increased cuttings across shakers and erratic torque and drilling parameters. Mud weight in 9.9 ppg with glycol. 00:00 - 06:00 ~ 6.00 ~ DRILL I DRLG j INTRM1 !Directional drilling from 15036' MD (5801' TVD) to 15297 Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 21 of 57 Operations Summary'Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT - DR{LLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To 'Hours '~ Code 'Sub '~~ Phase ~ Description of Operations Code 12/15/2005 00:00 - 06:00 6.00 DRILL DRLG INTRMI String weights: Up = 275,000# // Down = 145,000# Rotating = 190,000# WOB = 12 - 18,000# i Flowing 650 GPM = 4000 psi on bottom / 3870 psi off bottom 100 Top drive RPM = 17-20,000 ft# on bottom / 16-17,000 ft# off ~, bottom Maximum gas units 106 background gas 34 units. ' Bit = 13.1 4.1 total drilling hours in 6 hours with ROP of 64 fph. 06:00 - 18:00 ~ 12.00 ~ DRILL ~ DRLG I, INTRM1 18:00 - 00:00 I 6.001 DRILL I DRLG I INTRM1 12/16/2005 100:00 - 06:00 I 6.00 ~ DRILL !DRLG I INTRM1 06:00 - 12:00 6.001 DRILL I DRLG i INTRM1 Directional drilling from 15297 (5888' TVD) to 16160' MD (6008' TVD) String weights: Up = 280,000# // Down = 140,000# Rotating = 190,000# WOB = 12 - 15,000# Flowing 625 GPM = 3900 psi on bottom / 3690 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 19-22,000 ft# on bottom / 16-17,000 ft# off bottom Maximum gas units 109 background gas 33 units. Bit = 21.90 8.8 total drilling hours in 12 hours with ROP of 98 fph. Directional drilling from 16160' MD (6008' TVD) to 16560 (6269' TVD) String weights: Up = 290,000# // Down = 145,000# Rotating = 180,000# WOB = 12 - 15,000# Flowing 625 GPM = 3900 psi on bottom f 3690 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 20-23,000 ft# on bottom / 20-22,000 ft# off bottom Hello HRZ! Maximum gas units 86 background gas 28 units. Bit = 25.93 4.03 ADT // .69 AST // 3.34 ART 4.03 total drilling hours in 6 hours with ROP of 99 fph. Jar hours = 70.88 total Directional drilling from 16560 (6269' TVD) to 16990' MD (6400' tvd) String weights: Up = 290,000# // Down = 145,000# Rotating = 180,000# WOB = 12 - 15,000# Flowing 600 GPM = 3940 psi on bottom ! 3670 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 20-23,000 ft# on bottom / 20-22,000 ft# off bottom Maximum gas units 9 background gas 30 units. Bit = 25.93 4.03 AD7 // .69 AST !! 3.34 ART 3.91 total drilling hours in 6 hours with ROP of 109 fph. Jar hours = 74.79 total Directional drilling from 16990' MD (6400' tvd) to 17314 (6488' TVD) String weights: Up = 295,000# // Down = 145,000# Rotating = 185,000# Printed: 2/16/2006 4:03:41 PM ConocoPh'illips Alaska Page 22 of ~7 Operations. Summary.. Report. Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From -To -Hours I Code ~, Sub ', Phase Code 12/16(2005 ~ 06:00 - 12:00 12:00 - 18:00 18:00 - 18:30 18:30 - 00:00 12/17/2005 ' 00:00 - 06:00 6.00 DRILL DRLG ~ INTRMI 6.001 DRILL I DRLG 0.501 RIGMNT; RGRP 5.501 DRILL I DRLG INTRMI INTRM1 INTRM1 Description of Operations WOB = 12 - 15,000# Rotating and stacking out sliding with very little differential pressure. Having a tough time sliding and making progress. Flowing 620 GPM = 3920 psi on bottom / 3720 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 20-23,000 ft# on bottom / 20-22,000 ft# off bottom Maximum gas units 89 background gas 34 units. Bit = 34.51 4.67 ADT // 1.67 AST // 3.0 ART 4.67 total drilling hours in 6 hours with ROP of 70fph. Jar hours = 78.63 total Directional drilling from 17314 (6488' TVD) to 17440' MD String weights: Up = 295,000# // Down = 145,000# Rotating = 185,000# WOB = 12 - 15,000# Rotating and stacking out sliding with very little differential pressure. Having a tough time sliding and making progress. Flowing 620 GPM = 3920 psi on bottom / 3720 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 20-23,000 ft# on bottom ! 20-22,000 ft# off bottom Maximum gas units 89 background gas 34 units. Bit = 37.49 2.98 ADT // 2.27 AST // .7 ART 2.98 total drilling hours in 6 hours with ROP of 42fph. Jar hours = 81.61 total Change out valve and seat on mud pump #1 Circulate sweep while working on pump. Directional drilling from 17440' MD to 17553' MD (TVD = 6543') String weights: Up = 295,000# !! Down = 145,000# Rotating = 185,000# WOB = 12 - 15,000# Rotating and stacking out sliding with very little differential pressure. Having extreamly a tough time sliding and making progress. Flowing 620 GPM = 3920 psi on bottom / 3720 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 20-23,000 ft# on bottom / 20-22,000 ft# off bottom Maximum gas units 89 background gas 34 units. Bit = 37.49 2.13 ADT // 2.13 AST // .83 ART 2.96 total drilling hours in 6 hours with ROP of 38fph. Jar hours = 84.57 total 6.00 DRILL ~ DRLG 'i INTRM1 Directional drilling from 17553' MD (TVD = 6543') to 17622 (6576' TVD) String weights: Up = 295,000# // Down = 145,000# Rotating = 185,000# ~, WOB = 12 - 15,000# Rotating and stacking out sliding with very little differential pressure. Having extremely a tough time sliding and making ~ `progress. Flowing 600 GPM = 3850 psi on bottom / 3550 psi off bottom ;Reduced flow rate because of pressures limits Printed: 2/162006 4:03:41 PM CanocoPhillips Alaska Page 23 of 57 From - To 'Hours ' Code ~ ode I Phase ' Description of Operations - _- ~ 00:00 - 06:00 6.00 DRILL I DRLG INTRM1 ~ 100 Top drive RPM = 20-22 000 ft# on bottom / 20-22 000 ft# off Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 12/17/2005 bottom Maximum gas units 89 background gas 24 units. Bit = 43.21 2.76 ADT // 2.76 AST // 0.0 ART 2.96 total drilling hours in 6 hours with ROP of 38fph. ;Jar hours = 87.33 total 06:00 - 10:00 Operations. Summary Reporf 4.00 10:00 - 12:15 ! 2.25 12:15 - 12:30 0.25 12:30 - 16:00 ~ 3.50 16:00 - 17:15 1.25 17:15 - 20:00 ~ 2.75 20:00 - 23:15 3.25 23:15 - 00:00 0.75 12/18/2005 00:00 - 00:30 0.50 00:30 - 04:15 ~I 3.75 DRILL I DRLG INTRM1 DRILL CIRC INTRMI DRILL OBSV INTRM1 DRILL WIPR INTRM1 DRILL ~ RIGMNT CIRC . INTRM1 RSRV INTRM1 DRILL WIPR INTRM1 DRILL i REAM INTR : MI DRILL REAM ~ INTRM1 DRILL CIRC (INTRMI Directional drilling from 17622 (6576' ND) to 17726' (6588"ND) String weights: Up = 300,000# // Down = 145,000# Rotating = 190,000# WOB = 12 - 22,000# Rotating and stacking out sliding with very little differential pressure. Flowing 600 GPM = 3850 psi on bottom / 3550 psi off bottom Reduced flow rate because of pressures limits 100 Top drive RPM = 20-22,000 ft# on bottom / 20-22,000 ft# off bottom Maximum gas units 89 background gas 24 units. Bit = 44.95 1.77 ADT // 1.77 AST // 0.0 ART 2.96 total drilling hours in 6 hours with ROP of 59fph. Jar hours = 89.07 total Geologist called casing point, Slightly behind on require inclination of 85 degrees at projected 80 - 81 degrees at bit. Circulate and condition at 650 gpm = 3850 psi rotating at 100 rpm Pump weighted sweep. Monitor well for flow and hold PJSM for short trip. POOH from 17726 to 11,000' 390,000# maximum pull. PuII 5 stands and pump dry job. POH on elevators, hole taking correct fill and look good. Circulate and condition at casing shoe. 650 gpm 3600 psi 100 rpm PJSM: To slip & Cut and service rig /Cut 69' drilling line ,service rig & top drive. Function test BOP's As per AOGCC reg's. RIH from 11,000' to 17390' Hit tight spot and work through. RIH to 17450 tag up and attempt to work through. Fill pipe and attempt to circulate. Packing off and tight. Stand back 1 stand and circulate and condition. Bring pumps up slowly some packing off. ECD's spike to 12 ppg. Wash and ream to 17600. at 630 gpm and 100 RPM. Torque spikes at 26 - 28,000ft# Ream and condition hole. Tight spots at 17390 - 17450 and 17500' Ream to bottom as precaution. Ream to bottom with 650 gpm 4000 psi. 100 RPM 18 - 28,000ft# torque. Pick up weight 310,000# Slack off weight = 140,000# Circulate and condition. Bottoms up loaded the shakers. Lots of cuttings. Pumped sweep (tube & nut plug) no increase in cuttings, hole starting to clean up. Pump Second sweep weight . hi-vis. Small increase in cutting but cleaning up. 620 gpm 4000 psi 100 rpm 18-20,000# P/U weight 305,000# // S/O weight 130.000# Rotating Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 24 of 57 Operations Summary. Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conoco phillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 'From - To __- - Hours "Code' ~ Sub ' Phase Code Description of Operations 12/18/2005 00:30 - 04:15 ' 3.75 DRILL CIRC INTRM1 ;weight 190,000# 1 .Planned to make second 10 stand short trip to check hole conditions. ~ 04:15 - 04:30 0.25 , DRILL OBSV INTRM1 Monitor well for trip .static. ': 04:30 - 05:15 0.75 DRILL WIPR ~ INTRM1 Short trip 11 stands to 16792' ~ Tight @ 17,300 - 282 pull to 400,000# j 17271 - 250 pull to 400,000# 17100 - 085 pull to 400,000# j ~I 17048 - 17000 pull to 400,000# ~ 05:15 - 05:45 ' 0.50 DRILL WIPR INTRM1 Trip in hole from 16792 to 17726. Hole in much better condition. i , 05:45 - 08:15 2.50 DRILL CIRC INTRM1 j Circulate and condition @ 625 gpm 3850 psi. Pump sweep hi vis ~' j I weighted. ~I ~ Pump 1010 bbls total volume. Shakers clean. 08:15 - 10:00 ! 1.75 DRILL CIRC INTRM1 Circulate and condition 650 gpm 3900 psi 120 rpm 24 - 26,000ft# torque. Pump 1010 total bbls. Torque high ECD 11.6 - 11.9. ppg Stand back one stand and continue to circulate. PJSM: Monitor well for well control to trip out. Pump dry job POH to 14865' Pulled 40K over at 17175, worked through one time with no over pull. P/O weight = 310,000# // S/O weight = 140,000 POOH from 14865 to 11050' 250,000# up weight / 130,000# S/O weight. 10:00 - 12:00 2.00 ~ DRILL TRIP INTRMI 12:00 - 14:15 2.25 DRILL TRIP i ~ INTRM1 14:15 - 16:45 2.501 DRILL CIRC INTRMI 16:45 - 17:30 0.75 DRILL OBSV ; INTRM1 17:30 - 22:00 4.50 DRILL TRIP INTRM1 22:00 - 22:30 ! 0.50 DRILL !TRIP INTRM1 22:30 - 00:00 ~ 1.50 DRILL I WIPR INTRM1 i 12/19/2005 i 00:00 - 02:30 2.50 ~ DRILL TRIP ! INTRM1 02:30 - 03:30 ~ 1.00 03:30 - 04:30 ~ 1.00 DRILL (PULD INTRM1 DRILL i PULD INTRM1 04:30 - 05:00 0.50 05:00 - 05:30 . 0.50 05:30 - 05:45 ! ~ 0.25 05:45 - 07:45 I 2.00 07:45 - 10:00 ~i 2.25 10:00-11:00 I 1.00 11:00 - 13:00 '. 2.00 13:00 - 17:45 'i 4.75 DRILL PULD ~ INTRM1 CASE i NUND INTRM1 CASE iNUND INTRM1 CASE NUND INTRM1 CASE NUND INTRM1 CASE I NUND I INTRMI CASE jRUNC INTRM1 CASE ~RUNC INTRM1 At casing shoe 11050 circulate @ 650 gpm 3300 psi 120 rpm. Pump sweep with 20% increase in cutting on bottoms up. Monitored well for well control. Pump dry job to trip out. Pull out of hole standing drill pipe in derrick to 4275' SLM. Prepare rig floor to lay down drill pipe to make room on rig floor to run casing. Continue to pull out of hole laying down singles from 4275 to 1050. Lay down ghost reamer. Continue to pull out of hole from 1092 feet. Handle BHA and lay down HWDP, NMFDC and jars. Ghost reamer was in good shape and full gauge. Down load MWD tool. and pull pulser. Lay down MWD, motor and bit. Bit graded 3-2-CT-N_D-3-E-TD The bit was 3 /16" under gauge and may have been a contributing. part of slower ROP sliding as the ghost reamer (full ga) hung up in the shale. Lay down tools off rig floor and to pipe shed. Rig up and pull wear bushing. Pick up test plug Change out ramslo 7 5/8". RaJ up test equipment, Filj stack with water: Test 7 5/8" rams to 250 low and 3500 psi high. Valve on test pump faking on tins# test. Make up hanger and landing joint. Make dummy run, make landing and lay down same. PJSM to pick up and run 7 5!8" casing. Pick up casing handling equipment. Make up float equipment and run in hole to 2150. Float shoe, 3 x joints csg (130'), Float collar, 3 x jts csg, Pup joint with Pip tag, Joints 7 - 13 2 centralizers, joints 8 - 21 1 x centralizers. Two centralizers on first 13 joints. 1 centralizers 14-21 Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Event Name: ROT -DRILLING Start: 11/18/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours ~ Code Code { Phase 12/19/2005 i I 17:45 - 00:00 6.25 CASE RUNC INTRMI I 12/20/2005 1 I I 00:00 - 00:30 II 0.50 I CASE I j RUNC INTRM1 1 I 00:30 - 01:00 ~ j 0.50 ~ CASE I I ~ CIRC INTRM1 01:00 - 03:00 2.00 CASE RUNC INTRM1 I ~ ~ 03:00 - 03:30 ~ i j 0.50 ~ CASE I j CIRC ~ INTRMI ~ 03:30 - 06:00 I I 2.501 CASE ~ ~ RUNC INTRM1 I I 1 j 06:00 - 06:15 ~ ~ 0.251 CASE j I SFTY INTRMI 1 06:15 - 08:00 1.75 CASE I ~ RURD f INTRMI ~ 08:00 - 09:45 ~ 1.75 CASE GIRC J INTRM1 1 ~ 09:45 - 10:30 ~ ~ 0.75 ~ CASE I I f RUNG ~ INTRM1 ~ 1 10:30 - 11:15 ~ 11:15 - 12:00 ~ ~ I, 0.751 CASE 0.75 CASE 1 ~ I OTHR RUNC ~ INTRM1 INTRM1 1 1 12:00 - 13:30 ~ I I, 1 1.50 CASE I I 1 RUNC INTRM1 I II 113.30 - 14:30 I ~ 1.001 CASE ~ CIRC INTRMI I I 14:30 - 15:30 ~ I 1 1.001 CASE i RUNC ~ I INTRMI I 1,15:30 - 16:45 I 1.251 CASE I I I CIRC ~ INTRMI I i j 16:45 - 18:00 I I II ( 1.25 ~ CASE , I RUNC II I I INTRM1 j I ~ 18:00 - 20:45 I 1 j I 2.75' CASE i I ~ RUNC 1 INTRMI Page 25 of 57 Spud Date: 11/21/2005 End: 1/28/2006 Group: Description of Operations ~ Pick up and run 7 5/8" casing to 6190 feet. Fiil pipe every 5 joints and circulate every 10 joints. Record pick up and slack off weight every 10 joints. 145 joints picked up at midnight. ~ Pick up weight = 168,000# Slack off weight = 120,000# 1 Circulate 6 bpm = 450 psi. I Pick up and run 7 5!8" casing from 6190 feet(145 jts) to 6396' (150 jts). Fill pipe every 5 joints and circulate every 10 joints. Record pick up and ~ slack off weight every 10 joints. Circulate 7-5/8" casing @ 6396'. Circ rate 6 bpm w! 450 psi. Continue running 7-518" 29.7 ppf, L-80, BTC-M f/ 6396' (150 jts) to 18521' (200 joints). Fill pipe every 5 joints, and circulate every 10 joints. ~ Record PU and slack off weight every 10 joints. Ran a centering guide on joint # 156. ~ Circulate 7-5/8" casing @ 8521'. Circ rate 6 bpm w/ 550 psi. Continue running 7-5/8" 29.7 ppf, L-80, BTC-M f/ 8521' (200 joints)to 11082' (260 joints). Fill pipe every 5 joints, and circulate every 10 joints. Record PU and slack off weight every 10 joints. PU wt 245k, SO wt f 132k @ 11082'. PJSM on R/D side door elevators and RU long bales, Frank's fillup tool and 350 ton elevators. ~ R!D side door elevators and RU long bales, Frank's fillup tool and 350 jton elevators. Circ and condition mud @ 10-3/4" casing shoe. Circ @ 11082' (200 joints) 7 bpm w! 830 psi. PU wt 250k, SO wt 130k, Pump a total of 435 I bbls. Continue running 7-5/8" 29.7 ppf, L-80, BTC-M f/ 11082' (200 joints) to 11350' (267 joints). Fill pipe every 5 joints, and circulate every 10 joints Record PU and slack off weight every 10 joints. PU wt 255k, SO wt ~ 125k @ 11350'. Change out "O" rings in Frank's fillup tool, due to leaks. Continue running 7-518" 29.7 ppf, L-80, BTC-M f/ 11350' (267 joints) to 11650' (273 joints). Fill pipe every 5 joints, and circulate every 10 joints Record PU and stack off weight every 10 joints. PU wt 265k, SO wt 120k @ 11650'. Continue running 7-518" 29.7 ppf, L-80, BTC-M f/ 11650' (273 joints) to 13245' (310 joints). Fill pipe every 5 joints, and circulate every 10 joints. ~I Record PU and slack off weight every 10 joints. PU wt 280k, SO wt 125k @ 13245'. Break circ @ 13245' (310 joints), 6.5 bpm w! Frank's fillup tool and 860 psi. Change out rubber on Frank's tool I Continue running 7-5/8" 29.7 ppf, L-80, BTC-M f/ 13245' (310 joints) to 14530' (340 joints). Fill pipe every 5 joints, and circulate every 10 joints Record PU and slack off weight every 10 joints. it Break circ @14530' (340 joints), 7bpm w/ Frank's fillup tool and 1010 psi. Pumped 78 bbls. Frank's tool trapping pressure. Bad Equalizing valve. Lay down Frank's tool. Continue running 7-518" 29.7 ppf, L-80, BTC-M f/ 14570' (340 joints) to 115435' (362 joints). Fill pipe every 5 joints, and circulate every 10 joints j Record PU and slack off weight every 10 joints. PU wt 350k, SO vrt i 130k. Continue running 7-5/8" 29.7 ppf, L-80, BTC-M f/ 15435' (362 joints) to 17671'( 414 joints). FiII pipe every 5 joints, and circulate every 10 joints Printed: 2/16/2006 4:03:4'1 PM ConocoPhillips Alaska Page 26 of 57 Legal Well Name: 1C-20 Operations Summary Report Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28!2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1 /2 812 0 0 6 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To I Hours ~ Code Sub 'Code 12/20/2005 18:00 - 20:45 ~ 2.75 CASE ~ RUNC I 20:45 - 21:00 ~ I 0.25 CASE 1 RUNC j 21:00 - 21:15 I 0.251 CASE ~ RURD ~ 21:15 - 00:00 f I I i 2.75 ~ CEMENI~CIRC 12121!2005 i 00:00 - 02:00 i 2.00 ~ CEMENTCIRC 02:00 - 02:15 ~ 0.25 02:15 - 03:00 i 0.75 i 03:00 - 04:30 ~ 1.50 04:30 - 07:15 2.75 Phase INTRM1 INTRM1 INTRM1 I NTRM 1 I NTRM 1 SFTY j INTRM1 I CIRC ~ INTRM1 I I PUMP ~ INTRMI DISP INTRM1 07:15 - 09:30 I 2.251 CASE I RURD ; INTRM1 09:30 - 10:45 10:45 - 13:00 13:00 - 13:30 13:30 - 13:45 13:45 - 18:00 18:00 - 00:00 1.25 ~ WELCTL~ OTHR I INTRM1 I I 1 2.251 WELCTLI OTHR j INTRM1 I 0.50 ~ DRILL OTHR INTRMI 0.251 DRILL iSFTY 4.25 ~ DRILL I PULD 6.001 DRILL I PULD INTRM1 INTRM1 I NTRM 1 Description of Operations Record PU and slack off weight every 10 joints. PU wt 390k, SO wt 130k. Ran centering guides on joints # 403, 406, 409 and 412. MU/ RIH w/ FMC Hutted hangerw/ pup (Assembly # P 172 126) (CPAI part # 45080009) (Bowl 10.38", Bore 8.85") w/ landing joint (LH 8.5 ACME threads). R/D GBR power tongs, Remove slips, RIH, Land casing in wellhead. Rig up Dowell cement head, rig up circulating lines. Circ and condition mud prior to cement job. Stage pumps up f/ 2 bpm w! 775 psi, then 3 bpm w/ 870 psi, then 4 bpm wi 835 psi, then 5 bpm w/ 900 psi, then 6 bpm w/ 1000 psi, then 7 bpm w/ 1050 psi Circ and condition mud prior to cement jab. Circ 7 bpm wt 1fl50 psi.. Reap pipe 30' stroke. At 0200 hrs a total of 1$25 bbls pumped since on bottom w/ 7-5/8" 29.7 ppf L-80 BTC-M casing. PU wt 375k, SO wt 132k. MW 10.4 ppg, PV 14, YP 20. PJSM on cement job with rig supervisor, tourpusher, rig crew, Dowell, and mud engineer. Continue circulating and conditioning mud while having meeting. Continue circ and recip @ 7 bpm prior to cementing casing. PU wt 380K, SO wt 130K. Pumped a total of 2053 bbls mud prior to cement job. MW 10.4 ppg, PV 16, YP 21, 10 sec gels 8, 10 min gels 13. Dowell pump 10 bbls CW 100(8.34 ppg) @ 5 bpm w/ 680 psi ,test lines to 3500 psi, follow w/ 30 more bbls CW 100(8.34 ppg) @ 5 bpm w! 690-700 psi for total of 40 bbls CW 100, follow w/ 40 bbls Mudpush II spacer (12.5 ppg) @ 3.1-4.5bpm w/ 600-670 psi, shut down and drop bottom plug, mix and pump 52.8 bbls(255.5 sx) class "G" (15.8 ppg)( Yield 1.16 cuft/sx)( mix water 5.094 galfsx) @ 4 to 1.6 bpm w/ 586-124 psi, shut down and drop top plug, cleanup on top of plug w/ 5 bbls water @ 2 bpm w/ 215 psi. Then turn over to rig for displacement. Dowell had problems with pumps, therefore slower rates than planned. Reciprocated pipe 30' stroke throughout pumping. Rig displace cement w/ 10.4 ppg mud @ 5 bpm. Initial pressure 350 psi, final pressure before slowing pumps to 3 bpm was 600 psi. Reciprocated pipe 30' throughout pumping until slowing pumps to 3 bpm f/ last 20 bbls of displacement, then landed pipe w/ 132k down wt (blocks 70k of this wt, PU wt was 415k final). Bumped plug @ calculated displacement using 95.5°lo pump efficiency (.1002 bps) with 500 psi over final circ pressure of 600 psi @ 3bpm. Bumped plug w/ 1100 psi. Had full returns throughout. He{d pressure fJ 5 min., bleed off and check floats, holding. CIP @ 0657 hrs 12/21/2005 Blow down cemeting line. R/D Dowell 7-5l8" cementing head, UD FMC landing joint. UD Frank's fillup tool, UD GBR tongs, elevators, and slips. Change bales to short drilling bales and 5" elevators. Loading 4" dp in pipe shed, cleaning surface equipment and mud pits. Drain stack. RU and install FMC 7-5l8" packoff. Test packoff to 3000 psi f/ 15 min. Continue to load pipe shed w/ 4" dp. PJSM on changing top pipe rams f/ 7-5/8" to 4" fixed. Change top pipe rams to 4". Inspect BOP's. Install iron roughneck track. Install mousehole in rotary table to laydown dp f/ derrick. PJSM on laying down 5" dp f/ derrick. UD Weatherford 5" drill pipe from derrick using the mousehole. Continue laying down Weatherford 5" drill pipe from derrick using the mouse hole. Cleaning pits while UD dp. 49 stands left in derrick. Printed: 2!16!2006 4:03:41 PM ConacoPhillips Alaska Page 27 of 57 tJperations Summary Report Legal Well Name: 1C-20 Common Well Name: 1 C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11!18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1128!2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To , Hours Code 'Sub 'Code' Phase Description of Operations 12/22/2005 00:00 - 05:30 j _ 5.50 ~ DRILL PULD ~ INTRMI j Continue laying down last 49 stands Weatherford 5" driA pipe from j I derrick using the mouse hole. Cleaning pits while UD dp. I H2S drill. Muster area was shop. 05:30 - 06:00 i 0.50 I DRILL OTHR INTRMI Clear floor. Pick up XT-39 saver sub to rig floor. 06:00 - 08:30 1 108:30 - 10:00 j 2.501 1.50 DRILL DRILL OTHR OTHR ~ INTRM1 INTRM1 I Change out saver sub on top drive to 4" XT 39. IUD 5" handling tools, PU 4" handling tools to rig floor. 10:00 - 11:00 1.00 RIGMNTI, RSRV INTRM1 I Service top drive, crown of derrick, and complete derrick inspection. 111:00 - 12:00 1.001 DRILL I OTHR j INTRMI I Install FMC wear bushing,7- 1/16" ID, 10 13/16" OD, 1.0' length. UD ~ 12:00 - 12:30 1 0.50 i DRILL ~ SFTY INTRM1 (running tools. PJSM with all hands on MU BHA (6 3/4" bit and bit sub) and PU 4" DP j with HT 38 connection. 12:30 -16:00 3.50 DRILL I PULD ~ INTRM1 I MU 6 3/4" bit and bit sub. PU 4" HT 38 connection Weatherford dp. I ~ 16:00 - 18:00 1 2.001 I RIGMNT RGRP I INTRM1 Rabbit pipe to 2.45" with plastic rabbit. 100 joints picked up. Ij Change out "ramp tilt" cylinder packing on pipe skate. 118:00 - 19:00 1.00 ~ RIGMNT RGRP I INTRM1 ~ PJSM, Continue working on "Ramp tilt" cylinder packing replacement j 19:00 - 20:30 120:30 - 23:15 ~ 1.501 75 2 RIGMNT RSRV RIGMNT RGRP INTRMI INTRMI Ion pipe handling machine in pipe shed. j Slip and cut 85' of drilling line. I Continue work on pipe handling machine j 23:15 - 00:00 . 0.75 DRILL SFTY i INTRM1 . I PJSM on picking up Weatherford 4" DP. 12/23/2005 100:00 - 06:00 6.00 DRILL PULD INTRMI j PU Weatherford 4" DP, rabbit w/ 2.45" plastic rabbit. Picked up total of ~ j 1195 joints of 4" HT 38, then crossover, then will PU 4" X739. Total of 49 1 1 joints of XT39 picked up @ 0600 hrs. Total of 81 stands and asingle= j ~ I 17683'. 106:00 - 07:00 1.00 DRILL I CIRC INTRMI I Circ and condition thick mud in hole @ bit depth of 7683'. Circ @ 6.5 j 07:00 - 07:15 0.25 I DRILL ~ PULD f INTRM1 bpm w! 1420 psi. Pumped total of 250 bbls. Blow down top drive. ~ 07:15 - 07:30 ~ 07:30 - 12:00 0.25 4.50 DRILL DRILL SFTY ~ I PULD I INTRM1 INTRM1 I PJSM prior to PU 4" dp. I PU Weatherford 4" dp w/ XT 39 connections, drift w/ 2.45" plastic drift. 1 ~ j PU a total of 156 more joints f! total of 400 joints in hole (195 joints XT 12:00 - 17:30 ~ 5.50 DRILL I i 'PULD I INTRM1 138 + 205 joints XT 39). Depth 12536' I Continue PU Weatherford 4" dp w/ XT 39 connections, drift w/ 2.45" ~ 1 ~ plastic drift. PU a total of 161 more joints f! total of 561 joints in hole ~ ~ j I (195 joints XT 38 + 366 joints XT 39). Depth 17542'. PU wt 210k, SO wt 17:30 - 18:00 ~ 0.501 DRILL j ~ I PULD j INTRM1 1115k, blocks 70k. I PU joints 562 and 563 to tag up on cement above wiper plugs on float 1 118:00 - 20:45 I 2.751 DRILL I I CIRC ~ INTRM1 I collar @ 17581' MD. Tag @ 1757T.UD joint 563. Circ and condition mud in the hole @ 17570'. Circ 5 bpm w/ 2050 psi.6 I j I I bpm w/ 2000 psi, 7 bpm w/ 2700 psi. Circulate a total of 930 bbls. j 20:45 - 21:45 i 1.00 DRILL I OTHR I INTRM1 I Blow down top drive. PU single tag top of cement. UD single, install I ~ j I PS16 slips, UD single. 121:45 - 22:30 0.75 DRILL I TRIP INTRM1 I POOH standing 4" Weatherford dp in derrick. Pull 2 stands wet to . I ! 117322'. Lower volume in pit 5. Mix dry job using pit 5. 22:30 - 22:45 0.25 DRILL f CIRC ~ INTRM1 I Pump 40 bbl dry job @ 3bpm w/ 800 psi. Depth 17322'. 22:45 - 23:00 123:00 - 00:00 0.251 DRILL 1.001 DRILL i OTHR j I TRIP I INTRM1 INTRM1 j Blow down top drive. 1 POOH slow w/ Weatherford 4" DP f/ 17322' to 15481'. Install Western 12!24!2005 ~ 00:00 - 01:15 1.25 j DRILL j I (TRIP 1 INTRM1 ~ Wells super sliders according to plan. POOH slow w/ Weatherford 4" DP f/ 15481' to 13803'. Record PU and j I 01:15 - 02:15 I ~ 1.00 ~ DRILL II I TRIP I INTRM1 SO wt's every 10 stands. ,POOH slow w/ Weatherford 4" DP fl 15481' to 13803'. Install Western j I I ~ I, ~ I Wells super sliders according to plan. (Middle of bottom joint every ~ stand). Record PU and SO wts every 10 stands. j 02:15 - 02:30 I 0.25 DRILL CIRC j INTRMI ~ Pump dry job #2. Blow down top drive. 02:30 - 06:00 I 3.50 ~ DRILL ~ TRIP I INTRM1 ~ POOH w/ Weatherford 4" DP f! 12407 to 6806'. Install Western Wells Printed: 2/16/2006 4:03:41 PM ConocoPhil{ips Alaska Page 28 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1 C-20 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 'Date From - To ;Hours ' Code ', Code I' .Phase ' 12/24/2005 ~ 02:30 - 06:00 I 3.50 ~ DRILL ~ TRIP I INTRM1 106:00 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 18:00 j18:00-00:00 12/2512005 j 00:00 - 00:30 00:30 - 01:00 01:00 - 02:30 I 02:30 - 03:00 03:00 - 06:00 I ~ 06:00 - 10:30 10:30 - 11:00 11:00 - 11:45 11:45 - 12:00 ~~12:00-13:00 13:00 - 20:30 it 20:30 - 20:45 1120:45 - 21:00 21:00 - 22:00 ~ 22:00 - 00:00 12/26/2005 100:00 - 02:45 5.501 DRILL (TRIP 0.501 DRILL OTHR 1.00 LOG I PULD 5.00 LOG DLOG 6.00 ~ LOG I DLOG I 0.50 I LOG I I DLOG 0.50 LOG DLOG I 1.50 LOG I , DLOG I 0.50 LOG CIRC 3.00 ~ LOG ; ELOG 4.50 LOG i ELOG 0.50 ~ LOG ELOG 0.75 WELCT OTHR 0.25 WELCT OTHR 1.00 WELCTI ~ OTHR 7.50 WELCT BOPE 0.25 WELCTLOTHR 0.25 WELCTl10THR 1.00 DRILL I ~ PULD 2.00 ~ DRILL i PULD 2.75 ~ DRILL i PULD 02:45 - 03:15 03:15 - 04:15 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRMI INTRM1 INTRMI INTRMI INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRMI 0.501 DRILL ;PULD i INTRM1 1.001 DRILL I CIRC I INTRMI Spud Date: 11/21/2005 Start: 11/18/2005 End: 1/28/2006 Rig Release: 1/28/2006 Group: Rig Number: 15 Description of Operations super sliders according to plan. (Middle of bottom joint every stand) PU wt 140k, SO wt 100k, blocks 70k. Record PU and SO wts every 10 stands. POOH w/ Weatherford 4" DP ff 6806' to bit. Install Western Wells super sliders according to plan. (Middle of bottom joint every stand) PU wt 140k, SO wt 100k, blocks 70k. Record PU and SO wts every 10 stands. Break bit and bit sub. Clear and clean rig floor. PJSM. IUEEt Schlumberger king tools (SCMT} ~hlumberger. Overall StiA tet~h is 44.61'. RiH w/ Schlumberger logging tools (SCMT) on Weatherford 4" dp @ moderate rate f/ 44' to 9100'. Record PU and SO wts every 10 stands. PU wt 150k, SO wt 95k, blocks 70k @ 9100'. RIH w! Schlumberger logging tools (SCMT) on Weatherford 4" dp @ moderate rate f/ 9100' to 17527'. Record PU and SO wts every 10 stands. POOH w/ Schlumberger logging tools (SCMT) on Weatherford 4" dp f! 17527' to 17114'. Logging quality of cement, Speed of travel 25-30 ft per min. RIH w1 Schlumberger logging tools (SCMT) on Weatherford 4" dp f/ 17114' to 17527'. Moderate speed. POOH w/ Schlumberger logging tools (SCMT) on Weatherford 4" dp fl 17527' to 15990'. Logging quality of cement, Speed of travel 25-30 ft per min. Pump dry job @ 57 spm (5.7 bpm, 241 gpm) w/ 1750 psi. Blow down top drive. POOH w/ Schlumberger logging tools (SCMT) on Weatherford 4" dp f! 15990' to 9185'. Speed of travel 150 ft per min. PU wt 162k, SO wt 100k @ 9185'. POOH w! Schlumberger logging tools (SCMT) on Weatherford 4" dp f/ 9185' to surface..Speed of travel 150 ft per min. UD 44' Schlumberger tool string (SCMT). Pull FMC wear bushing. UD running/pulling tool. Clear and clean rig floor. Rig up to test BOPE. Fill stack and lines w/water Test ROPE. Test afl componenets to 250 psi low and 3500 psi high. Hold each test f/ 5 min. Test accumulator. Witness of test waived by AOGCC inspector John Crisp. Gas detectors and H2S detectors calibrated and tested. Rig down test equipment. Install FMC wear bushing, 7- 1116" ID, 10- 13!16" OD, 1.0' length. UD running tool. Blow down choke line, kill line and choke manifold. Bring 3- 1/2" IF mule shoe and 3 1/2" x HT 38 box crossover to floor. PJSM. Pickup and RIH w/ Weatherford 4" HT 38 drill pipe. (Total of 126 planned to be picked up). 25 jts picked up @ midnight. Pickup and RIH w! Weatherford 4" HT 38 drill pipef/ 788' to 3976' (Total of 126 planned ). 25 jts to 126 joints. Rabbit w/ 2.45" rabbit. Three super sliders were applied in pipe shed to last three stands picked up. Change out bad joint (Box) of Weatherford 4" HT 38, after trying to screw top drive saver sub (XT 39) into joint (HT38). Circ and condition mud w/ headpin and crossover. Flush drill pipe. Pump total of 403 bbls. Stagging pumps up to final of 13 bpm w/ 2000 psi. Circ @ highest rate shakers would handle- 6bpm = 600 psi. 10 bpm Printed: 2/16/2006 4.03:41 PM ConocoPhillips Alaska Page 29 of 57 Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1 C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLIN G Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours ' Code ~ Sub ', phase Code ' Description of Operations 12/26/2005 ~ 03:15 04:15 1 ~ 04:15 04:30 II 1 00 ~ DRILL 0 251 DRILL ~ CIRC ~ INTRM1 I OTHR iiI INTRM1 I 1200 psi. ~ Rig down and blow down circulating lines. 104:30 - 06:00 1.501 DRILL ~ TRIP I INTRM1 I POOH w/ 126 joints (42 stands) of Weatherford 4" HT 38 drill pipe f! j 06:00 - 06:30 ~ 0.501 DRILL I OTHR ~ INTRM1 3976' to surface. Break crossover and mule shoe. ~ Clear rig floor. ' 06:30 - 07:45 'I 1.251 RIGMN T~ RGRP INTRM1 I Change out saver sub on top drive, due to damage f/ screwing into ~ 11 ~, 07:45 - 08:00 ~ j 0.251 DRILL j I I SFTY I INTRM1 (wrong thread connection. ~ PJSM on picking up BHA #6. 108:00 - 10:15 I 2.25 I DRILL PULD I INTRM1 I PU/MU bit#6 (Security FSF 2641, ser # 10722272), Sperry Sun 4-3/4" I ~ I I II j ! 5200 series GeoPilot (ser # 024), Sperry Sun flex collar, MWD smart stab, directional prob, gamma/Res, PWD/Nuetron Density, TM-HOC. I i 10:15 - 11:15 .00 DRILL I I OTHR I INTRMI 1 Depth 110'. Upload Sperry Sun MWD. 11:15 - 12:00 I~ 0.751 DRILL 1, OTHR j INTRM1 ~ MU circ lines. Shallow test MWD. Good test. Rig down and blow down i ! i 12:00 - 12:15 ` I ~ 0.251 DRILL I ~ PULD ~I INTRM1 ~ i same. I MU welded blade stab, float sub, baker circ sub, one 4-314" nm flex ~ collar to 150' 12:15 - 12:30 II 12:30 - 13:00 I 0.25 ~ DRILL 0.50 DRILL ~ SFTY i INTRM1 I OTHR INTRM1 j PJSM on loading nuke sources w/ Sperry Sun. Load nuke sources w/ Sperry Sun. 13:00 - 13:30 I 0.50 ~ DRILL ~ PULD j INTRM1 I PU/MU 4-3/4" NM flex collar, two crossovers, Daily jars, two 4" HWDP, 13:30 - 15:45 ~ 2.251 DRILL ~ TRIP j INTRM1 I crossover to 280'. I Trip in hole w/ Weatherford 4" HT 38 dp f/ 280' to 3406' (33 stands), PU ~ I ~ ~ I I Daily mechanical jars, follow wl (2 stands) of Weatherford 4" HT 38 dp I I I I ~ jto 3627, PU/MU Accelerators to 3659.81'. 115:45 - 18:00 2.251 DRILL 1 TRIP I, INTRM1 1 Continue trip in hole w/ Weatherford 4" dp f/ 3660' to 9810'. Total of 100 ~ ~ ~ i ~ stands of Weatherford 4" HT 38 dp in hole w! BHA. Western Well Tools ~ ~ ~ super sliders start on stand # 40, which is 4115' above bit. Ran one per i j 18:00 - 19:45 I 1.75 ~ DRILL I I TRIP INTRM1 I stand on bottom single. PU wt 170k, SO wt 90k, blocks 70k @ 9810'. ~ Continue trip in hole w1 Weatherford 4" dp f/ 9810' to 10473'. Total of I 1 I i 1107 stands of Weathertord 4" HT 38 dp in hole w/ BHA, install j I ~ Weathertord crossover HT38 pin x XT 39 box, follow w/ 43 stands l f ~ I Weatherford 4" XT39 drill pipe to 14485'. Western Well Tools super I i sliders ran one per stand on bottom single from stand 40 thru 150, total j 19:45 - 21:00 ~ j I 1.251 RIGMNT~ RGRP j INTRM1 I of 111 in hole. Total of 150 stands dp in hole with BHA = 14489.12'. I Attempt to fill pipe and break circ. Work on bell guide f/grabs. 21:00 - 22:30 1 I 1.501 RIGMN T~ RSRV i INTRMI I Slip and cut 135' of 1-3/8" drilling line. Checked crown-o-matic. I 22:30 - 23:00 I 23:00 - 23:30 ~ 0.501 RIGMNTI RGRP INTRMI 0.50 j DRILL ~ OTHR j INTRM1 j Install grabber dies in top drive. MU top drive. Fill pipe. Test MWD @ 14485'. Pump @ 67 spm (283 j ~ I ~ ~ ~ gpm) w/ 3500 psi, 279 gpm w/ 3250 psi. Rotate @ 20 rpm breaking in ' ' I i f 23:30 - 00:00 0.50 j DRILL I ~ OTHR I INTRM1 ~ j geoPilot. PU wt 230k, SO wt 110k, blocks 70k @ 14485 . Blow down top drive. 12127/2005 it 00:00 - 01:00 I 1.001 DRILL I TRIP ! INTRM1 I Continue trip in hole w/ Weatherford 4" dp f! 14485' to 15702'. Total of i i i ~ ~ 107 stands of Weatherford 4" HT 38 dp in hole w/ BHA, Weatherford j I I 1 crossover HT38 pin x XT 39 box, follow w/ 56 stands Weatherford 4" i 1 ! I XT39 drill pipe to 15702'. Western Well Tools super sliders ran one per j 1 j j stand on bottom single from stand 40 to stand 163, total of 124. Total of ~ I ~ I j 1163 stands dp in hole with BHA. Mud running over top of drill pipe, float j not holding. 101:00 - 01:15 j ~ 0.25 j DRILL !CIRC i INTRM1 ~ i Fill pipe, Circ 60 bbls @ 287 gpm w/ 3600 psi. ~ 01:15 - 02:15 I 1.001 DRILL TRIP ! INTRM1 Continue trip in hole w/ Weatherford 4" dp ff 15702' to 17566'. Total of I ~ 107 stands of Weatherford 4" HT 38 dp in hole w/ BHA, Weathertord I I I I crossover HT38 pin x XT 39 box, follow w/ 76 stands Weatherford 4" II I ! 1 I j XT39 drill pipe to 17566'. Western Well Tools super sliders ran one per Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 30'of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1 C-20 Spud Date: 11!21!2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1!28!2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ' Hours ; .Code !Sub ~~ Phase ;Code Description of Operations -- - 100 ----_ 12/27/2005 ~ 01:15 - 02:15 I DRILL i TRIP INTRM1 stand on bottom single from stand 40 to stand 183, total of 144. Total of I I I I 02:15 - 02:30 I 0 25 ~ DRILL OTHR INTRM1 i j 183 stands dp in hole with BHA = 115702.5'. Ta cement on to of wi er lu MU to drive on stand # 184 s @ . j ~ I p p . g p p g 1757T with no rotation. With rotation tag @ 17575', no pump. Lay down I ~ ~ stand # 184. Total of 107 stands of Weatherford 4" HT 38 dp in the ~ j ~ I j hole, total of 77 stands of Weatherford XT 39, for a total of 184 stands. ~ j I I j I With 184 stands in hole, Western Well tool super sliders ran one per ~ ` ` ~ stand on bottom siongle start @ stand 40 and continue to stand 184 for ! .total of 145 in hole. 02:30 - 05:00 i 2.50 I, i, 05:00 - 05:30 I 0.50 05:30 - 06:00 ~ 0.50 I 06:00 - 07:00 j 1.00 07:00 - 12:00 j i j 5.00 12:00 - 12:45 I 0.75 12:45 - 14:45 2.00 14:45 - 16:00 1.25 I 16:00 - 18:00 i 2.00 I 18:00 - 21:30 I 3.50 21:30 - 21:45 I 0.25 21:45 - 00:00 12/28/2005 100:00 - 06:00 DRILL ~ CIRC ~ INTRM1 i I DRILL DEQT INTRM1 DRILL DEQT IINTRM1 I DRILL jl DEQT ~ INTRM1 DRILL i DRLG INTRMI DRILL DRLG ~ INTRMI DRILL I CIRC IINTRM1 DRILL ~ FIT ~ INTRM1 I DRILL CIRC ~ PROD DRILL I ~ ~ OTHR ~ PROD DRILL i GIRC I PROD 2.251 DRILL i DRLG 6.00 I DRILL I DRLG PROD PROD i Circ and condition mud @ 17566' prior to casing test. Circ @ 290 gpm w13950 psi, rotate @ 50 rpm, 12k ft Ib torque off bottom. PU wt 275k, SO wt 115k, rot wt 170k. Blow down top drive. Rig up to test 7-5/8" casing. Fill and flush lines. Close upper pipe rams. Pump @ 6 spm and test casing to 3800 psi w! 88 stnylces totaj puQ (t3:8t5 .Chart test. Record pressures for 30 min test of 7-518", 29.7ppf, BTC-m, L-80 casing. FC @ 17581', FS @ 17713'. Rig down test equipment. MU stand # 184, tag cement while rotating and pumping 290 gpm w! 3200 psi, drilling cement f! 17574', wiper plugs, FC @ 17581.5' - 17582.7', cement, FS @ 17712.0 '- 17713.5', rat hole to 17726'. Note: Found float equip 6' high w/ this 4" dp tally while rotating. Drilling 6-3/4" new hole f/ 17726' to 17746'. Drill w! 296 gpm (10.0 ppg LSND) wf 3200 psi, 70 rpm w! 14k ft Ib torque on bottom. PU wt 275k, SO wt 125k, Rot wt 150k. ADT .72 hrs. Circ and condition mud. 10 ppg, 45 vis. PuU tack inside Ming. RU to pet#orm FIT wt 1O ppg ntud. EMW 12.5ppg w/ 870 psi. ~ 6686.41' TVD (csg shoe). Displace 10.0 ppg LSND mud from well. Displace to 9.2 ppg flo pro. Displace @ 295 gpm w! 3100 psi. PU wt 275k, SO wt 125k, Rot wt 150k. Off bottom torque 9-10k ft Ibs w/ 40 rpm. Service top drive while clean under shakers and troughs in pits. Change shaker screens. Prepare to drill ahead w! 9.2 ppg FloPro. MU top drive. Record slow pump rates @ 17746' w/ 9.1+ FloPro mud. # 1 mud pump @ 20 spm w/ 1020 psi, 30 spm w/ 1280 psi. # 2 mud pump @ 20 spm w/ 980 psi, 30 spm w! 1280 psi. Directional drill 6-3/4" hole w/ Sperry Sun GeoPilot 5200 (ser # 024) f/ 17746'- 17838' (6601' TVD) (92') ART 2.08 hrs. Total hrs on bit = 2.80 hrs.Total hrs on jars = 72.73hrs, WOB 5-10k, 70 rpm's, pumping 272 gpm, 9.2-9.1 ppg mw, on bottom pressure 3100 psi, off bottom pressure 3080 psi, on bottom torque 10k ft/Ib, off bottom torque 9k ft/Ib, PU wt 230k, SO wt 122 k, Rot wt 150 k. ECD 11.6 ppg Directional drill 6-314" hole w/ Sperry Sun GeoPilot 5200 (ser # 024) f/ 17838'- 18188' (6579' TVD) (350') ART 3.4 hrs. Total hrs on bit = 6.2 hrs.Total hrs on jars = 76.13hrs, WOB 10-15k, 70-140 rpm's, pumping 272-305 gpm, 9.2-9.1 ppg mw, on bottom pressure 3100-3550 psi, off bottom pressure 3080-3520 psi, on bottom torque 10-13k ft/Ib, off bottom torque 9-10k ft/Ib, PU wt 230-250k, SO wt 122-120 k, Rot wt 150-152 k. ECD 11.66-12.0 ppg ii Note: PWD baseline was pertormed @ 17842'. Pump rate of 270 gpm, j 80 rpm w/ 11.76 ppg clean hole ECD. Pump rate of 270 gpm w! 140 rpm wf 11.76 ppg clean hole ECD. Pump rate of 320 gpm, 80 rpm w/ Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 31 of 57 .Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name; ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28!2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ~ Hours Code , Code l Phase Description of Operations 12/28/2005 00:00- 06:00 i 6.001 DRILL j DRLG ~ PROD ~ 11.9 ppg clean hole ECD. Pump rate of 320 gpm, 140 rpm e/ 12.04 ppg i I I i I clean hole ECD. 06:00 - 12:00 i 6.00 } i I I I I 12:00 - 13:15 i 1.25 13:15 - 14:45 j 1.50 14:45 - 16:00 ~ 1.25 16:00 - 18:00 2.00 DRILL DRLG PROD I I I I ~ I I I DRILL I DRLG ~ PROD DRILL ~ CIRC PROD I, I ~ DRILL I OTHR PROD DRILL I CIRC I PROD 18:00 - 18:30 ~ 0.50 j DRILL CIRC ~ PROD 18:30 - 20:00 j 1.501. DRILL TRIP I PROD 20:00 - 21:45 ~ 1.75 ~ DRILL ~ CIRC ~ PROD 21:45 - 23:45 I 2.00 23:45 - 00:00 0.25 12/29(2005 ~ 00:00 - 02:00 DRILL ~ TRIP ~ PROD DRILL CIRC PROD 2.00 i DRILL CIRC I PROD 02:00 - 02:30 ~ 0.50 i DRILL I TRIP I PROD 02:30 - 04:00 j 1.501 DRILL I CIRC I PROD 04:00 - 05:30 ~ 1.50! DRILL CIRC i PROD 05:30 - 06:00 I 0.50. DRILL TRIP I PROD Note: A 24.31 deg dog leg between 18150' and 18175'. Drop and turn left Directional drill 6-314" hole w/ Sperry Sun GeoPilot 5200 (ser # 024) f/ 18188'- 18496' (6588' TVD) (308') ART 2.66 hrs. Total hrs on bit = 8.86 hrs.Total hrs on jars = 78.79hrs, WOB 8-15k, 60-140 rpm's, pumping 305-292 gpm, 9.2-9.1 ppg mw, on bottom pressure 3400-3550 psi, off bottom pressure 3350-3520 psi, on bottom torque 10-12k ft/Ib, off bottom torque 9-10k ft/Ib, PU wt 250k, SO wt 120-123 k, Rot wt 155-160 k. ECD 11.77-11.96 ppg Directional drill 6-3/4" hole w/ Sperry Sun GeoPilot 5200 (ser # 024) f/ 18496'- 18589' (6587' TVD) (93') ART .68 hrs. Total hrs on bit = 9.54 hrs.Total hrs on jars = 79.47hrs, WOB 8-10k, 140 rpm's, pumping 300 gpm, 9.2-9.1 ppg mw, on bottom pressure 3570 psi, off bottom pressure 3250 psi, on bottom torque 10k ftllb, off bottom torque 8-9k ftllb, PU wt 230k, SO wt 120 k, Rot wt 160 k. ECD 12.06 ppg Losing tir . Lo~ipg •1 bpm (168gpm) w/pumping 7.14 bpm (300 gpm). Build mud volume. Mix 90 bbls 20ppb LCM pil using Mixll medium. Build mud volume. Mix 90 bbls 20ppb LCM pil using Mixll medium. Pump 59 bbls of 20 ppb LCM pill (Mix II medium). Pump @ 1.35 bpm (57gpm) w/ 1020 psi. Fluid loss f/ 0600-1800 hrs = 320 bbls Spot LCM pill, 30 ppb mixll. Displace out of drill string. POOH f/ 18589' to 17659' (inside casing). MU top drive. Circ, stagging pumps up f! 2 bpm w! 1000 psi to 3 bpm wl 1280 psi. Spot 78 bbls LCM pill consisting of 30 ppb Mixll med. Displace out of dp. Lost 42 bbls mud while pill (78 bbls) was exiting drill pipe @ 6bpm w/ 2520 psi, 36 bbls in annulus above bit. Open hole capacity is 39 bbls. While pumping/ spotting pill @ 2 bpm w! 1120 psi, pumping 120 bbl per hour, losing 47 bbls per hour (38% lost to hole) Blow down top drive. POOH f/ 17659' to 16822' (above LCM pill in annulus). Circ @ 16822'. Pump @ 7 bpm w/ 2970 psi. Pumped 105 bbls in 15 min. Lost 65 bbls in same time. Lost 62% of volume pumped to hole. ECD 10.84 ppg. Fluid loss f/ 1800- midnight = 246 bbls Total losses f/ day = 566 bbls. Circ @ 16822'. Pump @ 2 bpm w/ 1040 psi. Losing 40 bph. Losing 34% of volume pumped. Blow down top drive. Trip in hole fl 16822' to 17659' (csg shoe). Circ @ 17659'. Pump 1 bpm w/ 800 psi. Circ @ 17659'. Spot 93.6 bbl LCM pil{ w/ 40 ppb Mix II medium. Spot 10 bbls outside of bit. Lost 40 bbls to hole while pumping 93.6 bbls pill. 6-3/4" open hole volume 39 bbl. 53 bbls of pill in dp x csg annulus. Pump @ 2 bpm w/ 1000-1840 psi, final 6bpm wf 2700 psi. Blow down top drive.. POOH f/ 17659' to 17287'. PU wt 250k, SO wt Printed: 2/1612006 4:03:41 PM ConocoPhillips Alaska Page 32 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11121!2005 Event Name: ROT -DRILLING Start: 11118!2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number. 15 Date From - To ,Hours; Code ! Code li Phase. Description of Operations 12/29/2005 ~ 05:30 - 06:00 ~ 0.50 ~I DRILL ~ TRIP i PROD 125k 06:00 - 07:15 I I 1.25 , 07:15 - 09:30 I 2.25 I 09:30 - 12:00 ~ 2.50 12:00-13:15 ! 1.25 13:15-14:30 i I 1.25 i I 14:30 - 14:45 i 0.25 14:45 - 17:30 i 2.75 DRILL STRIP (PROD I DRILL i CIRC PROD f DRILL (TRIP PROD DRILL I DRLG I, PROD DRILL CIRC PROD I I I DRILL (TRIP PROD DRILL CIRC I PROD 17:30 - 18:30 1.001 DRILL TRIP I PROD 18:30 - 19:00 I I 0.50 19:00 - 20:15 1.25 I 20:15 - 21:00 ~ I 0.75 21:00 - 00:00 I 3.00 DRILL CIRC I PROD I DRILL Ij OBSV j PROD l ~ DRILL ~ CIRC ~ PROD I DRILL TRIP (PROD 12/30/2005 100:00 - 05:30 I 5.501 DRILL TRIP !PROD Note: Lost 190 bbls of mud to well f/ midnight to 0600 hrs. Total fluid lost to well @ 0600 hrs 756 bbls. Continue POOH f/ 17287' to 16259'. Pull above LCM in hole. (15 stands). PU wt 250k, SO wt 125k. Circ. Establish pump rates. Monitor losses. Pump @ 300 gpm w/ 3040 psi. Pump total of 5500 strokes. Total losses while pumping 554 bbls was 93 bbls. 17% of fluid pumped was lost to formation. Blow down top drive. Trip in hole f/ 16259' to 18589'. Ream last stand, no problems. Directional drill 6-3/4" hole w! Sperry Sun GeoPilot 5200 (ser # 024) fl 18589'- 18683' (6586' TVD) (94') ART 1.04 hrs. Total hrs on bit = 10.58 hrs.Total hrs on jars = 80.51 hrs, WOB 8-10k, 90 rpm's, pumping 277 gpm, 9.2-9.1 ppg mw, on bottom pressure 2950 psi, off bottom pressure ??? psi, on bottom torque 10-15k ftllb, off bottom torque 8-9k ft/Ib, PU wt 245k, SO wt 120 k, Rot wt 151 k. ECD 11.11 ppg Note: Losses while drilling were 120 bbls per hour. *"* As noted on 12/28/2005 report between the hours of 00:00 and 06:00 hrs, there is a 24.31 deg dog leg between 18150' and 18175'. Sperry Sun Tools failed while drilling this 94' of hole. Resistivity tools and no surveys. Will POOH to correct problem. Pump 90 bbl LCM pill. Pilf consisted of 40 ppb Mixll medium. Pump @ 280 gpm wf 3000 psi. Monitor losses. Log fault zone. Bit depth 18653' to 18683', spead of travel 1 fpm. Pumping @260 gpm w/ 4000 psi when LCM pill @ bit. POOH f/ 18683' to 18589'. Mud out of balance, flowing out of dp. Monitor well, Circ @ 2 bpm (20 spm,82 gpm) w/ 1030 psi. Once LCM pill near bit, increase rate to 6 bpm (60 spm, 253 gpm) Monitor losseslgains. Pushed 90 bbls away to formation Build mud volume. Mix 100 bbls LCM pill w140 ppb mix II medium. POOH f/ 18589' to 17659'. No problems. PU wt 268k. Note: Fluid losses f/ 0600 hrs to 1800 hrs are 485 bbls Total fluid losses to well @ 1800 hrs is 675 bbls. Circ @ 6.3 bpm (63 spm,266 gpm) w! 2560 PSI. Pump away 30 bbls of fluid. Blow down top drive. Monitor well. static. Mix and pump dry job while monitoring well. Pump 43 bbf dry job weighing 11.o ppg. Blow down top drive. UD one single. POOH f/ 17627' to 12716'. Record PU and SO weights every 10 stands. Calc fill @ 12716' = 29.15 bbls Actual fill = 30.28 bbls POOH f/ 12716' to 1345'. Record PU and SO weights every 10 stands. Record PU and SO wt's every 10 stands. Calc fill 98 bbls. Actual fill 150 bbls 6 bph losses over calculated. *****As noted on 12!2812005 report between the hours of 00:00 and 0:600 hrs. there is a 24.31 deg dogleg between 18150' and 18175'. Sperry Sun tools failed whiffle drilling f! 18589' to 18683'. Resistivity tools and no surveys. Change BHA to correct problem. Printed: 2/16!2006 4:03:41 PM ConocoPhillips Alaska Page 33 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/2812006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To I Hours I Code Sub ,phase Description of Operatiohs I'Code~ 12!3012005- -_~----------- _i____--_______________-__________-_____. __.__-_ 'i 05:30 - 06:00 0.50 ~ DRILL ;PULD PROD j UD 2 jts 4" Weatherford HWDP, jars, x-o and a flex DC. 06:00 - 07:00 I 1.00 07:00 - 09:00 ~ 2.00 09:00 - 09:30 0.50 09:30 - 11:15 1.75 11:15 - 11:45 I 11:45 - 12:00 0.50 0.25 12:00 - 14:45 i 2.75 I 14:45 - 15:45 1.00 15:45 - 16:30 I 0.75 16:30 - 16:45 ' 0.25 16:45 - 17:00 0.25 17;00 - 17:15 0.25 17:15 - 18:00. 0.75 18:00 - 19:30 j 1.50 19:30 - 00:00 ~ 4.50 12/31/2005 100:00 - 03:00 3.00 I j 03:00 - 03:45 0.75 I I 03:45 - 06:00 ! 2.25 06:00 - 06:30 06:30 - 11:00 DRILL ' SFTY ~ PROD DRILL {PULD PROD DRILL 1OTHR PROD DRILL ~ PULD PROD DRILL j OTHR PROD DRILL I SFTY PROD DRILL PULD PROD I DRILL I OTHR PROD DRILL ~ OTHR ,PROD DRILL PULD ~ PROD DRILL ~ SFTY PROD DRILL IOTHR PROD DRILL I PULD PROD I RIGMNT RGRP I I PROD DRILL iTRIP PROD DRILL -TRIP [PROD DRILL i CIRC PROD DRILL ~ TRIP ~ PROD 0.501 DRILL I PULD 4.50 it DRILL ~ CIRC I 11:00 - 11:30 j 0.50; DRILL ; SFTY 11:30 - 12:30 I 7.00 i DRILL i OTHR PROD PROD PROD PROD ~ Note: Fluid losses f/ midnight to 0600 hrs is 68 bbls. Total fluid losses to well are 1337 bbls @ 0600 hrs. ~ PJSM on removing nuke sources. Remove nuke sources. Lay down one 4-3/4" flex collar. Download I MW D. ,Flush BHA and geopilot skid w/ water. Blow down. ~ Lay down BHA # 6. I Clear and clean rig floor. PJSM on picking up BHA #7. PU/MU bit#7 (Security FSF 2641, ser # 10722272, w/ 3- 16's), Sperry ~ Sun 4-314" 5200 series GeoPilot (ser # TL009), Sperry Sun flex collar, MWD smart stab, directional prob, gamma/Res, PWD/Nuetron Density, I TM-HOC, Stabilizer w! corrosion ring. Depth 117.55'. (Upload Sperry Sun MWD. I MU circ lines. Shallow test MWD. Pump w/ 250 gpm 690 psi. Good test. Rig down and blow down same. I MU float sub, baker circ sub, one 4-3/4" nm flex collar to 151' PJSM on loading nuke sources w/ Sperry Sun, I Load nuke sources w/ Sperry Sun. PU/MU 4-3/4" NM flex collar, two crossovers, one Weatherford 4" j HWDP, Daily jars, two 4" HWDP, crossover to 310'. Note Fluid lost f/ 0600 to 1800 hrs is 70 bbls. ,Total fluid lost. to w~l ®! 1800 hrs is 1447 bbls. Trouble shoot top drive. Locking pin for handling ring. I RIH w/ BHA # 7 on Weatherford 4" dp to 7758'. PU wt 145k, SO wt ~ 105k. Total of 78 stands in hole @ midnight, total of 39 super sliders in hole ~ @ midnight. I Note: Fluid losses f! 1800 hrs to midnight is 54 bbls. (9 bph avg while tripping in hole. ~ Total fluid lost to well @ midnight is 1461 bbls. RIH w! BHA # 7 on Weatherford 4" dp f/ 7758' to 13118'. PU wt 200k, ISO wt 118k. Record PU & SO wt's every 10 stands. ~ Fill pipe. Establish circ rate and losses @ 2 bpm w/ 700 psi. Losses are 12 bph. ~ Continue RIH w! BHA # 7 on Weatherford 4" dp f! 13118' to 17654'. i PU wt 200k, SO wt 118k. Record PU & SO wt's every 10 stands. I Calculated isplacement 98 bbls, Actual displacement 41.9 bbls. ~ Averages 4.7bph losses. !Total fluid loss f/midnight to 0600 hrs= 61 bbls Total fluid lost to well is 1522 bbls @0600 hrs. PU single drill pipe f/ shed that was laid down prior to POOH. RU headpin to circulate. j Circulate, establishing circulation rates/pressures/losses. f/ 44 gpm to 250 gpm. Moitoring losses. Losses are 24 bph w/ 172 gpm w! 1400 psi. j 250 gpm w/ 2250 psi. I PJSM w/ dowel! on pumping MI product named Form-A- Set AK. I Establish injection rate @ 1.2 bpm w 500 psi, 1.5 bpm w/ 650 psi / 2 I bpm w/ 800 psi. Shut down, bleed off pressure. Dowell pump 5 bbl water, test lines to 3500, 10 bbls spacer, 100 bbls Printed: 2(16!2006 4:03.41 PM ConocoPhiHips Alaska Page 34 of 57 Opera#ions Summary Report' Legal Well Name: Common Well Name: ' Event Name: I Contractor Name: I Rig Name: l Date From - To, 12/31 /2005 j 11:30 - 12:30 I 12:30 - 13:30 I I I ~~ 13:30 -14:45 I 14:45 -18:00 18:00 - 18:30 J 18:30 - 20:30 I 20:30 - 22:30 22:30 - 23:00 I 23:00 - 00:00 I I I 1 /112006 100:00 - 00:30 00:30 - 02:15 102:15 - 06:00 i 1 I i 06:00 - 12:00 i i 12:00 - 15:15 I 3.251 DRILL I OTHR !PROD C-20 C-20 tOT - D )15CM( )oyon 1 Flours 1.00 1.00 1.25 3.25 0.50 2.00 2.00 0.50 1.00 0.50 1.75 3.75 6.00 BILLING ~conocophillip; i Code Sub ..Code DRILL ~ OTHR I DRILL OTHR DRILL ~ OTHR I DRILL OTHR I DRILL OTHR RIGMNT~ RSRV RIGMNT RGRP I DRILL ~ OTHR DRILL CIRC I I DRILL CIRC DRILL SURV DRILL OTHR I DRILL ~ OTHR Spud Date: 11/21/2005 Start: 11/1812005 End: 1/28/2006 ~.com Rig Release: 1/28/2006 Group: Rig Number: 15 Phase ' Description of Operations PROD Form-A-Set AK, 10 bbls spacer, then displace 75 bbls w/ 9.2 ppg FloPro mud @ 5 bpm.(2 bbls of spacer past bit.) PROD !Dowell slow rate to 1 BPM, Close annular, slowly close choke, allow squeeze pressure to stabilize (350 psi) and then increase injection rate Ito 2 BPM. Intial pressure 450 psi. Final circulating pressure 760 psi. SICP 750 psi. Final shut in casing pressure 730 psi. Bleed pressures off and open anular. Squeezed FAS pill 5 BBLS past bit. Approximately 165 BBLS of FAS paill squeezed away into leak point. PROD I Rig circulate drill pipe volume @ 301 gpm w! 2850 psi. Lost 15 BBLS while circulating to clean drillstring. MWD/LWD tools appear to be working after pill. PROD ~ Circulate, monitoring uses. Finat rate 49 gpm ur/ 550: psi. No kisses w/ 1 c~rculatigg. j Fluid lost f/ 0600 hrs to 1800 hrs = 266 bbls. Total fluid lost to well @ 1800 rs = 1788 bbls. PROD Rig down and blow down circulating lines. PROD MU top drive. circ @ 1 bpm w! 527 psi. Losses @ 4 bp. Slip and cut 108' of 1-3/8" drilling line. Inspect and service drawworks. Break out top drive. PROD Working to fix lock pin hyd cylinder f/ handling ring on top drive. Circ over top of hole. Losses are approx 1 bph. PROD 1 Blow air through choke and kill lines from previous use during squeeze. ~ PJSM on pumping and kick off planned @ 17950'. PROD Establish circ rate of 7 bpm, 71 spm (300 gpm) w/ 2950 psi. Losses are calculated @ 113 bbls (32 bbls loss in 17 min). Slow down to 1 bpm w/ ~ 600 psi. PROD Circ @ 1 bpm w( 600 psi. PROD I MU top drive. Casandra survey's @ 17,745', 17765', 17797' and 17816'. PROD ~ Troughing 6-314" OW f/ sidetrack plann~l @ 17950'. Start troughing @ 1.17900' tb f T95!}'. Pump&rg 293 gpm w! 2775 psi, ECD's 10.81 ppg. Rotate 100 rpm w/ 10k ft Ib torque. Note Fluid loss rate 27 to 36 bph. ~ Fluid lost f/ midnight to 0600 hrs = 203 bbls. Total fluid losses to well = 2052 bbls. PROD ~ Troughing 6-314" OH f/ sidetrack planned @ 17950'. Start troughing @ f 17900' to 17950'. Pumping 295 gpm w/ 2800 psi, ECD's 10.80 ppg. Rotate 100-130 rpm w/ 10k ft Ib torque. PU wt 240k, SO wt 125k, Rot wt 155k. 15:15 - 16:00 ! 0.75 16:00- 17:00. 1.00 17:00-17:30 I 0.50 17:30 - 18:00 ! 0.50 DRILL CIRC j PROD DRILL ITRIP (PROD DRILL ~ CIRC j PROD DRILL {TRIP PROD Fluid losses avg 25 bph. Troughing 6-3/4" OH f! sidetrack planned @ 17950'. Start troughing @ 17900' to 17950'. Pumping 295 gpm w/ 2800 psi, ECD's 10.80 ppg. Rotate 100-130 rpm w/ 10k ft Ib torque. PU wt 240k, SO wt 125k, Rot wt 155k. Geopilot not deflecting. Pump 40 bbl, 30 ppb LCM pill. POOH w/ BHA # 7 to PU motor w/ 1.5 deg bend f/ 17900' to 16820'. Geopilot not communicating. Monitor well. Pump dry job, blow down top drive. Continue POOH w/ BHA #7 to PU motor w/ 1.5 deg bend f/ 16820' to 16105'. PU wt 230k, SO wt 125k. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 35 of 57 Qperations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28!2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date :From - To 'Hours Code Sub ; .phase Code; Description of Operations 1/1/2006 117:30 - 18:00 j 0.501 DRILL j TRIP , PROD I Note: Fluid losses f/ 0600 hrs to 1800 hrs = 200 bbls I I I ~ Total fluid losses to well @ 1800 hrs = 2252 bbls. 18:00 - 18:45 I 0.751 DRILL TRIP PROD I, Continue POOH wf BHA # 7 to PU motor w/ 1.5 deg bend f/ 16105' to ( I 18:45 - 19:15 1 0.501 RIGMNT RSRV ~ PROD 114892'.. I Service top drive and crown. 19:15 - 00:00 I 4.751 DRILL TRIP ~ I ~ I ~ I PROD I Continue POOH w/ BHA #7 to PU motor w/ 1.5 deg bend f/ 14892' to ~ 3875'. 1/2/2006 100:00 - 02:00 ~ 2.00 I ~ I, 102:00 - 02:45 ' 0.75 I I I 102:45 - 03:00 j 0.25 I 103:00 - 03:45 I 0.75 03:45 - 04:15 0.501 04:15 - 05:30 I 1.25 i 05:30 - 06:00 I 0.501 06:00 - 07:00 I~ 1.00 07:00 - 08:00 I I I 1.00 1 08:00 - 08:45 0.75 08:45 - 09:15 I 0.50 09:15 - 10:00 I I 0.75 I I 10:00 - 12:00 ~ 1 2.00 12:00 - 18:00 ~ 6.00 DRILL I TRIP ;PROD DRILL ;TRIP f PROD DRILL ~ OTHR PROD DRILL OTHR PROD DRILL OTHR PROD DRILL PULD ~ PROD DRILL I SFTY PROD DRILL '~ PULD I PROD DRILL I OTHR I PROD DRILL CIRG PROD DRILL SFTY I PROD DRILL TRIP i PROD DRILL I TRIP I PROD DRILL (TRIP LPROD Fluid losses f/ 1800 hrs to midnight = 64 bbls Total fluid losses to well = 2316 bbls. Continue POOH w/ BHA #7 to PU motor w/ 1,5 deg bend f/ 3875' to 216'. PJSM on haandling BHA wJ nuke sources. Stand back (1) Weatherford 4" HWDP, (2) crossovers, (2) flex collars, circ sub, float sub and remove corrosion ring. Remove nuke sourcesfirom tools. Download Sperry Sun MWD. Flush BHA and GeoPilot skid w! water. Lay down Integral blade stabilizer, TM-Hang off collar, Security 6-3/4" FSF 2641 bit (ser # 10722272), Sperry Sun Geopilot 5200 (ser # TL09), Smart stabilizer and Geo-Pilot flex collar. Calculated fill on trip 103.55 bbls, actual fill 145.6 bbls. 42.05 bbls over calc= 3.2 bph losses while tripping. PJSM on picking up BHA #8 (Hughes 6-314" HCM 505z PDC bit, Sperry Sun motor w/ 1.5 deg bend). Fluid lost f/midnight to 0600 hrs = 38 bbls Total fluid lost to well = 2354 bbls PU BHA # 8. MU Hughes 6-3/4" HCM 505z PDC bit (ser # 7005515), Sperry Sun 5" OD motor 617-6.0 with ABI w/ 1.50 deg bend (ser # 500035), terminating sub, diirectional probe, GR/RES, PWD, Nukes, HOC. Start uploading tools @ 0700 hrs. Upload MWD tools. Float sub, baker circ sub, MU crosovers to be able to shallow test tools after downloading. Start uploading tools @ 0700 hrs. MU crosovers to be able to shallow test tools after downloading. PJSM on loading nuke sources. Load sources. PU/MU stand w/Float sub, baker circ sub, 2 flex collars, 2 Weatherford crossovers, one 4" Weatherford HWDP. Then astand w/ Daily jars and two 4" Weatherford HWDP. Then a crossover to 305'. RIH w/ 33 stands of Weatherford 4" dp w/ HT38 connections„ Daily jars, 2 stands more HT 38 dp, then accelerators to 3686.89'. Record PU and SO wt's every 10 stands. Fill pipe @ 30 stands. Con't RIH w/ Weatherford 4" dp w/ HT38 connections, total of 107 stands HT38 ,then crossover and follow w/ 4" XT 39 dp to 14610'. Record PU and SO wt's every 10 stands. Calc displ on trip in 79.5 bbls, actual 45.8 bbls, 33.7 bbls less in 12 hrs= 2.8 bph losses. j Total fluid loss f/ 0600 to 1800 = 81.5 bbl 1 I Total fluid lost to well @ 1800 hrs = 2435.5 bbls 18:00 - 20:00 I 2.001 DRILL I TRIP ~ PROD ~ Con't RIH wf Weatherford 4" dp w/ XT 39 connections f/ 14610' to 1 j 17686'. Record PU and SO wt's every 10 stands. PU wt 285k, SO wt I I ~ ! 1120k. Printed: 2/16/2006 4:03:41 PM ConocaPhillips Alaska Page 36 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1 C-20 Spud Date: 11121!2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ~ Hours ;Code ,Code ; Phase Description of Operations. - 1/2/2006___20:00-21:45 ___ 175---- I ~ DRILL i CIRC i _--_ PROD ~-_---_- _------------ -- ---____----- I MU top drive, circ and monitor loses @ 1 bpm w/ 500 psi = 14-15 bph 121:45 - 22:00 1 ~ I 251 DRILL TRIP 0 PROD ~ losses. Pumping 7 bpm w/ 2850 psi = 30 bph losses RIH f/ 17686' to 17900' 122:00 - 22:15 . 0.251 DRILL CIRC I PROD . j MU top drive. Record SPR's and survey, orient motor. ' ' 22:15 - 23:15 1.00 ~ DRILL I OTHR ~ PROD I Trough f/ 17900; . 300 gpm w/ 2800 psi. to 17950 23:15 - 00:00 0.75 ~ DRILL j OTHR j PROD ~ Time drill f/ 17930' to 17931'. Pump 395 gpm w/ 2750 psi. Losses are f ~ ~ ~ approx 30 bph. 1/3/2006 '100:00 - 06:00 I I I I 6.00'1 DRILL ~ I I I 06:00 - 12:00 ~ ~ I I ~ 6.00 j DRILL I 12:00 - 15:30 3.50 ~~ DRILL OTHR j PROD ii OTHR PROD I DRLG (PROD 15:30 - 18:00 I 2.50 DRILL j DRLG PROD 18:00 - 00:00 6.00 DRILL i DRLG Note:Total fluid loss f/ 1800 hrs to midnight = 125.5 bbls. Total fluid lost f/ day = 245 bbls Total fluid lost to well = 2561 bbls. Time drill f/ 17925' to 17927' (TVD = 6597'). Pumping 295 gpm w/ 2700 psi. PU wt 225k, SO wt 120k. Avg losses are 22.5 bph. Note: fluid lost f/ minight to 0600 hrs = 135 bbls Total fluid lost to well = 2696 bbls. Time drill f/ 17927' (TVD = 6597') to 17950 .Pumping 288 gpm w/ 2685 psi. PU wt 225k, SO wt 120k. Avg losses are 24 bph. Drill from 17950 to 17963' (TVD = 6580) Slowly increasing weight to estibish sidetrack. Drill from 17693 to 18056' (TVD = 6580') AST = 4.47 hrs // ADT = .29 hrd // bit hrs = 5.22 Jar S/N 1471-0019 = 5.22 hrs Jar S!N 1471-0044 = 85.73 hrs Accelerators # 1447-1001 = 85.73 hrd Pumping @ 284 gpm = 2850 psi on bottom / 2670 psi off bottom. Up weight = 225,000# Down weight = 125,000# Rotating weight = 160,000# Torque @ 50 rpm = 5,000 FT# off bottom 10,000ft# on bottom ECD's = 10.6 ppg while rotating. Pumped 3 x LCM pill 30 bbl's each @ 30# /bbl Fluid loss 06:00 - 12:00 = 174 bbls Losses from 12:00 = 18:00 = 165 bbls Total losses 06:00 - 12:00 = 339 bbls Total losses to well = 3059 PROD j Drill from 18056' (TVD = 6580') to 18346' MD (6581' TVD) }AST = 1.54 hrs // ADT = 3.95 hrd !! bit hrs = 8.67 ~ WOB = 8-10,000# -Jar S/N 1471-0019 = 8.67 hrs Jar S/N 1471-0044 = 89.68 hrs Accelerators # 1447-1001 = 89.68 hrs I Pumping @ 300 gpm = 3000 psi on bottom / 2850 psi off bottom. Up weight = 230,000# Down weight = 120,000# ~~ Rotating weight = 155,000# Torque @ 80 rpm = 9,000 FT# off bottom 9-10,000ft# on bottom ~ 200 units maximum gas 65 units background gas ~ ECD's = 10.6 ppg while rotating. Losses = 20 -30 bph Printed: 2!16/2006 4:93:41 PM ConocoPhillips Alaska Page 37 of 57 Opera#ions Summary Report Legal Well Name: 1C-20 Common Weli Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 1!312006 'From - To Hours ' Code 'Sub ~, Phase Description of Operations ;Code; ~ 18:00 - 00:00 II 6.00 DRILL I DRLG i PROD II Losses from 18:00 = 00:00 = 141 bbls j ~ Total losses past 24 hours =639 bbls ~ ~ ;Total losses to well = 3200 bbls 1!412006 100:00 - 06:00 06:00 - 07:00 6.00 DRILL I DRLG PROD Drill from to 18346' MD (6581' TVD) to 18,504' (6575" TVD) AST = 1.24 hrs !/ ADT = 1.52 hrd /! bit hrs = 11.43 WOB = 8-10,000# Jar S/N 1471-0019 = 11.43 hrs Jar S/N 1471-0044 = 91.94 hrs Accelerators # 1447-1001 = 91.94 hrs Pumping @ 295 gpm = 3000 psi on bottom / 2850 psi off bottom. Up weight = 225,000# Down weight = 118,000# Rotating weight = 155,000# Torque @ 75 rpm = 9,000 FT# off bottom 9-10,000ft# on bottom 200 units maximum gas 65 units background gas ECD's = 10.6 ppg while rotating. Losses = 20 -30 bph Losses from 00:00 - 06:00 = 146 bbls Total losses past 24 hours =639 bbls Total losses to well = 3346 bbls PROD I Drill from to 18,504' (6575" TVD) to 18,520' MD (6574' TVD) ~ Bit hrs = 12.31 Pumping @ 295 gpm = 3000 psi on bottom ! 2850 psi off bottom. j Up weight = 225,000# Down weight = 118,000# I Rotating weight = 155,000# ~ Torque @ 75 rpm = 9,000 FT# off bottom 9-10,000ft# on bottom 1200 units maximum gas 65 units background gas 1.00 07:00 - 08:30 i 1.50 i I I 08:30 - 12:00 ~ 3.50 DRILL I DRLG ORDR DRILL I DRLG PROD ~ Waiting on orders from town to drill ahead and ! or evaluate geology I and well profile. Circulate @ 270 gpm while rotating PROD ~ Drill from to 18,520' MD (6574"TVD) to 18594' MD (6576' TVD) AST = 2.36 hrs /! ART = .89 hrs !/ADT = 3.25 hrd !! Bit hrs = 14.68 I WOB = 8-10,000# ~ Jar S/N 1471-0019 = 14.68 hrs Jar S/N 1471-0044 = 95.83 hrs Accelerators # 1447-1001 = 95.83 hrs Pumping @ 295 gpm = 3000 psi on bottom / 2850 psi off bottom. I Up weight = 230,000# Down weight = 120,000# Rotating weight = 155,000# Torque @ 75 rpm = 9,000 FT# off bottom 9-10,000ft# on bottom ECD's = 10.58 ppg while rotating. Losses = 20 -30 bph 12:00 - 14:00 ~ 2.00 i DRILL 'I DRLG ~ PROD ~ Drill from to 18594' MD (6576' TVD) to 18641' MD (6582' TVD) j AST = .27 hrs // ART = ,79 hrs // // Bit hrs = 15.74 I I j I ~ WOB = 8-10,000# i ! ~ ~ Jar S!N 1471-0019 = 15.74 hrs Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 38 of 57 Opera#ions Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11J21J2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours Code Code I' Phase ' Description of Operations 1!4!2006 j 12:00 - 14:00 I 2.00 i DRILL DRLG ~ PROD ~ Jar S/N 1471-0044 = 96.25 hrs I Accelerators # 1447-1001 = 96.25 hrs j I it ~ I Pumping @ 300 gpm = 3350 psi on bottom / 3200 psi off bottom. I ~ ~ Up weight = 230,000# ~ I I ~ Down weight = 120,000# Rotating weight = 155,000# ~ Torque @ 75 rpm = 9,000 FT# off bottom 9-10,000ft# on bottom. i I I I i Increase in losses at 18641' // reduction in return flow and ECD's 14:00 - 16:30 j 2.50 I 16:30 - 18:00 i 1.50 DRILL j CIRC PROD DRILL ~ DRLG I PROD 18:00 - 19:00 i 1.00 DRILL I I I ~ 19:00 - 21:15 ~ 2.25 i DRILL 21:15 - 21:30 i 0.25 I 21:30 - 22:00 ~ 0.50 22:00 - 23:30 ~ 1.50 23:30 - 00:00 CIRC !.PROD WIPR I PROD DRILL ~ OBSV PROD DRILL !WIPR I PROD DRILL i CIRG i PROD 0.501 DRILL I WIPR i PROD 1/5/2006 100:00 - 00:15 I 0.25; DRILL I TRIP ;PROD Circulate 40 bbl LCM pill @ 45 #/bbl LCM. Monitor losses. Loosing from 120 bph to 90 BPH. Drill from to 18641' MD (6582' TVD) to 18708' MD (6578 ' TVD) AST=.O hrs l/ ART=.77hrs////Bit hrs=16.51 WOB = 8-10,000# Jar S/N 1471-0019 = 16.51 hrs Jar S/N 1471-0044 = 97.02 hrs Accelerators # 1447-1001 = 97.02 hrs Pumping @ 300 gpm = 3350 psi on bottom / 3200 psi off bottom. Up weight = 230,000# Down weight = 120,000# Rotating weight = 155,000# Torque @ 75 rpm = 9,000 FT# off bottom 9-10,000ft# on bottom. Drill past loss section. ECD's = 10.73 ppg while rotating. Losses = 20 -30 bph Losses from 06:00 - 12:00 = 160 bbls Losses from 12:00 - 18:00 = 456 bbls Total losses past 24 hours =616 bbls Total losses to well = 3962 bbls Pump 25 bbl's 45 ppb LCM pill. Change trouble time from BHA to hole conditions after passing depth of last BHA trouble, 18683'. Pull to casing shoe and circulate at drilling rate to squeeze away pill with ECD pressure @ 300 GPM Losses @ 120 - 150 BPM Lost 45 bbl pill in 7 minutes. Reduce flow arte to 100 gpm and monitor losses. Losses at 20 - 45 BPH. Monitor well with no pumps. Well static, fluid not dropping or flowing back. Trip in hole to lost depth 18641' to spot LCM pill. Break circulation at 280 GPM 3200 psi Pressure higher than before, Pump 45 bbls of LCM pill at 45#/bbl Displace with 2050 stks to clear LCM pill of BHA. POH to circulate and squeeze LCM pill with ECD's Daily losses = 944 bbls Total losses to well = 4144 bbls Continue to POH from 18782 to 17686 at 7 5/8" casing shoe to spot Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Page 39 of 57 Legal Well Name: 1C-20 Common Wel{ Name: 1C -20 Spud Date: 11/21!2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D1 5CM@conocophillips.com Rig Release: 1128!2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ', .Hours ' Code 'Sub ;phase iCode ' Description of Operations 1/5/2006 ~ 00:00 - 00:15 II 0.25 DRILL TRIP i PROD I and squeeze form-a-set pill. 00:15 - 03:00 2.7511 DRILL CIRC I PROD I j Circulate 2 300 GPM to squeeze away 45 ppb Icm pill spotted om 1 j bottom. ~ ~ ~ ~ ~ Losses 100 - 120 bph at 300 gpm got 40 bbls ! i ~ I ~ Reduce flow to 100 gpm l 870 psi fosses reduced to 20 - 30 bph. i 03:00 - 03:30 ~ 0.50 DRILL I LOT PROD I Waiting on Form-a-set pill and trucks. I Shut in well with bag and estibilis injectionat 1 bpm = 480 psi U 2 bpm = I I I ~ 620 psi. j ! I I I Shut down pumps and estibilish static pressure to 320 psi in 5 minutes. I ~ 03:30 - 04:00 I I 0.50 DRILL ~ I CIRC I PROD I Bleed down and open bag, b{ow down top drive and ki0 lines. I ~ 104:00 - 04:30 1'I I 0.501 DRILL I SFTY PROD I PJSM to mix and pump MI Form-a-set 100 bbls LCM treatment. I j 04:30 - 05:00 11 I 0.50 I DRILL I SFTY PROD Dowell pump 5 bbls fresh water and test lines to 3500 psi. 05:00 - 05:30 11 0.50 DRILL CIRC ~ PROD ~ Dowell pumped 10 bbls hi-vis spacer, 100 bbls foraset LCM treatment, f I ~ 10 bbls hi-vis spacer. j 05:30 - 06:30 ~ 1.001 DRILL CIRC PROD Dowell displace with 66 bbls fresh mud directly from truck. j i i Close bag and choke and begin to squeeze. ~ ! ~ i I @ 66 bbls displacement start squeeze. X66 I ~ 06:30 - 08:00 i 1.50 DRILL CIRC PROD I 178 bbls displace, open bag and circulate at 266 gpm 2125 psi. 1 i ~ I Squeezing away 30 bbls form-a-set from bit depth @ 17686 to 17950. I j Reduce pump rate to balance losses to 80 gpm. ~j j 1 ~ ~ ~ ~ ~ 1 Pump till 32 additional bbls squeezed into zone. ~ Reduce pump rate to 1 bpm f ~ ~ ~ ~ We11 static with 32 bbls squeezed into well since annular was opened. I I I ~ I I 142 bbls in open hole volume, leaving +/- 10 bbls in open hole. I 08:00 - 10:30 ~ 2.50 DRILL CIRC j PROD j Circulate @ 42 GPM 490 psi. Monitoring losses @ 30 bbls. Well static ~ 10:30 - 11:45 ~ I I 1.25 DRILL I 1 OBSV PROD ~ as circulated. I Monitor well for losses. i j I Gave back 3 bbls fluid. Well became static, ~, i i I ~ Pump dry job and blow down top drive. ~ 11:45 - 18:00 6.25 ~ DRILL ~ TRIP PROD I Pull out of hole from 17686 to 491 T Estibilish up and down weight I f ~ I every 10 stands I I ~ ~ ~ @ 17330 = 245 up / 125 down i I 18:00 - 21:30 1 I 3.50 i DRILL I I I TRIP i PROD I Hole taking correct fill on trip, I POH from 4917 to BHA. ~ ~ 21:30 - 00:00 j 2.5Q . DRILL PULD I PROD Handle BHA. Pull nukes, down load MWD and drain motor. Lay down I 1 ~ MWD tools. ~ I I ~ I I Total fluid lost to well 1!5 = 296 bbls 1 includes 120 bbls squeezed with 1 j form-a-set treatment. Total fluid lost to well = 4440 bbls 1/6!2006 00:00 - 00:15 I 0.251 DRILL PULD PROD I Continue to down load MWD data. 100:15 - 01:30 j 01:30 - 02:00 I 1.25 I DRILL 50 ~ DRILL 0 I PULD I PROD ~ PULD I PROD ~ Lay down MWD tools to pipe shed. i Break off bit and lay down mud motor 102:00 - 03:00 I . 1.00 j DRILL ~ PULD ~ PROD . !Pull wear rig and install test plug. 03:00 - 04:00 j 1.00 ~, WELCTL~ BOPE i PROD j Rig up test pump and hoses to test BOP's ~ ~ 04:00 - 08:45 ' I ~ 4.75 ~ I ~ WELCTy BOPE i PROD ~ i I Bop test witness waived by AOGCC Chuck Shieve ~1 Test BOP"s 250 low // 3500 psi high I Hydrill, HCR, Likk, Choke, Upper , I BOP, XT39 TIW, Upper rams, Printed: 7J16l2006 4:03:41 PM ConocoPhiflips Alaska Page ao of 57 Opera#ions Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11118/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 1 /6/2006 1 /7/2006 From - To Hours Code Sub ,Code.. 04:00 - 08:45 I j 4.75 ~ WELCTIJ BOPE I ~' I 08:45 - 10:30 ~ f I 1.75 ~ WELCTI~ BOPE 10:30 - 16:45 ~ I 6.25 ~ DRILL PULD I 16:45 - 18:00 ~ ~ 1.25 ~ DRILL i TRIP I 18:00 - 00:00 ~ I I 6.00 j DRILL j TRIP j I I I 00:00 - 03:15 ~ I I I 3.25 j DRILL i TRIP 03:15 - 03:45 0.50 ~ DRILL CIRC I ~ ~ 03:45 - 06:00 ~ ~ I 2.25 RIGMNT~ RSRV I 06:00 - 07:15 ~ I I I 1.25 ~ RIGMNT~ RSRV 07:15 - 09:00 ~ I 1.75 DRILL i TRIP 09:00 - 11:00 ~ f 2.00 ~ LOG ~ CIRC 11:00 - 18:00 ~ ~ I ~ I ~ ~ i 7,00 }DRILL ~ DRLG ~ I I ~ I ~ j I I ~ I j ~ I 18:00 - 00:00 ~ 6.00 DRILL !DRLG Phase PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD Manual Kill, Choke manifold! valves, H7 39 dart valved did not test, Called Weatherford to replace. Hold each test f/ 5 min. Test accumulator. Witness of test waived by AOGCC inspector Chuck Shieve. Gas detectors and H2S detectors calibrated and tested. Pull test plug install wear ring and blow down top drive/ ckoke & kill lines. Pick up MWD tool , geopilot and bit, Test and up load MWD .Troubles communicating with MWD. Load nuke sources and surface test. Pick up NMFDC's and remaining BHA. Trip in hole with drill ppe from derrick from 375 to 1988'. Take up and down weight every 10 stands. Test HT 38 dart valve that arrived from weather to complete BOP test. Continue to run in the hole from 1988 to 11717' fill 25 stands and take up and own weight every 10 stands for torque and drag. Hole not taking any fluid on trip in. Hole has trot taken any fluid in'past 24 hours. Total fluid last to Weil 4440 bbls. Continue to trip in hole from 11717 fo 17713 at 7 5/8" casing shoe. Fill pipe every 25 stands and estibilish up and down weight every 10 stands for torque and drag. Circulate staging up pump rate to check losses. 100 gpm = 650 psi no losses! 150 gpm = 950 psi no Iosses11200 gpm = 1420 psi slight loss. 250 gpm 1910 psi 45 bph loss rate for 5 minutes. Reduce pump rate to 100 gpm. Circulate at 100 GPM 650 psi. Slip and cut drill line while circulating. Also working on mud pump #1 drive sproket. Circulate at 100 gpm = 650 and service top drive and rig. Increase flow rate and check MWD toold and down link to geopolit. Trip in open hole from 17713 to 18435. Up weight = 250,000# down weight = 110,000# Madd pass for addition log data with MWD from 18435 to 18708. Pumping at 250 gpm with losses at 20 - 45 bph. Drill with Geopilot from 18708 to 19130' MD (6581' TVD) ART = 3.99 hours and bit hours 3.99 hrs. Up weight = 255,000# Down weight = 120,000# Rotating weight = 162,000# Torque on bottom 10 - 12,000ft# // Torque off bottom = 8 - 10,000ft#. Pumping 300 GPM = 2450 psi. ECD's average 10.52ppg Jar hours SN 1471-0019 = 20.46 !/ S/N 14710044 = 100.971/ Accelerators # 14471001 = 100.91 hrs Losses 06:00 - 12:00 = 153 bbls losses 12:00 - 18:00 = 296 bbls Total losses to well 4889 bbls. PROD i Drill with Geopilot from 19130' MD (6581' TVD) to 19489' MD (6590" i TVD) ~~ART = 3.47 hours and bit hours 7.42 hrs. Up weight = 245,000# Down weight = 110,000# Rotating weight = 160,000# ~ Torque on bottom 12 - 13,000ft# /J Torque off bottom = 10 - 11,000ft#. ~ Pumping 295 GPM = 2400 psi. ECD's average 10.6 ppg Description of Operations Printed: 2116!2006 4:03:41 PM ConocoPhillips Alaska page 41 of 57 Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1 /2 812 0 0 6 Group: Rig Name: Doyon 15 Rig Number: 15 Date 1/7/2006 1 /8/2006 `From - To ' Hours i Code Sub ~ phase Code Description of Operations _ _ _ _ _ _ 18:00-00:00__._ `_______-_'--- -- 1 6A0 ~ DRILL I DRLG ~ PROD ---- ----------_---- ------- ~ Jar hours SN 1471-0019 = 23.9311 S/N 14710044 = 104.44 // ~ ~ I Accelerators # 14471001 = 104.44 hrs l I Losses 20 - 60 bph Treating with LCM sweeps @ 40 ppb I i j I Total daily losses = 623 bbls I j ~ ~ Total losses to well = 5063 bbls I I I ~ 00:00 - 06:00 I 6.001 DRILL DRLG PROD I, Average 46 BPH since drilling started. I Drill with Geopilot from 19489' MD to 19844" MD (6586' TVD) ~ ~ I I ~ ART = 3.96 hours I I I Torque @ 120 RPM: on bottom 10 - 13,000ft# // Torque off bottom = 8 - I ~ ~ ~ 10,000ft#. ~ I Pumping 290 GPM = 2650 psi. j I. - ~ Up weight - 265,000# Down weight = 103,000# Rotating weight = 1158,000# !I I I i I ECD's average 10.52ppg ~ I j ~ % j Jar hours I I I , ~ SN 1471-0019 = 27.89 hrs ~ J I ~ S/N 14710044 = 108.40 hrs ~ j ~ ~ I IAcceeerators # 14471001 = 108.40 hrs ~ I I Losses 00:00 - 06:00 = 270 bbls i j ~ i I, Average losses per hour for past six hours = 45 bph 06:00 - 18:00 ART = 8.85 hours and bit hours 20.23 hrs. Up weight = 265,000# Down weight = 105,000# Rotating weight = 158,000# Torque @ 120 RPM: on bottom 14 - 15,000ft# // Torque off bottom = 10- 11,000ft#. Pumping 290 GPM = 2650 psi. ECD's average 10.79ppg Jar hours SN 1471-0019 =36.74 hrs S/N 14710044 = 117.25 hrs Accelerators # 14471001 = 117.25 hrs Gas = 50 - 250 units Losses 06:00- 18:00 = 454 bbls Average losses per hour for past twelve hours = 48 bph Total losses to well = 5333 bbls Treat with LCM directly into system at 1 sack per minute. 18:00 - 23:30 12.00 5.50 DRILL !DRLG DRILL f DRLG PROD PROD Drill with Geopilot from 19844" MD (6586' TVD) to 20205, MD (6596' ~ Drill with Geopilot from 20205, MD (6596' TVD) to20577" MD (6613' II TVD) ART = 3.53 hours and bit hours 23.76 hrs. ~ Up weight = 265,000# Down weight = 107,000# Rotating weight = 158, 000# Torque @ 120 RPM: on bottom 13 - 14,000ft# /1 Torque off bottom = j 11- 12, OOOft#. I Pumping 290 GPM = 2650 psi. II ECD's average 10.79ppg climbed to 11.4 ppg @ 20577_ 1 Jar hours ~ SN 1471-0019 =40.27 hrs S/N 14710044 = 120.78 hrs Printed: 2!16/2006 4:03:41 PM ConocoPhillips Alaska Page 42 of 5~ Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11!21!2005 Event Name: ROT -DRILLING Start: 11!18/2005 End: 1!28!2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ~ Hours ~ Code '; Sub ,phase Description of Operations !Code, , 1/8/2006 j 18:00 - 23:30 5.501 DRILL i DRLG j PROD i Accelerators # 14471001 = 120.78 hrs j I j Gas = 40 -160 units j ~ j [Losses 18:00 to 24:00 = 226 bbls j I j Average losses per hour for past twelve hours = 38 bph ~ ~ !Total losses last 24 hours 950 bbls ~ Total losses to well = 6013 bbls j I ~ I Treat with LCM directly into system at 1 sack per 2 minute. I ! I i li MWD tool flat lined at 23:30 ~ I Pumped 25 bbls water and surged tool 3 times to revive. I j MWD tool working again. 23:30 - 00:00 0.501 DRILL i CIRC 1 /9/2006 i 00:00 - 06:00 06:00 - 12:00 6.00 6.00 DRILL I DRLG DRILL I DRLG PROD PROD Reduced LCM treat to directly dumping into system at 1 sack per 2 minute. Work drill string to decreased ECD;s from 11.3 PPG to 10.42 Circulate and surge drill pipe by starting pumps quickly and started MWD tool after flat line. MWD tool flat lined at 23:30 Pumped 25 bbls water and surged tool 3 times to revive. MWD tool working again. Total losses last 24 hours 950 bbls Total losses to well = 6013 bbls Increased flow arte to 300 GPM and RPM to aid in hole cleaning. Losses stayed at 30 - 60 BPH and seam to be decreasing with reduced ECD's and increased flow rates. Watching carefully. Drilling with Geopilot from 20577" MD (6613' TVD) to 20791' MD (6613' TVD) ART = 3.85 hours and bit hours 2761 hrs. Up weight = 260,000# Down weight = 110,000# Rotating weight = 160, 000# Torque @ 120 RPM: on bottom 13 - 14,000ft# /1 Torque off bottom = 11- 12, OOOft#. Pumping 298 GPM = 3290 psi. Pump pressure up. ECD's average 10.6 - 11 ppg climbed to 11,2 ppg Jar hours SN 1471-0019 =44.21 hrs S/N 14710044 = 124.63 hrs Accelerators # 14471001 = 124.63 hrs Gas = 25 - 137 units Losses 18:00 to 24:00 = 226 bbls Average losses per hour for past twelve hours = 44 bph Total losses last 6 hours 264 bbls Total losses to well = 6277 bbls PROD !Drilling with Geopilot from 20791' MD (6613' TVD) to 21045' MD (6644' j TVD) BART = 3.78 hours and bit hours 31.39 hrs. Up weight = 250,000# Down weight = 100,000# Rotating weight = 1160,000# Torque @ 120 RPM: on bottom 13 - 14,000ft# !f Torque off bottom = 11- 12,000ft#. Pumping 286 GPM = 3210 psi. Pump pressure up. ECD's average 10.6 - 11 ppg Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 43 ofi 57 Operations- Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1J28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ' Hours ' Code Code I~ Phase ,Description ofi Operations 1/9/2006 06.00 - 12:00 _ __ _ _ _ _ _ _ :_.__ __ _ _ ._ _ - _- _ _. _ _ __ _ ._ _ _ ___ _ - _- . _ __ -- - _ _ _ -_ - 6.00 DRILL DRLG ~ PROD ~ Jar hours I I, SN 1471-0019 =47.90 hrs I. ~ S/N 14710044 = 128.41 hrs ~ I ~ ~ Accelerators # 14471001 = 128.41 hrs ~ ~ Gas = 25 - 80 units 12:00 - 12:45 I 0.751 DRILL DRLG !PROD 12:45 - 14:15 ~ 1.50 ~ DRILL I DRLG ~ PROD 14:15 - 15:00 i 0.75 DRILL I CIRC i PROD 15:00 - 16:00 j 1.00 ~ DRILL CIRC PROD 16:00 - 18:00 I 2.00 DRILL WIPR PROD II 18:00 - 21:15 i I 3.25 i DRILL WIPR PROD 21:15 - 21:30 ~ 0.25 ~ DRILL I I OBSV PROD 21:30 - 23:00 ~ 1.50 ~ DRILL ~ CIRC f PROD 23:00 - 00:00 I 1.00 i DRILL I CIRC i PROD 1/10/2006 100:00 - 00:15 00:15 - 00:30 00:30 - 02:15 02:15 - 02:30 02:30 - 06:00 0.25 i DRILL I CIRC I PROD j I I 0.25 ~ DRILL OBSV j PROD 1.75 ~ DRILL I WIPR PROD 0.251 DRILL I ~ I i OBSV j PROD i 3.50 ~ DRILL I I CIRC I PROD Drilling with Geopilot from 21045' MD (6644' TVD) to 21080 (6658' TVD) ART = .43 hours and bit hours 31.82 hrs. Up weight = 250,000# Down weight = 100,000# Rotating weight = 160,000# Torque @ 120 RPM: on bottom 13 - 14,000ft# // Torque off bottom = 11- 12,000ft#. Pumping 286 GPM = 3210 psi. ECD's average 10.6 - 11 ppg Jar hours SN 1471-0019 =48.33 hrs S/N 14710044 = 128.84 hrs Accelerators # 14471001 = 128.84 hrs Gas = 25 - 79 units MWD not working, Trouble shoot MWD No signs{ from MWD, Circulate and surge to attempt to start. Pump out from 21081 to 21048' while weighting up to 9.4ppg. Circulating at 7 bpm = 3250 psi rotate at 120 rpm Lost 1200 psi pump pressure while circulating, dropped to 2000psi @ 7 bpm. Trouble shoot pressure foss, surface and down hole. Monitor well and pump out of hole @ 4 bpm = 1260 gpm to avoid swabbing. Up weight = 270,000# Down weight = 100,000# 9.4 ppg mud weight going in. Continue to pump out of hole @ 4 bpm = 1260 psi, from 19930 to 17685' into 7 5/8" casing shoe. Monitor well for well control, Slight flow. Circulate 9.4 ppg mud at 300 gpm 2075 psi. Bottoms up had some gas cut to 8.9 ppg. Rig up to test cir-sub while circulating. Pump down kill line with bag closed taking returns from drill pipe through rig floor bleed off. Pump 5 barrels down back side with no returns. Slight trickle signifying that cir-sub is closed and only getting fluid through the port in float valve. Pressure loss while drilling is blow the float valve. Fluid lost in past 24 hours = 421 bbls Total fluid fast to wetf =6698 bbt's Bleed of pressure and blow down lines .all indication show that Cir-sub is closed and pressure loss is below float valve. Monitor well for well control. Well is static. Trip back in hole with no tight spots or trouble. From 17685 to 21041 feet. Did not tag up or attempt to tag up. Monitor well for well control. Well static with no flow or losses while not pumping. Fill pipe and circulate. Stage up pumps. 150 - 200-250 -300 gpm. 300 gpm = 2250 psi. Weight up = 270,000# Printed: 2/16/2006 4:03:41 PM ConocoPhilGps Alaska Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1 C-20 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillip, Rig Name: Doyon 15 Date From - Ta ~ Hours ' Code 'Sub _ _ _' Cade 1!1012006 ~ 02:30 - 06:00 ~ 3.50 ~ DRILL II CIRC ~ 1 I I I 106:00 - 09:00 i 3.00 DRILL CIRC 1 I I I I f 09:00 - 12:00 ,i 3.00! DRILL I CIRC 1 I ~ II' I I 12:00 - 14.00 2.00 DRILL CIRC I I I~ ~ I 14:00 - 15:45 i 1.75'1 DRILL jOB5V I ~ it I 115:45 - 16:15 I 0.50 ~ DRILL OBSV 16:15 - 18:00 II 1.751 DRILL CIRC I ~ f ~ I 18:00 - 19:30 1.50 DRILL j CIRC 19:30 - 21:45 2.251 DRILL CIRC j I I I j ~ 21:45 - 22:00 1 0.251 DRILL CIRC I i, I i 22:00 - 22:45 ~ 0.75 ~ DRILL OBSV i ~ I I I I 1 I I 22:45 - 23:15 0.50 DRILL ~ OBSV 1 I ~ ~ I 123:15 - 00.00 0.75 ~ DRILL 1 TRIP 1 [ I II i 1 I I II i I I i 1 I 1!11/2006 ~ 00:00 - 01:00 ~ 1.00 j DRILL j TRIP I 1 I 01:00 - 06:00 i 5.00 it DRILL ~ TRIP i II I 06:00 - 11:00 I 5.00 ~ DRILL TRIP I 1 II I i 1 j 11:00 - 13:15 ~ 2.25 ~I DRILL ~ PULD Page 44 of 57 Spud Date: 11/21/2005 Start: 11/18/2005 End: 1/28/2006 ~.com Rig Release: 1!2812006 Group: Rig Number: 15 Phase ' Description of Operations PROD I Weight down = 106,000# Loosing 65 BPH Mud weight 9.1 ppg out and 9.4 ppg going in. Slight i gas cut on bottoms up. Start to weight up to 9.6 ppg @ 5:45 hrs PROD ~ Continue to circulate at 300 gpm 1850 psi. Weighting up to 9.6 ppg. Loosing 45 to 60 bph. PROD i PJSM to pump out of hole. Pump out from 21041 to 18945' @ 168 gpm 1260 psi. Up weight = 280,000# j Down weight = 100,000# I PROD Continue to pump out of hole. Pump out from 18945' to 17685@ 168 gpm 1260 psi. At 7 5/8" casing shoe. j Up weight = 280,000# 1 Down weight = 100,000# PROD ~ Monitor well. slight flow. Circulate bottoms at 230 gpm = 1475 psi. I Up weight = 250,000# ~ Down weight = 90,000# PROD Monitor well for well control. Slight flow back. PROD Circulate and weight up to 9.8 ppg. @ 250 gpm = m1670 psi. 33 bph j losses. 7103 total barrels lost to well. from 06:00 to 18:00 405 bbls lost to well. PROD it Continue to weight up to 9.8 PPg while circulating at 5.5 bpm. PROD i Drop dart to open cir-sub amd act as rabbit for pipe to run finer. Open cir sub and increase flow rate to 300 gpm and monitor losses. Losses at 35 0 40 bpmf Still weighting up to 9.8 ppg. I Pit volume getting low. Order out two loads new mud at 9.8 ppg. PROD i Slow pump rate to 100 gpm to reduce losses till mud can arrive. Still ~Iweighting up to 9.8 ppg. PROD I Monitor well for well control with no pumps. Well flowing slightly. Monitor 45 minutes, in forst 15 minutes got 11 bbls back and reduced to no flow back. Evaluate to well giving back some fluid that it has taken. Well static. PROD i Continue to monitor well for flow. No flow / static to dropped two barrels ion back side. Mud volume low, trucks delayed by rig move. Pit volume getting critical. PROD II Pull out of hole slow and carefully monitor well for correct fill. First 3 stands taking no fill. 4 - 5 stand start taking fill. and 6 - 10 takes correct i fill. ~~ Monitor well every 10 stands !static. 24:00 hours: truck load mud I arrives. Total losses last 24 hours = 991 bbls j Total losses to the well = 7689 bbls. PROD II Continue to pull out of hole from 16759 to 16479. ~ Flow check well, static. PROD ~ Gontinue to pull out of hole from 16479. to 8325' Flow check every 10 1 stands Flow check well, static. PROD ~ Trip out from 8325' to BHA, SLM each row. Flow check on each row as !SLM is recorded. We taking correct fill to some additional fluid on trip lout. PROD ;Handle BHA. Fountt BHA parted @ pin orr cir-sub 118 feet 153h IeR in Printed: 2/16/2006 4:03:41 PM ConocaPhiNips Alaska Qperations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Event Name: ROT - D Contractor Name: D15CM(c Rig Name: Doyon 1 Date From - To !Hours 1/11/2006 11:00 - 13:15 ~ 2.25 113:15 - 14:00 ~ 0.75 1 j 14:00 - 22:00 !~ 8.00 I I 22:00 - 22:15 I 0.25 22:15 - 00:00 1.75 I I I I I I I j I i I 1/12/2006 ~ 00:00 - 02:00 ~ 2.00 I I I ~ I ii I i 02:00 - 02:45 1 0.75 ~ 02:45 - 04:15 ~ 1.50 I I I I 04:15 - 06:00 i 1.75 06:00 - 12:30 I 6.50 12:30 - 14:45 I 2.25 14:45 - 15:15 i 0.50 15:15 - 18:00 I 2.75 BILLING ~conocophillip: i Code Sub Code DRILL PULD I FISH j PULD I FISH STRIP f FISH CIRC FISH i CIRC I I I FISH CIRC I I II FISH i CIRC FISH TRIP I 1 Page 45 of 57 Spud Date: 11/21/2005 Start: 11/18/2005 End: 1/28/2006 >.com Rig Release: 1/28/2006 Group: Rig Number: 15 .Phase ', Description of Operations PROD j hole, ab MWD and geo-pilot. ~ _ - - _ _ ~ _ - _ _ - Clear rig floor of all unneeded tool sand equipment. Pick up Baker tools Ito rig floor. PROD Pick up and make up Baker fishing BHA. Isolate drill pipe in derrick so i that pipe that had been in high dog leg was ran into well. PROD ~ Run in hole to 17706' with Baker fishing BHA. Hole taking fluid as (tripping in. PROD !Monitor well at casing shoe. Static. PROD j Circulate at casing shoe. Mud weight in 9.8 ppg mud weight out 9.4 ppg !after shakers. Mud weight before shakers is .1 - .2 ppg higher/ shaking out weight material. Stage up pumps 100 gpm= 750psi = 25 - 45 bph losses 250 gpm = 65 - 70 bph losses. Circulate and condition mud to weight 9.8 ppg in & out. Pick up weight = 240,000# Slack off weight = 115,000# i Got 290 bbls mud from Nordic 3 PROD Circulate @ 100 gpm at casing shoe 17713 = 750 psi. Up weight - 240,000# Down weight = 115,000# Increase flow to 250 GPM = 1750 psi Losses at 30 - 60 BPH ~ Reduce pump rate to conserve mud while volume is be transported. Get 290 bls 9.1 used mud from Nordic and weight up to 9.8 with spike fluid. PROD j Monitor well. Static falling slightly. PROD I Run in hole to 19477' MD start stacking out and taking weight. Stand j back one stand. Engage top drive and fill pipe. Start pumping at 70 gpm = 970 psi. FISH WASH PROD I FISH ~ WASH j PROD I ~ I I I FISH ~ GIRG ~ PROD ~ ~ j FISH WASH Ij PROD I iI I FISH i FISH PROD !Washing though restrictions from 14477 to 19757' MD at 90 - 200 gpm. 90 gpm = 900 psi. Well taking 20 -30 BPH while pumping. I Washing down from 19757 to 20879' @ 210 GPM = 1450 psi Up weight = 290,000# ~ Down weight = 100,000# i Circulate and condition mud. Mud weight in = 9.8 ppg mud weight out = 9.8 ppg. Circulate at 190 gpm. Building mud volume and weighting up mud. Shakers were shaking out .2 ppg. Remove outer screens. ~ Wash to top of fish @ 20925' I Up weight = 290,000# Down weight = 100,000# 1189 gpm = 1400 psi. ~ Fish at 20925 to 21045' j Engage fish and es'tabtish circulation through fish. AAVVD tool began i pulsing . (Attempt to jar fish free. Jars and bumper sub closing at 70,000# hook ~ load (top drive weight) ~ Getting very little jar actions. Having to stop pumps and bleed off ~~ pressure to cock jars and close bumper sub (over come jar extension j force). Maximum pull 480,000# j Max down weight = 70,000# Vary flow rates from 100 GPM = 750 psi to 294 gpm = 2650 psi. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 4s of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11!18!2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1!28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ~ Hours I Code ;Sub ;' Phase Description of Operations !Code, __-- - - -_ _-I------_-~-- -__-_------------------- -_-_----.--.- 111212006 115:15 - 18:00 ~ 2 75 ~ FISH FISH j PROD i Fish not moving. 18:00 - 22:00 ~ 4 001 FISH JAR PROD ~ Jaring and circulating on fish. ~ ~ 1480,000# maximum pull up and 70,000# down. 1 ~~ ; 300 GPM = 2717. ~ 22:00 - 22:15 I 0.25 I FISH JAR PROD ! PJSM for plan to free fish with reduced mud weight and OBM. 122:15 - 23:00 j I 0.75 I 23:00 - 00:00 i 1.00 I I 1/13/2006 f 00:00 - 03:45 ~ 3.75 I 03:45 - 05:30 ~ 1.75 I I I 05:30 - 09:00 j 3.50 I 09:00 - 09:30 i 0.50 09:30 - 10:15 ! 0.75 Continue to circulate at 300 gpm - 2700 psi. j 1) Pump appx 35 bbl (convenient pill pit volume) of 5% KCL brine from j pill pit #1 = 333 stks. 2) Pump at least 290 bbls (3000 stks)of 9.1 ppg Flo-Pro mud. Start out j pit #5 and off load mud from Nodic as we pumping in to pit #5. 3) As brine is pumped outside of fish, keep rate in turbulent flow (as ~ I fast as possible 320 - 350 gpm) and keep working fish. We're unable to cock the jars while pumping, therefore will only be able to work pipe 1 i until the brine is past the fish. One brine clear fish and up hole shut j ~ down cock jars and fir as fast as possible up and down. After we will ~ 1 cock jars and stroke up with 320 GPM to fire jars with pumps on. 3200 ~ I ~ stk from start of spacer !While we are pumping and working pipe we will take OBM on and weight up to 9.8 ppg with bar. ~ iAlso build 60 bbls viscosify 5% KCL spaced j ! ! 4) Once spacer reaches surface, shut down pumping. 5) Jar with 9.1 ppg still in annulus near surface and pumps off for 1 1 greatest reduction in hydrostatic. Put well on trip tank and watch 1 i i carefully for flow. Resume pumping if well control issues develop. 1 !Some U-tubing will occure with 9.8 ppg in drill string and 9.1 ppg in 1 j annular. Keep close track of gains and losses and amount well is flowing. FISH ~ JAR PROD I 1 1 I ~ FISH 1 JAR i PROD i FISH JAR I PROD FISH (JAR ~ PROD I I I I 1 FISH i JAR j PROD i l 1 FISH ~ JAR ~ PROD i FISH IJAR (PROD i !Pump 29 bbls 5% KCL to-vis sweep followed by 9.1 ppg flo-pro. i i Pump to-vis around fish at 330 gpm. Shut down pumps and jar. Loosing jar action and not seeing bumper sub closing. Work string from 480,000 hook load to 70,000# hook load. Fish not moving. Work string from 480,000# up to 70,000# while spotting 9.1 ppg flo-pro to surface reducing hydrostatic. Displace with 9.8 ppg flo-pro. At 9130 stks spotted. began to work string. Continue to work string to jar fish. Hook load 480,000# up 70,000# i down. Displace 9.1 ppg flo-pro mud and spot to surface for maximum hydrostatic reduction with 9.8 ppg. Flow check well. No flow while drill j pipe is shut in .Well will U tube when drill pipe is open to bleed off pressure to cock jars. Well Static. 5000' ND @ 9.1 ppg = 200 psi i reduction. Work drill string, no jar action nor bumper sub. !Pump 25 barrels hi-vis spacer, 25 bbls OBM, 25 barrels HI-vis spacer and displace with to 5 bbls OBM out of fish. Work string hook {oad 480,000# up 70,000# down. j Not able to establish jar action '~ Continue to work string, hook laod 480,000# up to 70,000# block weigh j down. Pump .5 barrels every 30 minutes of oil base out along fish. Apply 12 wraps right hand torque into string and work string Hook load 460 - 470,00# up and 160,000 # hook load down to attempt to apply ~ torque to fish. Staging .5 bbls every 30 minutes OBM around fish. i Continue to work string hook load 460 - 470,000# up and 160,000 # Printed: 2/16/2006 4:03:41 PM ConacoPhillips Alaska Page 47 of 57 .Operations Summary Report - Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number; 15 Date 1!13!2006 'From - To Hours Code 'Code Phase '; Description of Operations. 09:30-10:15__._ _,-_ -~---_ _-_ 0.751 FISH JAR ~ PROD _~___-____----_--_--__ _______:_._.____ hook load down to attempt to apply torque to fish. Staging .5 bbls every i ! 130 minutes OBM around fish. No jar movement. Fill hole with hole fill pump, taking 10 - 20 bph while not pumping. 10:15 - 10:45 I 0.50 FISH JAR ~ PROD IApply18 wraps right hand torque into string to unlatch fish. Work torque I I I into string 450,000# up 140,000# down. U}~ 3~5,, ~ aid I I I f free frar~ ._ siwd ~rdn NNVIfD. 10:45 - 13:00 I 2.251 FISH JAR i PROD I Circulate bottoms up at 300 gpm 12350 psi. @ 650 bbls pumped. Small I i I amount of OBM seen at surface. Rotate at 50 RPM / 11,000 ft# torque. 13:00 - 13:15 j 0.25 FISH JAR I PROD (Attempt to re-engage fish with overshot. Could not latch onto fish. I 113:15 - 18:45 I 5.501 1 FISH I CIRC PROD PJSM & monitor well. Pump out to shoe @ 300 gpm ! 1160 psi up ( i ht = 325 000# d i ht = 90 000# I we g own we g , , I j I ;Losses to well 06:00 to 18:00 433 bbls = 36 BPH average 18:45 - 19:00 0.25 1,19:00 - 00:00 I 5.00 1!14/2006 100:00 - 04:45 j 4.75 04:45 - 08:00 I 3.25 I 08:00 - 09:30 i 1.50 1!1512006 09:30 - 11:30 j 2.00 11:30 - 16:15 I 4.75 I 16:15 - 18:00 ~ 1.75 18:00 - 19:30 ~ 1.50 19:30 - 21:30 i 2.00 I 21:30 - 00:00 I 2.50 00:00 - 06:00 FISH TRIP FISH 1 TRIP I FISH TRIP FISH ~ PULD I FISH TRIP I FISH I PULD FISH TRIP I I RIGMNTI RSRV I I I FISH CIRC RIGMNTI RSRV FISH ~ TRIP 6.001 FISH I WASH PROD I Monitor well at shoe /well static. PROD Pull out of hole from 17519 to 10708. Record up /down weight every 10 I stands. Total fluid lost to well 10,127 bbls PROD Continue to POH with fishing assembly to Baker fishing tools. PROD I PJSM on handling BHA, Break and lay down Baker fishing tools and I inspect. Grapple was sprung. Change out OS and pick up BHA # 11 PROD RIH with BHA #11 to 3002 feet 100,000# up weight 80,000# down ,weight. PROD PROD PROD PROD PROD PROD I PROD 06:00 - 18:00 ; 12.00 I FISH i, WASH ',PROD Pick up drilling hydraulic jars and HWDP. RIH from 3438 to casing shoe depth @ 17620' Up weight = 280,000# Down weight = 110,000# PJSM, Pump tube pill and slip and cut 144' drilling line. Adjust breaks and service top drive. 0600 - 18:00 lost 202 bbl's Iota{ tosses to wets 10,329 bbls Continue to circulate lube pill around 5 BPM = 1400 psi. PJSM to change out top drive saver sub. Change out saver sub to allow for maximum pull of 420,000# on drill string. Continue to trip in open hole. sat down @ 18530' !Rotate through with no pumps. RIH to 19260' tag up. Kelly-up and start to wash to bottom. 270,000# Up and 70,000# hook load down !stacked out without pump or rotating while in restriction. 120,000# down weight when free. 150,000# rotating weight when free. Continue to ream fishing BHA to bottom. Section are free and then stacks out. Mostly not sticky up. Up weight = 240,000# Down weight 120,000# when free. Rotating weight = 160,000# with 9000 ft# torque when free. Torque limit set at 15,000 ft# Pulling 320 - 380K if pushed into tight spot. If sat down < 10K to over pull. Ream through resistance at 50 RPM = 10,000 ft# Torque free. Stalls at top drive limit setting (15,000ft#) id pushed into restriction. Washing to 20422. Free in places. Up weight = 270,000# Down weight = 110,000# Printed: 2!16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Page 48 of 57 Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To : -.Hours Code !Sub ', .Phase Description of Operations Code - _ __ _ I 1 /15!2006 06:00 - 18:00 -- -____~______-_- I. 12.00 ~ FISH I WASH I PROD -,___---___-_____ _-.___--- -_____________ i Rotating weight = 155,000# when pipe is Free. I j I 1 Stack-out to 70,000# Hook load and takes 320 - 380K pull free. j j I, I Pumping 4.5 BPM = 1580 psi. I I ~ j Pumping tube pills ay 20% tube to reduce drag !works well and can see I as turns the corner. Gan not keep enough tube unfrozen to pump pigs I es needed. ~ 18:00 - 00:00 ~ 6.001 FISH WASH I PROD Continue to wash down. 20422 to 20720'. AT 20720 - 20750 hanging i i I dup. I 20750 to 20918 Free to top of fish. j j I I Wash at 50 - 80 RPM = 10,000 ft3 Torque if free. Top drive limit set at I I ~ I i ~17,000ft # Up weight 270,000# Down weight 120,000# ~ ~ I i Rotate weight 170,000# I I ~ I I Rotate at 60 RPM = 10,000ft# 130 spm = 750 psi. I j j SPR @ 20 spm = 730 psi ~ j ~ I SPR @ 30 SPM 930 psi. 1/16/2006 100:00 - 00:15 i 0.25 l j I i I I I I I II 00:15 - 01:15 j 1.00 01:15 - 02:30 02:30 - 02:45 02:45 - 04:00 04:00 - 06:00 06:00 - 09:00 09:00 - 11:30 11:30 - 13:00 FISH I FISH i PROD FISH I FISH !PROD 1.251 FISH {CIRC I PROD 0.25 FISH ~ CIRC PROD 1.25.FISH (TRIP ,PROD 2.001 FISH I TRIP j PROD i Take slow pumps rates prior to engaging fish. 20 spm = 730 psi 130 spm = 930 psi. ~ Up weight = 270,000# Down weight = 120,000# Rotating weight = 168,000# (Attempt to engage fish as per fisherman with 15 spm 640 psi Pressure increase 1240 psi as fish was swallowed. ~ Pick up did not latch. Pull off with no over pull. Several attempts, with no pumps and with increased pumps and I applying torque. Start banging down no movement. Looks like we are swallowing fish 1.5 feet. No catches. Up weight 270,000# Down weight = 120,000# ~ No pulses from MWD tool. I Circulate bottoms up at 295 gpm 2450 psi. !i Loosing 60 - 80 BPH. Monitor well for well control. Slight flow back foe 5 minutes and static. PJSM Pull out of hole on elevators to 19395. Weight up = 330,000# II weight down 100,000# Hole not taking correct fill. Think it is breathing 'but will pump out as precaution. II Pump out if hole to the shoe at 17713' ,100 GPm = 800 psi. Up weight = 280,000# Down weigh= 100,000# 3.00 i FISH ~ CIRC j PROD i Circulate 300 GPM = 1831 psi. bottoms up. 6500 stks. ~ ~ Perform derrick inspection while circulating. 2.501 FISH I CIRC j PROD i Monitor well while mixing LCM pill. Blow down top drive. Well static. 1.501 FISH CIRC ~ PROD j Pump and spot 100 bbls LCM pill with 2000 stks @ 65 spm 2680 psi i !Monitor well. Printed: 2!16/2006 4:03:49 PM ConocoPhillips Alaska Operations Summary Report Page. 49 of 57 Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To i Hours ' Code ',Code ! Phase Description of Operations 1/16!2006 i 13:00 -14:00 1.001 FISH jTRIP I PROD j Pull out of hole and above LCM pill. 15760' UP weight 250,000# i 1 ~ ~ ~ Down weight = 120,000# 14:00-14:15 ! 0.25 14:15 - 14:30 ~ 0.25 14:30 - 14:45 I 0.25 14:45 - 21:00 6.25 FISH I CIRC I PROD FISH CIRC ~ PROD FISH I CIRC ~ PROD FISH ITRIP I PROD 21:00 - 21:30 ~ 0.501 FISH PULD I PROD 21:30 - 22:30 1.00 ~ FISH I PULD PROD 22:30 - 23:15 I 0.75 ~ FISH TRIP I ~ PROD 23:15 - 00:00 ~ 0.751 FISH , ~ TRIP ~ PROD 1/17/2006 100:00 - 00:30 I 0.50 1 00:30 - 01:30 I 1.00 01:30 - 03:00 i 1.50 I ~ 103:00 - 06:00 I 3 00 06:00 - 08:30 ~ . 2.50 08:30 - 10:00 1.50 ~ 10:00 - 11:00 , 1.00 1118!2006 11:00 - 11:45 j 0.75 i 11:45 - 12:00 0.25 12:00 - 12:30 0.50 12:30 - 17:45 5 25 I 17:45 - 18:00 I . 0.25 18:00 - 20:45 I 2.75 20:45 - 21:15 0.50 21:15 - 22:15 i 1.00 22:15 - 23:15 I 1.00 23:15 - 00:00 I 0.75 00:00 - 00:45 'i 0.75 00:45 - 02:30 li 1.75 I 02:30 - 03:45 ~ 1.25 03:45 - 05:00 ~I I 1.25 05:00 - 05:30 ~ 0.50 05:30 - 06:00 I 0.50 FISH PULD I PROD I RIGMNT RSRV I PROD FISH ,PULD I PROD RIGMNT RGRP I PROD RIGMNT RGRP PROD FISH ~ TRIP I PROD FISH ~ TRIP ~ 1 PROD li F1SH I I j TRIP I I ~ PROD FISH I OTHR 1 ~ PROD RIGMNT RSRV PROD FISH FISH ITRIP CIRC ~ PROD PROD i I FISH CIRC I j PROD FISH FISH ITRIP ITRIP IPROD ~ PROD FISH TRIP I PROD FISH STRIP !PROD FISH jTRIP j PROD I FISH CIRC j PROD I FISH j JAR II PROD FISH j CIRC I PROD f 1 FISH JAR ~ PROD FISH ,TRIP PROD Monitor well for well control! well static. Pump dry job. Blow down top drive. POOH with BHA #11 From 15760 to 3470' Lay down 3 x SWDP at upper jars. Hole taking 20 BPH. Change out elevators to handle spiral DC's and jars, Lay down 2 x spiral DP and stand back SDP & jars. Change out elavator to 4" to continue tripping out to BHA. POH to BHA, Change out elavators to handle fishing tools. Total losses to this well 12,295 bbl's = 571 bbls last 24 hours Lay down overshot, 3 x DC's and change out grapple, Grapple was broken and control latch holding the grapple up so it would not catch. No pieces lost. Cut lip guide was cracked and bent. Service top drive & crown. Clear rig floor, Static losses at 9.5 BPH PJSM: Change out guide, grapple (4 5/8") Make up guide shoe, bumper subs, jars, cir-sub, 3 x 3 1!2" HWDP and intensifiers, XO to DP. Repair iron roughneck Repair iron roughneck. Hole took 6 bbls in 2 hrs. RIH w/ 30 stands HT 38 dp to 2982'. Work BHA #12 (Fishing BHA #3). PU/MU (3) 3-1/2" Spiral HWDP, Weatherford x-o, Daily 4.8" OD dual acting hyd jars, (3) 3-1/2" spiral HWDP, Daily 4-3l4" accelerators, (3) 3-112" Spiral HWDP to 3325'. Change elevators to 4". Continue RIH w/ BHA # 12 on 4" dp. Record torque and drag data every 10 stands. Install air slips. BOP drill. Service rig and drawworks. Continue RIH w/ fishing BHA to 17698' Circ bottoms up @ 70 spm wi 1920 psi. Fluid losses f/ noon to 1800 hrs = 22 bbls. Total fluid losses to well @ 1800 hrs = 12,359.5 bbls. Continue circ @ 17698'. Circ 287 gpm w/ 1800 psi. Circ BU x2. Continue RIH f/ 17698' to 18165'. Pump while RIH f! 18165' to 18818'. Pump 300 gpm w/ 1920 psi. Continue RIH f/ 18818' to 20600'. Taking weight @ 20600'. Pump while RIH f/ 20600' to 20730'. Pump 238 gpm(57 spm) w/ 1700 psi. Losses f/ 1800 hrs to midnight = 179 bbls Total losses to well @ midnight = 12538.5 bbls. Pump while RIH f/ 20730' to 20900'. Pump 238 gpm (57 spm, 241 gpm) w/ 1700 psi. Circulate and condition mud. Pump 238 gpm w! 1600 psi. Spot 50 bbl 15% tube pill. Spot 25 bbls outside of fishing assembly. Record SPR's, swallow top of fish 20925', jarring on fish. Circulate, stage pumps up f/ 101 gpm w/ 1800 psi to 201 gpm w! 3050 psi. Pump total of 300 bbls. Jar on fish while circ @ 20 spm wl 1300-1350 psi. Fish moved down, pull free and recip pipe while circ. Record SPR's, Pump out of hole wf fish f! TOF @ 20925' to 20684'. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 50 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Wefl Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1!28/2006 Contractor Name: D1 5CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ', Hours ', Code '~ 5ub ', Phase ~ Description of Operations Code - ---- ,- 1 /18/2006 05:30 - 06:00 j -- -___ __ --I----- 0.50 FISH I TRIP PROD __--_ __---___------_______ Pump w/ 20 spm 1100 psi. PU wt 250k, SO wt 115k. j ~ Fluid losses f/midnight to 0600 hrs 94 bbls 06 00 12 00 j 00 FISH TRIP I PROD 6 Total losses to well @ 0600 hrs 12632.5 bbl. I P 17791' f h l / fi h f/ 20684' t P 20 / 100 i : - : . . ump out o o e w ump spm w ps . s o 12:00 - 12:30 ~ I j 0.50 ~ FISH ~ TRIP PROD Maintain mud wt 9.8 ppg. Pump out of hole w/ fish f/ 17791' to 17604'. Pump 20 spm w/ 100 psi. 12:30 - 12:45 f I 0.251 FISH i OTHR PROD I Maintain mud wt 9.8 ppg. Monitor well and clean floor. 12:45 - 13:30 I 0.751 FISH CIRC I PROD i Pump dry job. Blow down top drive and mud line. 13:30 - 18:00 ~ 4.50 I FISH TRIP I PROD I Continue to POOH w/ fish f/ 17604' to 12400'. PU wt @ 180k. Pull string I ~ easy, in and out of slips. I j I Fluid loss f! 0600 hrs to 1800 hrs = 56 bbls j 18:00 - 23:00 II 5.001 FISH ~ TRIP ~ PROD ~ Total fluid loss to well @ 1800 hrs = 12688.5 bbls j Continue POOH wet w/ fish f/ 12400' to 3325'. 23:00 - 00:00 ~ 1.00 ~ FISH TRIP j PROD j PJSM, Pull air slips, change out elevators to 3-1l2", Continue POOH j I I ~ ( f I wet w/ fish f13325' to 3233'. Stand back spiral HWDP, UD Daily accelerators. 1!19/2006 i 00:00 - 00:45 ~ 0.751 FISH TRIP PROD I Continue POOH wf fish (wet) f/ 3233' to 2982'. Stand back 2 spiral 100:45 - 02:15 I 1.501 FISH TRIP PROD HWDP, UD Hyd jars and (2) crossovers. ~ Continue POOH w/ fish (wet) f/ 2982' to 241'. 02:15 - 02:30 0.25 ~ FISH ~ PULD PROD ~ UD intensifiers and crossover. Change out elevators. 02:30 - 02:45 I 0.25 ~ FISH SFTY j PROD I PJSM on handling Sperry Sun nukes and BHA #9 ie fish. j 02:45 - 03:00 j 0.251 FISH PULD I PROD I I POOH w/ fish (wet) f/ 241' to top of fish, ie atand back stand of 3-1/2" ~ HWDP, UD circ control joint, PU and release fish, UD super jars, (2) I 103:00 - 03:15 I ~ I 0.251 FISH PULL ~ PROD ~ bumper jars and overshot. I Inspect top of fish. 3 pieces of formation on top of float sub. UD float ~ i ~ ~ sub. 103:15 - 03:30 0.251 FISH OTHR I PROD I Handle nuke sources. 03:30 - 04:15 I 0.75 j FISH PULL I PROD IUD Sperry Sun stabilizer, pull guts for hang off collar and UD same. IUD PWD-Gamma Res, MWD, smart stab, geo flex collar, GeoPilot ~ I I i 5200 (ser # TL-027), Security 6-3/4" PDC bit (FSF 2641, ser # j 04:15 - 04:45 j ~ 1 0.501 FISH ~ OTHR PROD j10795399) ~ Clear rig floor of BHA #9, ie the fish. 04:45 - 05:00 ~ 0.25 I FISH j PULD I PROD ~ PU and break down Baker Oil Tools fishing tools. UD Super jars, I i I I I I bumper sub #1, bumper sub #2, top sub, overshot, scallop guide and i I overshot bowl. 05:00 - 05:30 j 05:30 - 05:45 I 0.50 I FISH OTHR PROD 0.25 WELCTL OTHR I PROD ~ Clear rig floor of Baker fishing tools. I Back out lock down screws on FMC wear bushing. 05:45 - 06:00 0.25 j WELCTL OTHR ~ PROD ~ RU to test BOPE. Test waived by AOGCC inspector. j i I I ~ Fluid lost to well f/ midnight to 0600 hrs = 35 bbls. Total fluid lost to well @ 0600 hrs = 12761 bbls. 106:00 - 09:00 ! 09:00 - 09:15 ~ 3.00 ~ WELCTL OTHR .PROD 0.25 WELCT SFTY PROD ~ ~ Continue rigging up to test BOPE ff 14 day test. ~ PJSM prior to testing ROPE. I, 09:15 - 12:00 I ROPE I PROD 2.75 ~ WELCT Start of 14 day BOPE test. Witness of test waived by AOGCC field ~ I inspector. Test Hydril, HCR, Ki111Choke, upper IBOP, XT39 TIW, upper i ~ I rams, manual kill, manual choke, choke manifold valves # I I I I 1i 2,3,8,9,16,17,12,13,14,15 to 250 psi low and 3500 psi high. Test HT 38 I 12:00 - 15:30 ~ ~ 1 3.50 I WELCTL BOPE ~ PROD I TIW valve 250 psi low and 3500 psi high. Hold each test 5 min. ~~ Continue testing BOPE. Test upper and lower 1BOP valves, HT 38 dart I j I I I valve, XT 39 dart valve failed. Test top set of 4" rams, test lower rams 3-1/2" x 6" variables, blinds all to 250 psi high and 3500 psi low, hold I ~ 15:30 16 30 I j I, 1 WELCTIJ OTHR PROD 00 ~; each test f! 5 min. Test accumulator. Test gas alarms. P ll FMC hi Bl h k ll FMC t t l I t b d - : . i I I wear own c j u es p ug. ns a us ng. ow o e j Printed: 2!1612006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-20 Page 51 of 57 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1!28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To !Hours ' Code 'Sub Phase Descrjption of Operations Code _ _ _ _ ___ __ _ I Ty OTHR - _ ~ i - _ - _ - - _ ._ _ _ . _ _ _ 1/19/2006 _ I PROD I manifold, kill and choke lines. ~ 16:30 - 16:45 I 0.25 DRILL SFTY PROD I PJSM on picking up BHA #13 (Cleanout assembly). I 16:45 - 18:00 1.25 DRILL PULD I PROD Pickup and makeup BHA #13 (Cleanout assembly). I I I Fluid losses f! 0600 hrs to 1800 hrs =zero bbls ~; Total fluid lost to well @ 1800 hrs = 12761 bbls. 18:00 - 20:15 2.251 DRILL I TRIP j PROD ~I Trip in hole w/ BHA #13 (cleanout prior to run slotted liner). 120:15 - 20:45 ~ 0 fill pipe 50 DRILL CIRC PROD j RU to fill HT 38 dp w/ 2" hose and headpin , . . 20:45 - 21:30 j 0.751 RIGMNTI RSRV I PROD I Service rig, top drive and crown. j 21:30 - 23:45 2.25 j RIGMNTI RGRP PROD ~ Change out iron roughneck pipe spinner clamp cylinder. 123:45 - 00:00 0.251 RIGMNTI RSRV I PROD PJSM on slipping and cutting drilling line. ~ Fluid lost to well f! 1800 hrs to midnight = 22 bbls j I ~ Total fluid lost to well @ midnight = 12783 bbls. 1!20/2006 100:00 - 01:45 i 1.75 RIGMNTI RSRV PROD Slip and cut 109' of 1-3/8" drilling line. Adjust brakes on drawworks. 01:45 - 06:00 j 4.25 DRILL TRIP PROD j Continue trip in hole w/ BHA #13 (cleanout prior to run slotted liner) f! j I ~ 12333' to 9903'. Fill pipe @ 4225', 6118', 8009', and 9903'. PU wt 160k, I I ~ ~ SO wt 110k @ 9903'. ~ ~ I Note: Fluid loss to well 0000 hrs to 0600 hrs =8 bbls j I Total fluid lost to well = 12791 bbls. 06:00 - 12:00 I 6.00 DRILL TRIP PROD ~ Continue trip in hole w! BHA #13 (cleanout prior to run slotted liner) f/ 1 I 9903' to 17651'. Fill pipe every 20 stands. 12:00 - 14:30 2.50 i DRILL i CIRC i PROD I Circ bottoms up plus. Pump @ 70 spm w/ 1900 psi. PU wt 220k, SO wt 110k. Rot wt 145k. Circ with no losses to hole. 1,14:30 - 14:45 0.25 DRILL I OTHR ~ PROD 1 Blow down top drvie. ~ ~ I ~ Note: Performed LOT and freeze protected 10-3/4" x 7-518" annulus 1 I I w/ Little Red Hot Oil. Filled annulus w/ 15.5 bbls diesel, used 11.5 bbls I I . I ~ I diesel to perform LOT. Flushed w/ 580 bbls- 70deg water, freeze I I 1 protect w/ 110 bbls diesel. ~ 14:45 - 17:00 j 2,25 ~ DRILL i TRIP i PROD ~ Continue trip in hole wf BHA #13 (cleanout prior to run slotted liner) f/ j I 117651' to 2091 T. Work through a tight spot @ 18370'. OK. MU top j drive on stand #219. Precautionary ream down 43' to 20960'. PU wt ~ i I ~ ~ 230k, SO wt 220k, Rot wt 150k. Rotate 50 rpm w! 11 k ft11b torque to j ~ I 1 start with. 17:00 - 18:00 1.00 DRILL I CIRC ~ PROD I Circ and conditiion hole f/ slotted liner run. Circ @ 70 spm w/ 2150 psi. 'I i i ~ I Slowed pumps to 50 spm w/ 1650 psi to decrease losses. Increased I I rpm to 120 rpm w! 12k ft/Ib torque. Note: Fluid loss to well 0600 to 1800 hrs = 154 bbls I ~ ~ ~ I ~ Total fluid lost to well @ 1800 hrs = 12949 bbls. 18:00 - 20:00 2.00 i DRILL ~ CIRC i PROD j Circ and condition hole f/ slotted liner run. Pump 120 bbl high vis sweep j 1 ~ I w/ 12 ppb LCM. Rump @ 207 gpm w/ 1700 psi, rotate 120 rpm w/ 12k j I ~ 1 ft/Ib torque. Slow pumps down to 87 gpm @ bottoms up because I ~ shakers overrunning w/ LCM. Increase rate to 127 gpm until sweep out ~ I ~ I 1 of bit and on backside. II ~ I ~ ~ Note: From 1700 hrs ti112000 hrs lost total of 200 bbls to hole. 20:00 - 20:15 j 0.251 DRILL OBSV PROD !Monitor well. Flowing back slightly w/ pumps off. j 20:15 - 00:00 I 3.75 DRILL ~ TRIP i PROD j Pump out of hole fl 20960' to 19983' monitoring losses. Pump out with I I I I g7 gpm and 380 psi. Pump 300 strokes per stand. Pulling speed 5-6 ~ ~ fpm. Hole appears to be taking 4-5 bph after calculating out pipe I ! I displacement. Flowing slightly wf pumps off. SLM. Dropped hollow I rabbit wJ 2.31" OD w/ 110' of wire. I I I ~ 1 Note: Fluid lost to well 1800 hrs to midnight = 239 bbls. ~ I I ~ 1 Total fluid lost to well = 13188 bbls 1/21/2006 II 00:00 - 06:00 ~ 6.00 DRILL ~ TRIP PROD Pump out of hole f/ 19983' to 17651' monitoring losses. Pump out with i I I I ! 87 gpm and 380- 500 psi. Pump 200 strokes per stand. Pulling speed Printed: 2!16!2006 4:03:41 PM ConocoPhillips Alaska Page 52 of ~7 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C -20 Spud Date: 11!21/2005 Event Name: ROT -DRILLING Start: 11/18!2005 End: 1128!2006 Contractor Name: D1 5CM@conocophillips.com Rig Release: 1(28/2006 Group: Rig Name: Do yon 15 Rig Number: 15 .Date From - To 'Hours ! Code ~ Sub ', Phase Description of Operations ode C , 1!21!2006 ~ 00:00 - 06:00 ~ _ _ 6.00 DRILL ~ TRIP I PROD ~ 10-11 fpm. Hole appears to be taking 10-15 bph after calculating out I i pipe displacement. Flowing slightly w/ pumps off. SLM. Dropped hollow I ~ j II rabbit w/2.31" OD w1 110' of wire. ~ Fluid losses to well f! midnight to 0600 hrs = 87 bbls. I it 06:00 - 09:00 I I I j 3.00 ~ DRILL ~ CIRC I ~ PROD 1 Total fluid losses to well @ 0600 hrs = 13271 bbls. I Circulate @ 17651' (shoe}. Rotate 120 rpm w110-11 ft! Ib torque. Pump j ~ j 300 gpm w! 2100 psi w! losses @ 120 bph. Slowed rate to 240 gpm w/ I, ~ i 1750 psi, losses slowed down to 80 bph. 09:00 - 10:45 j 1.75 DRILL CIRC ,I PROD Pump and spot 80 bbls EP metal to metal tube pill to within 1000' of I I I i I, surface. Pump @ 233 gpm wf 1400 psi while rotating 120 rpm w/ 10k j Iftllb torque. Fluid fosses are 50 bph. Increased pump rate to 295 gpm ~ wl 2100 psi and losses increased to 90 bph. 10:45 - 11:00 ~~ 0.25 DRILL I OBSV PROD ~ Monitor well. Static. ~ 11:00 - 11:451 j 1,11:45 - 12:00 'I 0.75 DRILL ~ 0.251 DRILL I CIRC PROD I TRIP I PROD I Pump dry job. Blow down top drive and mud line. I Total fluid lost while circ @ shoe = 240 bbls. Continue to POOH f/ 4-1/2" slotted liner on elevators f/ 17651' to ~ 1 I ~ 16950'. PU wt 240k, SO wt 120k. SLM out of hole. Record torque and i 12:00 - 15:00 I 7 3.001 DRILL TRIP PROD drag data every 10 stands. Continue to POOH f/ 4-112" slotted liner on elevators f/ 16950' to 12335'. SLM out of hole. Record torque and drag data every 10 stands. 15:00 - 15:15 15:15 - 17:15 I 0.25 RIGMNT 2.00 RIGMNT RGRP PROD RGRP PROD j PJSM on repair of service loop on top drive. ~ Repair service loop on top drive. j 17:15 - 18:00 ! 0.75 RIGMNT RGRP j PROD j Try to power up top drive. Would not power up. Rig electrician and j ~ ~ I I mechanic trouble shoot and fix problem. Pull one stand f/ 12335' to I I I C ~ 12241'. ', ~ I II Fluid losses to well f! 0600 hrs to 1200 hrs = 240 bbls j ~ ~ I I Fluid losses to well f/ 1200 hrs to 1800 hrs =zero j 18:00 - 22:30 I 4.50 "DRILL i TRIP PROD j Totatl fluid lost to well @ 1800 hrs = 13511 bbls. i Continue to POOH f! 4-1l2" slotted liner on elevators f/ 12241' to 6686'. ~ ~I SLM out of hole, replace tape @ 1930 hrs. Record torque and drag data i, ~ ~ ~ ~every10stands. 122:30 - 00:00 i 1.501 RIGMNT RGRP I PROD Repair top drive service loop power cable f! electric solenoids. ,1 i 1 I Fluid losses to well f/ 1800 hrs to midnight = 43 bbls, of this amount the I static losses are 5-6 bph while working on top drive. j 1!2212006 00:00 - 03:00 II 3.001 RIGMNT I RGRP I PROD i Total fluid lost to well @ midnight = 13554 bbls 'Repair top drive service loop power cable f! electric solenoids. j 03:00 - 05:15 I j 2.251 DRILL I I TRIP PROD I Well taking 5-6 bph static while working on service loop. ~ Continue to POOH ff 4-112" slotted liner on elevators f/ 6686' to 3279'. SLM out of hole. Record torque and drag data every 10 stands. 05:15 - 05:30 i~ 0.25 DRILL ~ SFTY j PROD j PJSM on laying down 30 stands of 4' Weathertord HT 38 dp. Will strap j ~ in pipe shed. 05:30 - 06:00 I 0.50 DRILL PULD I PROD I Lay down 90 joints of 4' Weathertord HT 38 dp. Will strap in pipe shed. I I j ~ I Fluid lost to well f/midnight to 0600 hrs = 80 bbls ~ ~~ j Total fluid lost to well @ 0600 hrs = 13634 bbls. ' ' 06:00 - 09:00 i 3.00 DRILL j PULD ~ PROD , laying down a total of 90 joints of I Continue POOH f! 2995 to 438 ~ I ~ j ~ I I I Weatherford 4" DP (HT 38 connection). No correction on tally (within ~ 2.5 ft). ~ 09:00 - 11:00 ~ 2.00 DRILL PULD ~ PROD IUD BHA # 13 (cleanout assembly). f 11:00 - 12:00 1.00 DRILL OTHR PROD Clear rig floor. Change out elevators. II 12:00 - 13:00 I 1.00 CASE i RURD j PROD Rig up to run 4-112" slotted liner. Rig up thread protector transfer line to I j 13:00 - 13:15 ~ 0.25 CASE SFTY PROD ~ pipe shed. Change out seal on GBR power tongs. ~ PJSM w! crew, company rep, casing crew, tooppusher and Baker service hand on running liner. Printed: 2!16/2006 4:03:41 PM ConocoPhillips Alaska Page s3 of 57 fJperations .Summary Report.: Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To !Hours ' Code ~ Sub ;Phase Description of Operations Code! 1!22!2006 13:15 -17:15 !. 4.00 j CASE I PULR ~ PROD ~ PU/MU 4-1/2" 12.6 ppf L-80 slots and blank liner to 3355'. MU 4-1/2" j j Ray's oil tools silver bullet guide shoe, x-o, 4-1/2" BTC 12.6 ppf L-80 I j I j j I ~ blank, then 4-1 /2" BTC 12.6 ppfL-80 slots and blanks as per plan w/ I I I ! total of 7 Easy Swell packers, spaced and placed where needed. Total I ~ I total of 42 blanks plus the shoe joint blank. Torque rings of 45 slots , I, I ~ i , installed in the collars to allow f/ 8170 ft/Ib of torque if rotation is I I ' I needed. Run one 4-1/2" x 6-1/2" spiralglider per jt, floating. 17:15 - 17:45 ~ 0.501 CASE I PULR PROD j - MU Baker 190-47 seal bore extension, Baker 5.5" x 7.625" Flexlock ~~ ~ ~ liner hanger, RS packoff seal nipple, Baker "NRD" ZXP liner top packer j 17:45 - 18:00 % 0.25 ~ CASE OTHR PROD I I assembly 5.5" x 7.625". PU wt 100k, SO wt 98k, Block wt 70k. Fill top of packer w/ PAL. Mix up PAL while cleaning rig floor. ~ j i Fluid lost to well f/ 0600 hrs to 1800 hrs = 9 bbls I II 18:00 - 1$:15 II 0.25 j CASE OTHR j PROD I I Total fluid lost to well @ 1800 hrs = 13643 bbls. Clear and clean rig floor while PAL is setting up. 118:15 - 00:00 ij 5.75 i CASE ~ RUNL PROD I Install crossover (3-1/2 IF pin x 4" HT 38 box), Trip in hole with liner f/ I j 3424' to 10896' @ midnight (79 stands 4" dp in hofe). Record PU and j j ~ ~ SO wt's every 10 stands in casing. Fill string w/ fillup line, every 10 ( I ~ I j I stands. I ~ i ~ I Fluid loss f/ 1800 to midnight zero j I I I j Total fluid lost to well = 13643 bbls 1/2312006 ~ 00:00 - 05:30 i 5.50 j CASE I RUNL PROD Continue trip in hole with liner f/ 10896' to 10896' to 17707 .Record I i PU and SO wt's every 10 stands in casing. Fil{ string w/ fillup line, j j 05:30 - 06:00 ! 0.50 j CASE ~ OTHR ~ PROD ~ every 10 stands. Top off DP w! mud. MU top drive. Record PU 230k, SO 125k, Rot wt j I 1155k. Rotate @ 20 rpm w/ 8-9k ft/ Ib torque. Establish circ. Record I ~ I ~ pressures @ 15 spm w/ 215 psi, 25 spm w/ 300 psi, 30 spm w/ 370 psi, I ~ I j 135 spm w/ 440-450 psi. Pump 24.7 bbls total volume. j I j ~ j Note:Top slot 3207.59' above liner guide shoe. Circ @ 14500' w/ guide i ~ I 06:00 - 06:15 0.25 j CASE OTHR PROD Ishoe @ 17707. Blow down top drive. j I I Fluid losses f/ midnight to 0600 hrs =zero. ~ I 1 06:15 - 09:00 ~ 2.75 CASE i RUNL j PROD Total fluid losses to well @ 0600 hrs = 13643 bbls. ~ Continue RIH w/ 4-1 /2" slotted and blank liner w/ 7 "Easy Well I j 1 j I Solutions" swell packers f/ 17707 into open hole to 20225'.Taking j j 09:00 - 10:45 I, 1.751 CASE I RUNL PROD weight. MU top drive. Rotate liner in hole w/ 20 rpm 10-11 k ft/Ib torque f/ 20225' it I ~ ~ to 20410', RIH w/ liner f/ 20410' to 20550', Rotate liner in hole f/ 20550' i I ~ to 20690'. RIH w/ liner f/ 20690' to 20875', rotate f/ 20875' to 20940'. PU j ~ ~ I I wt 276k, SO wt 70-80k, Blocks 70k. Rotating wt =136k j I ~ I Note:4-1/2" liner was run w/ Weatherford 4" dp total of 186 stands + I ~ 147.8' of stand 187. Of this pipe: stand #1-#72 was HT38, stands #73- j j i i 187 was X739 (total of 72 HT38, 115 X739). Total of 149 supersliders l ~ I ~ Ij 10:45 - 11:00 I 0.25 ~ I CASE ~ OTHR PROD Iwere run starting on stand #5 and ending on stand #153. I Drop 1-3/4" ball. Work pipe to set liner in tension w/ liner top packer @ 11:00 - 12:00 1.00 II I CASE j CIRC ~ PROD 117513' and guide shoe bottom @ 20927. I Pump ball down to seat. Pump 4 bpm w/ 750 psi, slow down to 2.5 bpm I 12:00 - 12:30 I, 0.50 ~ j CASE I OTHR PROD I w/ 400 psi. Seat ball w! 1372 strokes. II Pressure up to 1700 psi to set liner hanger. SO to 70k (top drive wt). ~ I j ~ j Pressure up to 4000 psi to release HRD Hyd running tool. Bleed off !. i 112:30 - 13:00 ~ 0.50. I I CASE DEOT I PROD ~ pressure. Pick up to neutral wt. I Close annular. Test liner top to 1500 psi f! 10 minutes (testing 7-5l8" j I csg x 4" dp). Good test. Slack off string weight on liner top. Pressure to i j I ~ ~ 1000 psi. PU and confirm liner released. Stand back 2 stands to stay Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Page 54 of 5~ Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11!18/2005 End: 1/28!2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date ;From - To .Hours '; Code Code' Phase ' Description of Operations 1!23!2006 ~ 12:30 - 13:00 ,I 0.50 CASE i DEQT i PROD approx 140' above liner top. Stand back stand 187 and 186. Circ w/ ~ 13:00 - 18:00 I 5 00 WAITON WOW ~ PROD stand 185 in hole . ~ Circ and condition mud while waiting on weather Phase 3 weather was . . I called @approx 1030 hrs 1-23-2006. Circ 2.5 bpm w/ 530 psi. PU wt i I 1220k, SO wt 125k, blocks 70k. I I ~ Fluid lost to well fl 0600 hrs to 1800 hrs = 18 bbls I 18:00 - 00:00 j 6.00 j ~ WAITON WOW ~ PROD I Total fluid lost to well @ 1800 hrs = 13661 bbls i Continue to circ and condition mud while waiting on weather. Circ 2.5 j I I I i bpm w/ 530 psi. PU wt 220k, SO wt 125k, blocks 70k. I Fluid lost to well f! 1800 hrs to midnight = 14 bbls j j 1 /24/2006 ~ 00:00 - 03:15 3.25 ~ ~ WAITON WOW j PROD Total losses to well @ midnight = 13675 bbls I Continue to circ and condition mud while waiting on weather (Phase 3). I I I I Circ 2.5 bpm w/ 530 psi. PU wt 220k, SO wt 125k, blocks 70k. Depth j 1 I 03:15 - 03:25 it 0.17 ~ CASE SFTY PROD 117371'. ~ PJSM on laying down 4" dp. 03:25 - 03:40 0.25 j CASE I CIRC PROD i Pump dry job. j 03:40 - 04:00 0.33 I CASE OTHR ~ PROD j Blow down top drive. Blow down mud line. 04:00 - 06:00 2.00 ~ CASE j OTHR I PROD I POOH UD 73 joints of Weatherford 4" dp. This is XT 39 dp. j ~ ~ Fluid losses f/ midnight to 0600 hrs = 12 bbls. 06:00 - 12:00 i 6.00 ~ CASE OTHR ~ PROD ;Total fluid losses to well up to 0600 am = 13687 bbls. I POOH L/D 169 jts Weatherford 4" DP. Remove 49 Western Well Toolf ~ Alaskan Energy Resources 4" non rotating drill pipe casing protectors I j 12:00 - 15:15 I 3.25 I CASE OTHR I PROD (patented) (NRDPCP) Heavy duty super sliders. j Continue POOH laying down Weatherford 4" XT 39 drill pipe. Removing j i i j j ' 32 more Western Well Tool/ Alaskan Energy Resources 4" non rotating j drill pipe casing protectors (Patented) (NRDPCP) Heavy duty super ~ I j j sliders. Lay down 97 joints of 4" drill pipe. Missing top collar for super j I 15:15 - 18:00 ~ 2.75 CASE OTHR ~ PROD slider on jt # 338 out of hole. Collar OD = 5-112", collar length 4-3/4". ~ Drain BOP stack. Attempt to fish out Western Well Tool/ Alaskan I i j 1 j Energy Resources 4" non rotating drill pipe casing protector (patented) j I ~ 18:00 - 00:00 ~ 6.001 CASE OTHR I. PROD ~ ~ I ~ (NRDPCP) Heavy duty super slider top collar (5-1/2" OD x 4-3/4" long). i, Attempt to fish out of well, the Western Well Tool/ Alaskan Energy " I I Resources 4 non rotating drill pipe casing protector (patented) I ~ I ~ I (NRDPCP) Heavy duty super slider top collar. Collar is in the 7-518" " ' " " I 29.7ppf (6.875 ID) casing below the FMC 7-1/16 ID x 10-13116 OD, 1 ' I I f/ I long wear bushing. Lockdown screws for the wear bushing @ 36.25 I , I ~ rig floor. I Pull Weatherford 4" HT38 drill pipe (5" OD tool joint) while observing ~ I I j hole f/signs of the collar. Collar (5-1/2" OD) could be seen below FMC . ~ I I ~ ~ wear bushing (7-1/16" ID). I j I ~ 1 j Weld piece of 3/8" cold roll onto a 1" "T" bar. Attempt to hook clamp. ~ No luck. Prepare a joint of 7-5/8" casing to sit on top of FMC wear l I I I 1 bushing to rotary table (3T length). Puli 40' Try to bring clamp up to I I I j ~ I I floor while ullin 4"drill i e. One tool oint ulled to rota table--no P 9 P P 1 P ry ~ I I ~ clamp. Stand back stand. Pull 2 joints of 4". Remove joint of 7-5/8". ~ i I I Prepare to shorten joint of 7-518" by 2' (total length 35') to allow to be I I I ~ i left in stack below rotary table while pulling pipe. I I i i While shortening the joint of 7-518" casing, attempted to fish w/ 1" T bar j j & 318"hook again. ~ j ! I Note: Hooked clamp and retrieved the clamp to rig floor @ 0100 hrs I ~ I I,1-25-2006. j i ~ ~ ~ Fluid lost to well f! 1800 hrs to midnight = 10 bbls I i I Tot I fluid lost t well midni ht - 13715 bbls. , a o @ g Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1C-20 Page 55 of 57 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: ROT -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 1/28/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 1 /25/2006 1126!2006 From - To 00:00 - 01:00 01:00 - 01:45 01:45 - 11:45 11:45 - 12:00 ~ I I 12:00 - 12:45 ~I 12:45 - 13:15 ~ 13:15 - 14:15 14:15 - 14:30 14:30 - 00:00 00:00 - 00:00 - 06:00 06:00 - 08:15 Hours i Code 'Sub 'Code 1.00 CASE i OTHR I I I i I 0.75 CASE ~ SFTY 10.00 CASE ~OTHR I I Phase PROD PROD PROD 0.25 ~ CASE I OTHR !PROD j I 0.75 II CASE i OTHR ~ PROD 0.50 ~ CMPLTNI OTHR ~ PROD 1.00 CMPLTNI RURD ~ PROD 0.25 i CMPLTNI SFTY ~ PROD I I 9.50 ~ CMPLTNI RUNT ~ PROD CMPLTNI I PROD 6.00 CMPLTNI RUNT ~ PROD 2.25 CMPLT NI RUNT I PROD Description of Operations Attempt to fish out of well, the Western Well Tool/ Alaskan Energy Resources 4" non rotating drill pipe casing protector (patented) (NRDPCP) Heavy duty super slider top collar, Collar is in the 7-5/8" 29.7ppf (6.875" ID) casing below the FMC 7-1/16" ID x 10-13/16" OD, 1' long wear bushing. Lockdown screws for the wear bushing @ 36.25' f/ rig floor. Pull Weatherford 4" HT 38 drill pipe (5" OD tool joint) while observing hole fJ signs of the collar still in hole. Collar (5-112" OD x 4-3/4" length) could be seen below FMC wear bushing (7-1116" ID. Using a hook made w/ 318" cold roll welded to a 1" T bar, attemt to fish Western WeII Tool upper collar f/ well. Successful in retrieving collar in one peke. Pictures posted to well folder on the "x" drive. 3 bolt heads broken. PJSM on POOH w/ Weatherford 4" HT 38 DP, removing Western Well Tool 4" NRDPCP Heavy duty super slider. POOH UD Weatherford 4" HT 38 DP. Remove 34 Western Well Tool/ Alaskan Energy Resources 4" non rotating drill pipe casing protectors (patented) (NRDPCP) Heavy duty super sliders. RIH 10 stands f/ derrick. Continue Laying down dp & super sliders. All 149 Western Well Tool Super sliders layed down. Lay down and service break Baker Oil Tools liner running tool. Calculated fill 94 bbls, actual fill 127 bbls. Fluid losses midnight to noon = 47 bbls Total fluid losses to well @ noon = 13752 bbls. Clear floor. Lay down crossovers, super sliders and collars for super sliders. UD 3-112" elevators and some bits. Drain stack and pull FMC wear bushing. Rig up to run 4-112" completion. PJSM on running 4-1/2" completion w/ Rig supervisor, Baker Oil Tool hand, GBR and Rig crew. PU/MU Baker Oil Tools mule shoe w/ 4.75" OD seals, seal sub seal spacer tube, seal spacer tube, baker 5.5" OD locator, 4-112" 12.6 ppf L-8D IBT-M tubing pup, 26 joints 4-112" 12.6 ppf IBT-M tubing, 4-1 /2" 12.6 ppf L-80 tubing pup, Baker CMU (closed) w 3.813" BX profile, 4-1 /2" 12.6 ppf L-80 IBT-M pup, 284 joints 4-112" 12.6 ppf L-80 IBT-M tubing @ midnight to 9610'. Total of 310 joints in hole @ midnight. Fluid losses f/ noon to midnight =zero Total fluid losses to well = 13762 bbls. Continue running 4-1/2" completion f/ 9610' to 15366': 107 joints 4-1/2" 12.6 ppf IBT-M tubing, 4-1/2" 12.6 ppf L-80 tubing pup, Schlumberger/Camco KBG-2-1 R GLM w/ BEK latch DCK-2 shear out valve set @ 3000 psi, 4-1/2" 12.6 ppf L-80 IBT-M pup, 78 jts 4-112" 12.6 ppf L-80 IBT-M tubing. Total of 495 jts in hole @ 0600 hrs. Depth @ 0600 hrs= 15366' Filled tubing @ 408 jts in hole (12678'), circ 20 bbls volume @ 25 spm w/ 225-200 psi, 23% flow line indicator. No fluid losses f/midnight to 0600 hrs Total fluid lost to well @ 0600 hrs = 13762 bbls. Continue running 4-1/2" completion f! 15366' to 17526'.:54 joints 4-112" 12.6 ppf L-80 IBT-M tubing, SchlumbergerlCamco "DB" nipple w! 3.875" no go profile, 15 jts 4-1 /2" 12.6 ppf L-80 IBT-M tubing. Total of 564 joints of tubing in hole. Printed: 2/16/2006 4:D3:41 PM ConocoPhiilips A(aska Page 56 of 57 Operations Summary Report Legal Well Name: 1C-20 Common Well Name: 1C-20 Spud Date: 11/21/2005 Event Name: RO7 -DRILLING Start: 11/18/2005 End: 1/28/2006 Contractor Name: D1 5CM@conocophillips.com Rig Release: 1!28!2006 Group: Rig Name: Doyon 15 Rig Number; 15 .Date From - To Hours ' Code :Code'. Phase ___---,___ _,_____ _ __ ' Descnptian of Operations .________ ____ _____---_ _:_ _______ 1!2612006 08:15-09:00 0.75 CMPLTNI OTHR j PROD ~ MU circulating head pin w/ crossover to 4-1 /2" lBT on jt # 565. RU 2" I ~ j circ hose, fill pipe. PU wt 200k, SO wt 108k, blocks 70k. j 09:00 - 09:30 j 0.501 CMPLTN CIRC ~ PROD j Establish circulation. Circ @ 38 gpm (9spm) w/ 900 psi. High I I 09:30 - 09:45 ~ ~ ~ 0.25 CMPLTNI OTHR PROD ~ pressure??. ~ Trouble shoot surface equipment. Inspect low torque valve, OK. I i ~ ~ ~ Remove bell guide on top drive to allow circulating assembly to fit better 1 i 09:45 - 11:30 i ~ 1.75 CMPLTNI CIRC ~ PROD ~ under top drive. I Circulate bottoms up stagging pump up f/ 2 bpm (21 spm) w/ 1188 psi- 1 ~ ~ 17% flow, 3 bpm(31 spm) w/ 700 psi- 22% flow, 5 bpm( 50 spm) w! 650 111:30 - 12:30 ` 1 00 CMPLTN SOHO PROD psi- 27°!° flow Takin weight Attem t to locate seals in Baker Seal bore extension 112:30 - 13:00 I . j I I 0.50' CMPLTN SOHO PROD p . g , set down 15k, PU and wash down past 17541', 17552', 17553' I Locate seals @ 17562'. Continue to slack off 1T and set down 20k on 113:00 - 13:45 ' I 0.75 i CMPLTNI DEQT I PROD ~ no go @ 17579'. Tubing Tally difference is 1T deep to liner tally. Rig down and blow down circulating lines. RU to test annulus to 1000 i t j I psi f/ 10 min. w/mule shoe @ 17579'. Good test. Rig down and blow I 113:45 - 14:45 i ~ ~ 1.00 CMPLTN SOHO I PROD ~ down same. Lay down joint # 566, 565 and 564. PU/MU 9.83' pup joint and then joint I I I ~ # 564, MU FMC 10.85" OD hanger and landing joint w/ 4-1/2" NSCT threads on pin & 4-1/2" IBT threads on top box. Rig up to circ and I 1 j ~ 1 displace well f! 9.8 ppg flo Pro to 9.8 ppg brine w/ hanger 30' away 1 j ~ I f/landed. Mule shoe @ 17545' inside of locator postion of 17541' i (extension of ZXP liner top packer). 114:45 - 17:15 I ~ 2.501 CMPLTNI CIRC PROD I Pump 35 bbls spacer and displace well w/ 9.8 ppg brine. Pump @ 297 1 j 17:15 - 18:00 ' ~ ~ 0.751 CMPLTN CIRC I PROD I gpm w! 830 psi. Move Vac trucks. Pump 180 bbls of planned total 341 bbls of 9.8 ppb j 18:00 - 20:00 i I 2.00 CMPLTN CIRC I PROD I brine w/ 1% corrosion inhib. Pump @ 293 gpm w/ 750 psi. Chase corrosion inhibited brine w/ 2653 strokes (267 bbls) brine. Pump 120:00 - 21:30 I I 1.50 CMPLTN SOHO PROD @ 270 gpm w/ 650 psi. I RIH w! hanger and land tubing :RIH mule shoe f/ 17545' to 17575'. I I ~ 21:30 - 22:30 i ~ 1.00 CMPLTN DEQT ~ PROD 1This is 4' above fully located. RU to test 7-5/8" x 4-1/2" annulus. Test 7-5/8" x 4-1/2"Annulus to 1000 psi f! 10 min. Good test. Rig down I 122:30 - 23:00 ~ 0.50 CMPLTN PULD ~ PROD I test equipment. Blow down. Back out and fay down 4-1/2 NSCT pin x 4-1/2" IBT landing joint. 123:00 - 23:30 1 0.501 WELCTL~ OTHR 1 PROD ~ PU backpressure valve running tool (T bar), Install back pressure valve. 123:30 - 00:00 I 0.501 DRILL I PULD I PROD 1 PJSM on laying down 8 stands of 4" Weatherford drill pipe f/ derrick. ~ I I j I This is the pipe that went through high dogleg at end of well. Install ~ ~ j ~ ~ mouse hole in rotary table. I 1 1127/2006 ~ 00:00 - 01:00 ~ ~ I 1.001 DRILL I PULD I PROD I j Lay down 8 stands of 4" Weatherford drill pipe f! derrick. This is the I pipe that went through high dogleg at end of well. Use mouse hole in I ~ 101:00 - 01:15 j I I 0.251 WELCTL SFTY I PROD rotary table. I PJSM on changing top pipe rams f/ 4" to 4-1/2" x 7". 01:15 - 03:00 i 1.75 ~ WELCTI~ OTHR ~ PROD 1 Change top pipe rams f/ 4" to 4-1l2" x 7" variables. Clean pollution drip j 03:00 - 03:15 ~ ~ 0.251 WELCTI~ SFTY I PROD Ipans. I PJSM on nippling down BOPE. 03:15 - 09:45 ~ 6.501 WELCTy NUND I PROD ~ Nipple down BOPE. Set back stack. I I I j Total fluid lost to well =13820 bbls. Yesterday lost 58 bbls white circ) I 1 j 09:45 - 12:00 j I 2.25 WELCT NUND j PROD I displace. I NU 11" 5m x 4-1/2" 5m adapter flange and tree. Test tree neck and I I I ~ hanger body seals to 250 psi low and 5000 psi high f! 10 minutes each. 12:00 - 13:00 I ~ 1.001 WELCT OTHR ~ PROD ~ PU lubricator. Pull CIW type H Back pressure valve. Well on a vac. ~ i , j I Install two way check. Printed: 2/16/2006 4:03:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-20 Common Well Name: 1 C-20 Spud Date Event Name: ROT -DRILLING Start: 11/18/2005 End: Contractor Name: D15CM@conocophillips.com Rig Release: 1!28!2006 Group: Rig Name: Doyon 15 Rig Number: 15 Page 57 of 57 11 /21 /2005 1 /28/2006 Date From - To ' -Hours ! Code ~ Sub 'Phase ; Description of Operations ,Code! 1/27/2006 ~ 13:00 - 14:15 ~ 1.25 i WELCTL~ OTHR ~ PROD I Fill tree w/diesel. Test tree and straight bore metal seal to 250 psi low 14:15 - 14:45 ~ 0.50 WELCT OTHR ~ PROD and 5000 psi high. Hold each test 10 min. Pull two way check valve w/ lubricator. 114:45 - 15:15 ~ ~ 15:15 - 15:30 ~ 0.501 0.25 ~ CMPLTN DEQT CMPLTN SFTY ~ PROD PROD I Fill tubing w/ water. Rig up hot oil and circulating lines. PJSM w/ hot oil on performing mechanical intergrity test on 7-5/8" x (15:30 - 16:15 I:1 ~ 0.75 ~ ~ ~ CMPLTNI DEQT i PROD ~ 4-1/2" annulus. Hot oil pump diesel and test inner annulus (7-5/8" x 4-1 i2") to 2500 psi for 30 minutes chart test I i 116:15 - 19:30 ~ 3.25 ~ CMPLTNI DEQT ~ PROD j . Attempt to shear DCK-2 shear valve in GLM @ 4600.81'. Rock ~ ~ ~ ~ i ~ pressure back and forth w/ Little Red f/ 4500 psi to 2500 psi. Check 119:30 - 20:00 ~ 20:00 - 22:30 ! 0.50 ~ 50 2 CMPLTN SFTY ~ CMPLTNI OTHR PROD PROD I j surface equipment- OK. ~ Bleed off pressure to zero. PJSM w/ FMC hand_ Lay down two way check and lubricator , 22:30 - 23:00 ! . 0.50 CMPLTN SFTY j PROD . PJSM w/ Halliburton slick line and Little Red on Rigging up lubricator I 123:00 - 00:00 ~ I 1.001 ~ CMPLTN SLIN ~ PROD ~ and tools to pull GLM valve (DCK-2). PU and Rig up HOWCO slickline tools to retrieve DCK-2 Shear valve wl 1/28/2006 100:00 - 01:00 ~ 1.00 ~ CMPLTN SLIN PROD 1 1 BEK latch. PU and Rig up HOWCO slickline tools to retrieve DCK-2 Shear valve w/ 01:00 - 01:30 j 0.5011 CMPLTNI SEOT PROD BEK latch. Little Red pressure test HOWCO lubricator w/diesel. Test to 1000 psi f/ I I 01:30 - 02:00 0.50 ~ j 1 CMPLTNI SLIN I PROD j ~ I 10 min. OK. Bleed off pressure. RIH w/ HOWCO slickline (.125") and tool string w/ kickover tool (overall 32' includes 2-118" OD roller stem w/ 2-9/16" OD rollers 1-13/16" OD I , , knuckle jts, and jars w/ 1-718" OD) to retrieve DCK-2 shear valve in II 02:00 - 02:30 ~ 0.5011 ~ CMPLTN SLIN I PROD I KBG-2 GLM @ 4600'. Locate bottom of manrel @ 4612' slickline measurement f/ rig floor. Jar 1, j 02:30 - 03:00 j 0.501 I CMPLTN SLIN PROD I twice. I POOH w/ HOWCO slickline f/ 4612' slickline measurement. Retrieved ' j I dummy valve, not aDCK-2 shear valve f/ GLM @ 4600'MD (2533.4 I f I I TVD @ 70 degrees) tubing tally measurement (4612' slickline 03:00 - 04:00 ~ 104:00 - 04:30 j ] 1.00 0.50 ~ CMPLTNI SLIN CMPLTNI SFTY PROD PROD measurement). Rig down HOWCO lubricator and slickline tool string. I PJSM on freeze protecting 7-5/8" x 4-112" annulus (IA) with Little 04:30 - 06:00 j 1 50 i CMPLTN FRZP i PROD Red/Hot Oil and rig crew. Little Red /Hot Oil pressure test lines to 2500 psi freeze protect 7-5/8" 1 . , I " " " ~ ~ ( x 4-1/2 annulus to csg x 4-1/2 tbg (IA) with 100 bbls diesel into 7-5/8 1 ~ I I I ~ 1381 T MD/ 2246' TVD. Pump 103 bbls @ 1 bpm w/ initial circ pressure ~ J I of zero and final of 400 psi. Fluid returns (9.8 ppg brine-NACI) to pits 06:00 - 07:00 j 1 1.001 I CMPLTNI FRZP PROD 1101 bbls. I Rig down Little Red/Hot Oil. "U" tube diesel f! annulus to tubing. 100 I I ~ 11 bbls diesel will leave diesel in both the inner annulus (7-518" x 4-1/2") I i, I i and the 4-112" tubing to 2415' MD/ 1890' TVD. Note: Base of permafrost 107:00 - 07:30 0.50 j CMPLTNI OTHR PROD 1 @ 1810' TVD= 2212' MD !Blow down and rig down cirulating lines f/ well. ~ 07:30 - 09:00 ! 1.50 WELCTL~ OTHR I PROD I Install BPV w/ lubricator. Rig down lubricator. Recored tubing pressure I 09:00 - 09:30 0.5011 WELCT, OTHR PROD ! = 50 psi, IA (7-5/8" x 4-1/2") = 210 psi, OA( 10-314" x 7-518" = 700 psi. 1 Remove double valve on annulus of 7-518" x 4-1J2". Secure weN. ~ 09:30 - 10:00 j 0.50 ~ 1 CMPLT ~ OTHR ~ PROD ~ Secure cellar, move knife valve. 10:00 - j CMPLTNI PROD j Rig released f/ 1 C-20 for move to 1 D-41, (4.8 mile move) @ 1000 hrs ~ I ~ ~ I i 1-28-2006. Printed: 2/16/2006 4:03:41 PM . Halliburton Company Global Report (~nwpan~: ConocoPhillipsAlaska Inc. I)a~c 2r16;2006 I~in~r. 14.33:24 Pa~,c: 1 Ficl~l: Kuparuk: River Unit Cu-urdinatclAI.) Kc fcrcnce: Well_ 1C-20, True North , Jifc: Kuparuk 1C Pad ~crtical ("I'~~I)~ Kcic rcncc: 1C-20: 10'1.2 f \~'cll: iC-20 ~ectiun (lti) licfcrc ucc Well (0.OON.O-OOE.°0.50Azi) li'ellpath: 1 G20 Surcec ('alculatiun ~lethud: Minimum Curvatu re ~ 1)h: Oracle -- Survey: -- Start Date: -- - _ Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnefic Model: bggm2005 Site: Kuparuk 1 C Pad Site Position: Northing: 5968522.46 ft Latitude: 70 19 28.285 N From: Map Easting: 562372 .05 ft Longitude: 149 29 39.293 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.48 deg Well: 1 C-20 Slot Name: Well Position: +N/-S 100.82 ft Northing: 5968622 .03 R r Latitude: 70 19 29.277 N +E/-W -149.13 ft Eas~i'ng ; 562222 .10 ft ~ .Longitude: 149. 29 43.646 W _ Position Uncertainty: 0.00 ft _ ' - Wellpath: 1C-20 Drilled From: 1C-20PB1 500292327300 Tie-on Depth: 17897.69 ft Current Datum: 1 C-20: Height 101 .20 ft Above System Datum: .Mean Sea Level Magnefic Data: 11/19/2005 Declination: 24.31 deg Field Strength: 57569 uT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.60 0.00 0.00 90.50 Survey Program for Definitive Wellpath Date: 2/16/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 181.00 1058.00 1 C-20PB1 gyro (181.00-1 058.00) CB-GYRO-SS Camera based gyro single shot 1142.32 17897.69 1C-20P61 (1142.32-1850 5.24) (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 17900.00 21008.62 1C-20 (17900.00-21008.6 2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey X11) Intl ~iim I11) S ~,'I~~~D '~'/,S l~:a~~ )lap,A' ~~lapl: huol ft deg deg ft ft ft ft ft ft 40.60 0.00 0.00 40.60 -60.60 0.00 0.00 5968622.03 562222.10 TIE LINE 181.00 0.25 185.64 181.00 79.80 -0.30 -0.03 5968621.72 562222.07 CB-GYRO-SS 272.00 1.04 172.05 271.99 170.79 -1.32 0.06 5968620.71 562222.18 CB-GYRO-SS 362.00 3.18 144.11 361.93 260.73 -4.15 1.64 5968617.89 562223.78 CB-GYRO-SS 458.00 6.40 147.04 457.58 356.38 -10.80 6.11 5968611.28 562228.30 CB-GYRO-SS 558.00 10.08 158.17 556.54 455.34 -23.61 12.40 5968598.53 562234.70 CB-GYRO-SS 658.00 13.79 164.64 654.36 553.16 -43.23 18.82 5968578.96 562241.27 CB-GYRO-SS 758.00 18.71 178.86 750.38 649.18 -70.79 22.30 5968551.44 562244.98 CB-GYRO-SS 858.00 22.72 178.32 843.89 742.69 -106.14 23.18 5968516.10 562246.16 CB-GYRO-SS 958.00 25.08 167.57 935.36 834.16 -146.16 28.31 5968476.12 562251.62 CB-GYRO-SS 1058.00 27.58 163.24 1024.98 923.78 -189.04 39.55 5968433.34 562263.22 CB-GYRO-SS 1058.60 27.58 163.24 1025.51 924.31 -189.30 39.63 5968433.08 562263.30 CB-GYRO-SS 1142.32 32.38 160.60 1098.01 996.81 -229.03 52.68 5968393.47 562276.67 MWD+IFR-AK-CAZ-SC 1235.91 36.88 158.24 1175.01 1073.81 -278.78 71.42 5968343.88 562295.82 MWD+IFR-AK-CAZ-SC 1332.65 38.37 157.36 1251.63 1150.43 -333.45 93.74 5968289.40 562318.60 MWD+IFR-AK-CAZ-SC 1428.01 38.99 157.70 1326.07 1224.87 -388.53 116.52 5968234.52 562341.83 MWD+IFR-AK-CAZ-SC 1523.25 41.34 155.44 1398.85 1297.65 -444.87 140.97 5968178.39 562366.74 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('nmpan~: ConocoPhillipsAlaska Inr. llafc: 2116!2006 fink. 14:33'24 Pair. 2 Ficlil: Ku paruk River Unit C~a-urd inatc~A'I:) Re fcrcucc: Well: 1 C-20, True North ~tiire: Ku paruk 1C P ad Fcitia il (~~~`~I Kcfr rcncc: 1G 20: 101.2 ~~'rll: 1 G 20 ~cclion (~ti~ kcfcrc ncc: Well i0.00N 0 00E 90-50Azi) ~~~cllpath: 1C-?0 tiunc} ("calculation ~lctho~l: Min imum Curvatur e Uh: Orarle tiur~c~ ~lll Intl ~zim l~~ D 5cs I1~U \iti I~:a1 ~lalaA ~laph; fool ft deg deg ft ft ft ft ft ft 1619.65 45.04 156.98 1469.12 1367.92 -505.24 167.55 5968118.25 562393.82 MWD+IFR-AK-CAZ-SC 1712.77 46.39 155.86 1534.14 1432.94 -566.33 194.22 5968057.39 562420.99 MWD+IFR-AK-CAZ-SC 1809.03 51.81 153.05 1597.15 1495.95 -631.90 225.64 5967992.08 562452.95 MWD+IFR-AK-CAZ-SC 1903.07 55.93 151.68 1652.59 1551.39 -699.17 260.89 5967925.12 562488.75 MWD+IFR-AK-CAZ-SC 1998.09 58.51 152.07 1704.03 1602.83 -769.62 298.54 5967854.99 562526.98 MWD+IFR-AK-CAZ-SC 2093.09 60.17 152.22 1752.47 1651.27 -841.87 336.72 5967783.07 562565.76 MWD+IFR-AK-CAZ-SC 2190.73 61.77 151.92 1799.85 1698.65 -917.29 376.71. 5967707.98 562606.36 MWD+IFR-AK-CAZ-SC 2285.39 65.34 152.55 1842.00 1740.80 -992.28 416.18 5967633.33 562646.45 MWD+IFR-AK-CAZ-SC 2379.10 69.29 152.27 1878.13 1776.93 -1068.89 456.22 5967557.06 562687.12 MWD+IFR-AK-CAZ-SC 2474.47 72.34 153.21 1909°47 1808.27 -1148.95 497.46 5967477.35 562729.02. MWD+IFR-AK-CAZ-SC . 2569.35 74.40 151.77 1936.63 1835.43 -1229.58 539.45 5967397.09 562771.68 MWD+IFR-AK-CAZ-SC 2664.61 75.95 147.49. 1961.01 1859.81 -1309.00 586.01 5967318.06 562818.89 MWD+IFR-AK-CAZ-SC 2758.56 73.44 145.29 1985.81 1884.61 -1384.46 636.15 5967243.02 562869.65 MWD+IFR-AK-CAZ-SC 2854.35 72.31 143.19 2014.02 1912.82 -1458.74 689.64 .5967169.19 562923.75 MWD+IFR-AK-CAZ-SC 2949.70 72.98 141.61 2042.46 1941.26 -1530.84 745.17 5967097.56 562979.87 MWD+IFR-AK-CAZ-SC 3046.00 74.25 140.87 2069.63 1968.43 -1602.88 803.01 5967026.01 563038.30 MWD+IFR-AK-CAZ-SC 3139.04 74.63 137.99 2094.59 1993.39 -1670.96 861.30 5966958.43 -- 563097.14 MWD+IFR-AK-CAZ-SC 3234.22 73.91 138.22 2120.39. 2019.19 -1739.15 922.48 5966890.75 563158.88 MWD+IFR-AK-CAZ-SC 3332.27 73.47 138.36 2147.93 2046.73 -1809.40 985.09 5966821.03 563222.06 MWD+IFR-AK-CAZ-SC 3422.26 75.15 136.50 2172.26 2071.06 -1873.20 1043.70 5966757.73 563281.19 MWD+IFR-AK-CAZ-SC 3529.73 75.69 132.40 2199.33 2098.13 -1946.01 1117.93 5966685.54 563356.02 MWD+IFR-AK-CAZ-SC 3626.97 75.59 131.18 2223.45 2122.25 -2008.79 1188.17 5966623.35 563426.77 MWD+IFR-AK-CAZ-SC 3719.92 75.74 131.44 2246.46 2145.26 -2068.24 1255.81 5966564.47 563494.90 MWD+IFR-AK-CAZ-SC 3818.35 73.77 130.58 2272.34 2171.14 -2130.55 1327.47 5966502.76 563567.06 MWD+IFR-AK-CAZ-SC 3911.23 71.18 130.84 2300.31 2199.11 -2188.31 1394.60 5966445.56 563634.66 MWD+IFR-AK-CAZ-SC 4008.21 69.97 132.34 2332.56 2231.36 -2249.02 1463.00 5966385.43 563703.56 MWD+IFR-AK-CAZ-SC 4102.28 70.48 133.69 2364.39 2263.19 -2309.41 1527.72 5966325.59 563768.77 MWD+IFR-AK-CAZ-SC 4197.12 70.54 133.57 2396.03 2294.83 -2371.10 1592.44 5966264.45 563833.99 MWD+IFR-AK-CAZ-SC 4293.92 72.25 134.12 2426.91 2325.71 -2434.64 1658.60 5966201.45 563900.67 MWD+IFR-AK-CAZ-SC 4387.86 69.96 133.91 2457.33 2356.13 -2496.40 .1722.51 5966140.24 563965.08 MWD+IFR-AK-CAZ-SC 4483.91 68.19 133.73 2491.64 2390.44 -2558.51 1787.24 5966078.67 564030.32 MWD+IFR-AK-CAZ-SC 4579.95 69.38 .133.27 2526.39 2425.19 -2620.14 1852.18 5966017.59 564095.76 MWD+IFR-AK-CAZ-SC 4675.15 70.97 132.10 2558.68 2457.48 -2680.85 1918.01 5965957.43 564162.09 MWD+IFR-AK-CAZ-SC 4768.84 71.82 131.28 2588.57 2487.37 -2739.91 1984.32 5965898.93 564228.88 MWD+IFR-AK-CAZ-SC 4863.92 69.80 131.30 2619.82 2518.62 -2799.16 2051.79 5965840.25 564296.83 MWD+IFR-AK-CAZ-SC 4960.90 73.04 128.27 2650.72 2549.52 -2857.95 2122.42 5965782,05 564367.94 MWD+IFR-AK-CAZ-SC 5052.78 73.29 128.67 2677.33 2576.13 -2912.66 2191.28 5965727.92 564437.24 MWD+IFR-AK-CAZ-SC 5147.77 71.70 127.65 2705.90 2604.70 -2968.63 2262.50 5965672.55 564508.92 MWD+IFR-AK-CAZ-SC 5238.03 75.52 125.66 2731.37 2630.17 -3020.30 2331.96 5965621.46 564578.80 MWD+IFR-AK-CAZ-SC 5339.98 74.44 125.70 2757.79 2656.59 -3077.73 2411.94 5965564.70 564659.25 MWD+IFR-AK-CAZ-SC 5431.85 72.69 125.69 2783.78 2682.58 -3129.14 2483.50 5965513.89 564731.23 MWD+IFR-AK-CAZ-SC 5526.87 71.32 126.19 2813.14 2711.94 -3182.18 2556.67 5965461.46 564804.82 MWD+IFR-AK-CAZ-SC 5623.37 72.47 126.11 2843.12 2741.92 -3236.29 2630.73 5965407.97 564879.32 MWD+IFR-AK-CAZ-SC 5720.73 70.88 125.30 2873.73 2772.53 -3290.23 2705.78 5965354.66 564954.81 MWD+IFR-AK-CAZ-SC 5815.60 72.37 122.96 2903.64 2802.44 -3340.73 2780.30 5965304.79 565029.74 MWD+IFR-AK-CAZ-SC 5910.32 72.25 122.72 2932.43 2831.23 -3389.67 2856.12 5965256.48 565105.95 MWD+IFR-AK-CAZ-SC 6004.89 71.64 119.86 2961.74 2860.54 -3436.36 2932.94 5965210.43 565183.15 MWD+IFR-AK-CAZ-SC 6098.99 69.75 119.98 2992.85 2891.65 -3480.66 3009.91 5965166.78 565260.48 MWD+IFR-AK-CAZ-SC 6191.59 68.52 121.21 3025.83 2924.63 -3524.69 3084.39 5965123.37 .565335.32 MWD+IFR-AK-CAZ-SC 6286.94 69.41 122.37 3060.06 2958.86 -3571.58 3160.04 5965077.12 565411.34 MWD+IFR-AK-CAZ-SC 6389.25 71.40 122.94 3094.37 2993.17 -3623.58 3241.18 5965025.79 565492.90 MWD+IFR-AK-CAZ-SC 6484.10 71.58 124.13 3124.48 3023.28 -3673.27 3316.15 5964976.73 565568.27 MWD+IFR-AK-CAZ-SC 6578.97 69.48 122.69 3156.10 3054.90 -3722.52 3390.80 5964928.10 565643.33 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('nm~i;w,: ConoroPhillipsAlaska Inc. Usa•: 2.16/2006 l~imr. 14:324 Pa<~r. 3 Fidel: Kupanik River Unit Cu-unlina~tc(\E) Reference: WeIL 1C-20. True North tiife: Kuparuk 1L Pad ~crtical I~III)) Kcli~rcncc: 1C-20:101.2 11c11: 1C-20 ~cctiun ('til Reference: Well (O.OON,O-OOE,90 50Azij ~1~cll~~.uh: 1C-20 ~ur~c} Calculation ~Ic[ho~l: Minimum Curvature Ilh: Oracle tiurci~c ~lU Ind Azini 1~'D Sys 7111 \;:ti I~a1~' 11n~iA ~ia~~l~: Tui~l ft deg deg ft ft ft ft ft ft 6675.50 72.87 120.03 3187.25 3086.05 -3770.04 3468.81 5964881.24 565721.72 MWD+IFR-AK-CAZ-SC 6770.76 73.66 119.96 3214.68 3113.48 -3815.65 3547.82 5964836.29 565801.09 MWD+IFR-AK-CAZ-SC 6865.88 74.08 121.00 3241.11 3139.91 -3862.00 3626.57 5964790.60 565880.22 MWD+IFR-AK-CAZ-SC 6960.71 74.07 116.12 3267.14 3165.94 -3905.58 3706.63 5964747.69 565960.63 MWD+IFR-AK-CAZ-SC 7057.09 73.93 114.01 3293.71 3192.51 -3944.82 3790.55 5964709.15 566044.86 MWD+IFR-AK-CAZ-SC 7148.43 73.81 11.4.07 3319.08 3217.88 -3980.57 3870.68 5964674.07 566125.28 MWD+IFR-AK-CAZ-SC 7243.79 72.76 113.70 3346.51 3245.31 -4017.55 3954.19 5964637.79 566209.09 MWD+IFR-AK-CAZ-SC 7339.43 72.00 114.22 3375.46 3274.26 -4054.57 4037.49 5964601.47 566292.68 MWD+IFR-AK-CAZ-SC 7434.75 71.55 114.06 3405.27 3304.07 -4091.59 4120.11 5964565.13 566375.60 MWD+IFR-AK-CAZ-SC 7529.41 71.35 113.46 3435.39 3334.19 -4127.75 4202.24 5964529.66 566458.02 MWD+IFR-AK-CAZ-SC 7624.54 69.85 114.28 3466.98 3365.78 -4164.06 4284.29 5964494.04 566540.36 MWD+IFR-AK-CAZ-SC 7719.12 67.75 116.03 3501.19 3399.99 -4201.53 4364.11 5964457.23 566620.47 MWD+IFR-AK-CAZ-SC 7814.27 66.42 115.94 3538.23 3437.03 -4239.92 4442.89 5964419.49 566699.56 MWD+IFR-AK-CAZ-SC 7910.83 66.16 117.05 3577.06 3475.86 -4279.36 4522.01 5964380.71 566779.00 MWD+IFR-AK-CAZ-SC 8006.40 65.73 118.54 3616.02 3514.82 -4320.06 4599.21 5964340.67 566856.53 MWD+IFR-AK-CAZ-SC 8100.92 69.73 122.91 3651.85 3550.65 - -4364.76 4674.34 5964296.59_ 566932.02 MWD+IFR-AK-CAZ-SC 8196.36 68.96 124.04 3685.51 3584.31 -4414.02- 4748.83 5964247.96 567006.91 MWD+IFR-AK-CAZ-SC 8292.64 73.90 122.89 3716.17 3614.97 -4464.32 4824.95 5964198.30 567083.43 MWD+IFR-AK-CAZ-SC 8386.46 76.72 122.22 3739.96 3638.76 -4513.14 4901.43 5964150.11 567160.32 MWD+IFR-AK-CAZ-SC 8478.18 75.89 120.16 3761.67 3660.47 -4559.29 4977.66 5964104.60 567236.91 MWD+IFR-AK-CAZ-SC 8576.86 75.77 117.97 3785.83 3684.63 -4605.77 5061.28. 5964058.82 567320.91 MWD+IFR-AK-CAZ-SC 8672.06 75.94 117.60 3809.10 3707.90 -4648.80 5142.95 5964016.47 567402.93 MWD+IFR-AK-CAZ-SC 8766.27 74.62 116.31 3833.04 3731.84 -4690.11 5224.17 5963975.85 567484.47 MWD+IFR-AK-CAZ-SC 8861.85 73.91 116.89 3858.96 3757.76 -4731.30 5306.43 5963935.34 567567.06 MWD+IFR-AK-CAZ-SC 8957.42 73.69 118.54 3885.62 3784.42 -4773.98 5387.67 5963893.34 567648.65 MWD+IFR-AK-CAZ-SC 9052.78 74.07 117.07 3912.10 3810.90 -4816.71 5468.70 5963851.29. 567730.02 MWD+IFR-AK-CAZ-SC 9148.85 71.77 114.00 3940.32 3839.12 -4856.30 5551.54 5963812.39. 567813.18 MWD+IFR-AK-CAZ-SC 9244.49 71.09 115.93 3970.78 3869.58 -4894.56 5633.72 5963774.82 567895.67 MWD+IFR-AK-CAZ-SC 9338.95 70.99 117.03 4001.47 3900.27 -4934.39 5713.69 5963735.65 567975.96 MWD+IFR-AK-CAZ-SC 9433.97 71.15 116.46 4032.30 3931.10 -4974.84 5793.95 5963695.87 568056.55 MWD+IFR-AK-CAZ-SC 9528.87 71.06 116.54 4063.03 3961.83 -5014.90 5874.30 5963656.48. 568137.22 MWD+IFR-AK-CAZ-SC 9624.49 71.12 116.19 4094.02 3992.82 -5055.07 5955.35 5963616.99 568218.59 MWD+IFR-AK-CAZ-SC 9719.73 71.16 115.82 4124.81 4023.61 -5094.59 6036.36 5963578.15 568299.91 MWD+IFR-AK-CAZ-SC 9813.38 69.82 117.46 4156.08 4054.88 -5134.16 6115.25 5963539.24 568379.13 MWD+IFR-AK-CAZ-SC 9909.33. 69.31 117.62 4189.58 4088.38 -5175.73 6194.98 5963498.33 568459.19 MWD+IFR-AK-CAZ-SC 10004.85 70:10 119.92 4222.72 4121.52 -5218.85 6273.50 5963455.87 568538.05 MWD+IFR-AK-CAZ-SC 10099.96 70.56 120.16 4254.73 4153.53 -5263.69 6351.03 5963411.68 568615.95 MWD+IFR-AK-CAZ-SC 10194.89 72.56 119.83 4284.76 4183.56 -5308.71 6429.02 5963367.32 568694.30 MWD+IFR-AK-CAZ-SC 10290.98 72.89 120.29 4313.29 4212.09 -5354.67 6508.43 5963322.02 568774.08 MWD+IFR-AK-CAZ-SC 10386.15 72.17 119.10 4341.87 4240.67 -5399.64 6587.29 5963277.71 568853.30 MWD+IFR-AK-CAZ-SC 10481.12 71.59 118.53 4371.40 4270.20 -5443.14 6666.37 5963234.87 568932.74 MWD+IFR-AK-CAZ-SC 10576.69 71.41 117.97 4401.73 4300.53 -5486.04 6746.21 5963192.64 569012.92 MWD+IFR-AK-CAZ-SC 10672.42 71.69 117.55 4432.02 4330.82 -5528.34 6826.57 5963151.01 569093.62 MWD+IFR-AK-CAZ-SC 10767.77 71.70 117.21 4461.97. 4360.77 -5569.97 6906.95 5963110.05 569174.33 MWD+IFR-AK-CAZ-SC 10863.81 71.67 117.20 4492.15 4390.95 -5611.65 6988.04 5963069.05. 569255.76 MWD+IFR-AK-CAZ-SC 10957.88 71.70 116.87 4521.71 4420.51 -5652.24 7067.59 5963029.12 569335.63. MWD+IFR-AK-CAZ-SC 11048.00 72.18 117.38. 4549.65 4448.45 -5691.31 7143.84 5962990.69 569412.20 MWD+IFR-AK-CAZ-SC 11063.09 71.94 117.22 4554.30 4453.10 -5697.89 7156.60 5962984.22 569425.01 MWD+IFR-AK-CAZ-SC 11110.49 71.07 117.63 4569.33 4468.13 -5718.59 7196.50 5962963.85 569465.08 MWD+IFR-AK-CAZ-SC 11205.17 71.72 117.74 4599.54 4498.34 -5760.29 7275.96 5962922.82 569544.87 MWD+IFR-AK-CAZ-SC 11298.22 71.79 119.73 4628.68 4527.48 -5802.77 7353.44 5962880.98 569622.70 MWD+IFR-AK-CAZ-SC 11395.61 72.08. 119.33 4658.88 4557.68 -5848.40 7434.00 5962836.02 569703.63 .MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('nm~c~m: ConocoPhillipsAlaska Inc- Ihuc: ?/162006 lino: 14:3324 Pa~,c: ~ Hiclil: Kuparuk River U nit ('u-i~r~ iinatclAI:) Rc fercucc: Well: 1C-20. True North ~itc: Kuparuk 1C Pad ~ertfc nl (Il Il) Kci'c rcncc: iC -20- 1012 \~cIL 1 C-20 tiectiu n <<~ti) 3tcfcrc ncc: We{I (O.OCN,000E .~J0.50Azi) 1Vcil~~:uh: 1 C-20 Sunc~~ (alcufaliun ~lctho~l: Mi nir7~um Curvatur e Ub; Oracle Snnc~ ~II1 lncl ~ziw l~U S~s~f~~l) V':S 1~71~ ~ia~~A ~Ispl~; ~frn~I ft deg deg ft ft ft ft ft ft 11490.56 71.99 119.88 4688.16 4586.96 -5893.02 7512.53 5962792.06 569782.52 MWD+IFR-AK-CAZ-SC 11585.02 71.86 120.25 4717.47 4616.27 -5938.01 7590.25 5962747.72 569860.59 MWD+IFR-AK-CAZ-SC 11681.83 70.80 117.38 4748.47 4647.27 -5982.22 7670.59 5962704.19 569941.30 MWD+IFR-AK-CAZ-SC 11777.73 70.70 116.82 4780.08 4678.88 -6023.46 7751.19 5962663.62 570022.22 MWD+IFR-AK-CAZ-SC 11872.35 70.29 116.10 4811.68 4710.48 -6063.20 7831.04 5962624.55 570102.39 MWD+IFR-AK-CAZ-SC 11966.36 70.76 115.78 4843.02 4741.82 -6101.97 7910.74 5962586.44 570182.40 MWD+IFR-AK-CAZ-SC 12061.02 70.61 115.31 4874.33 4773.13 -6140.49 7991.34 5962548.59 570263.31 MWD+IFR-AK-CAZ-SC 12154.77 72.13 115.88 4904.28 4803.08 -6178.87 8071.45 5962510.88 570343.73 MWD+IFR-AK-CAZ-SC 12251.44 72.01 116.50 4934.04 4832.84 -6219.46 8153.99 5962470.98 570426.59 MWD+IFR-AK-CAZ-SC 12346.01 73.43 118.80 4962.13 4860.93 -6261.37 8233.96 5962429.74 570506.91 MWD+IFR-AK-CAZ-SC 12441.41 72.93 120.49 4989.74 4888.54 -6306.54 8313.33 5962385.24 570586.63 MWD+IFR-AK-CAZ-SC 12536.94 72.95 120.02 5017.76 4916.56 -6352.55 8392.21 5962339.89 570665.89 MWD+IFR-AK-CAZ-SC 12631.61 73.47 118.15 5045.11 4943.91 -6396.60 8471.42 5962296.49 570745.45 MWD+IFR-AK-CAZ-SC 12727.00 73.47 116.60 5072.26 4971.06 -6438.65 8552.62 5962255.13 570826.99 MWD+IFR-AK-CAZ-SC 12818.67 72.84 117.89 5098.82 4997.62 -6478.82 8630.62 5962215.61 570905.32 MWD+IFR-AK-CAZ-SC 12918.89 72.57 118.41 5128.62 5027.42 -6523.96 8714.99 5962171.18 570990.05 MWD+IFR-AK-CAZ-SC 13014.13 72.05 118:67 5157.56 5056.36 -6567.31- 8794.70 5962128:49 571070.11 MWD+IFR-AK-CAZ-SC .13109.16 71.55 117.44 5187.24 5086.04 -6609.77 8874.37 5962086.70 571150.12 MWD+IFR-AK-CAZ-SC 13204.36 71.08 117.24 5217.74 5116.54 -6651.19 8954.47 5962045.95 571230.56 MWD+IFR-AK-CAZ-SC 13299.57 70.56 116.63 5249.02 5147.82 -6691.92 9034.64 5962005.89 571311.05 MWD+IFR-AK-CAZ-SC 13395.43 71.10 117.30 5280.49 5179.29 -6732.98 9115.34 5961965.50 571392.08 MWD+IFR-AK-CAZ-SC 13489.97 70.70 116.81 5311.43 5210.23 -6773.61 9194.90 5961925.53 571471.97 MWD+IFR-AK-CAZ-SC 13585.29 72.06 119.51 5341.87 5240.67 -6816.24 9274.53 5961883.57 571551.93 MWD+IFR-AK-CAZ-SC 13681.18 72.24 119.58 5371.26 5270.06 -6861.25 9353.93 5961839.22 571631.70. MWD+IFR-AK-CAZ-SC 13776.06 71.87 119.62 5400.49 5299.29 -6905.84 9432.42 5961795.30 571710.55 MWD+IFR-AK-CAZ-SC 13868.80 71.28 119.05 5429.81 5328.61 -6948.94 9509.12 5961752.83 571787.60 MWD+IFR-AK-CAZ-SC 13963.33 71.42 117.97 5460.04 5358.84 -6991.69 9587.82 5961710.74 571866.64 MWD+IFR-AK-CAZ-SC 14060.04 71.09 118.96 5491.12 5389.92 -7035.34 9668.33 5961667.76 571947.50 MWD+IFR-AK-CAZ-SC 14154.65 70.88 117.63 5521.94 5420.74 -7077.74 9747.09. 5961626.02 572026.60 MWD+IFR-AK-CAZ-SC 14249.04 71.09 117.42 5552.70 5451.50 -7118.98 9826.23 5961585.45 572106.07 MWD+IFR-AK-CAZ-SC. 14344.09 72.25 117.49 5582.59 5481.39 -7160.58 9906.29 5961544.52 572186.47 MWD+IFR-AK-CAZ-SC 14439.72 72.32 116.60 5611.69 5510.49 -7202.00 9987.42 5961503.77 572267.94 MWD+IFR-AK-CAZ-SC 14535.46 71.82 118.26 5641.16 5539.96 -7243.96 10068.27 5961462.49 572349.12 MWD+IFR-AK-CAZ-SC 14630.71 71.43 118.50 5671.19 5569.99 -7286.92 10147.80 5961420.19 572429.00 MWD+IFR-AK-CAZ-SC 14725.61 70.96 118.01 5701.78 5600.58 -7329.45 10226.93 5961378.33 .572508.47 MWD+IFR-AK-CAZ-SC 14820.15 71.16 117.71 5732.47 5631.27 -7371.24 10305.99 5961337.20 572587.86 MWD+IFR-AK-CAZ-SC 14915.48 71.53 120.38 5762.96 5661.76 -7415.09 10384.94 5961294:01 572667.17 MWD+IFR-AK-CAZ-SC 15011.31 71.54 120.23 5793.32 5692.12 -7460.95 10463.41 5961248.80 572746.01 MWD+IFR-AK-CAZ-SC 15105.96 70.11 118.53 5824.40 5723.20 -7504.81 10541.31 5961205.59 572824.26 MWD+IFR-AK-CAZ-SC 15201.73 71.08 118.99 5856.22 5755.02 -7548.27 10620.49 5961162.79 572903.79 MWD+IFR-AK-CAZ-SC 15289.35 72.44 117.63 5883.65 5782.45 -7587.73 10693.75 5961123.94 572977.37 MWD+IFR-AK-CAZ-SC 15391.46 71.16 116.84 5915.54 5814.34 -7632.13 10780.00 5961080.27 573063.97 MWD+IFR-AK-CAZ-SC 15486.32 72.25 118.29 5945.32 5844.12 -7673.81 10859.83 5961039.26 573144.15 MWD+IFR-AK-CAZ-SC 15581.94 73.99 118.26 5973.08 5871.88 -7717.15 10940.41 5960996.59 573225.07 MWD+IFR-AK-CAZ-SC 15678.02 73.81 117.46 5999.73 5898.53 -7760.29 11022.02 5960954.14 573307.03 MWD+IFR-AK-CAZ-SC 15772.75 73.53 116.94 6026.36 5925.16 -7801.84 11102.88 5960913.26 573388.22 MWD+IFR-AK-CAZ-SC 15867.93 73.49 116.83 6053.38 5952.18 -7843.11 11184.28 5960872.67 573469.95 MWD+IFR-AK-CAZ-SC 15963.13 73.61 116.43 6080.34 5979.14 -7884.04 11265.90 5960832.43 573551.90 MWD+IFR-AK-CAZ-SC 16058.13 74.12. 115.73 6106.74 6005.54 -7924.15 11347.86 5960792.99 573634.19 MWD+IFR-AK-CAZ-SC 16151.94 72.19 116.84 6133.92 6032.72 -7963.91 11428.36 5960753.91 573715.01 MWD+IFR-AK-CAZ-SC 16248.58 69.76 118.45 6165.43 6064.23 -8006.28 11509.29 5960712.21 573796.27 MWD+IFR-AK-CAZ-SC 16342.65 70.45 118.49 6197.44 6096.24 -8048.45 11587.05 5960670.69 573874.37 MWD+IFR-AK-CAZ-SC 16439.47 70.91 117.18 6229.47 6128.27 -8091.11 11667.84 .5960628.71 573955.51 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('nmpan~: ConpcoPhillips Alaska Inc. U,itc: 2i 1612006 ~finu~: 14:33:24 Pa~c: I~icl~: Kuparuk River Unft (~~~-urdin~itclAl~~.) Rcfi•rcncc: Well: 1C-20. True Norfh 5itc: Kuparuk 1C Pad ~~crtiril (I'~U) itcfcrcnce: 1C-20- 101.2 ~~~ell: 1 C-20 Sectiuu ~`.~~ti) Reference: Well (O.OON.O.OOE 90 50Azi) ~l'cllpath: 1C-20 ~urve~ ('alculatiun ~1cUu~d: Minimum Curvature llh: Oracle ~urcc~ 111) lucl lzim llD S~sl~1~D \1ti I~:r11' ~la~A ~Ia~~i~: I~nul ft deg deq ft ft ft ft ft ft 16533.77 71.10 116.78 6260.16 6158.96 -8131.56 11747.30 5960588.92 574035.29 MWD+IFR-AK-CAZ-SC 16629.12 71.19 116.75 6290.98 6189.78 -8172.20 11827.87 5960548.96 574116.19 MWD+IFR-AK-CAZ-SC 16724.26 71.20 115.78 6321.65 6220.45 -8212.05 11908.63 5960509.78 574197.27 MWD+IFR-AK-CAZ-SC 16819.78 72.59 113.63 6351.33 6250.13 -8249.99 11991.10 5960472.53 574280.05 MWD+IFR-AK-CAZ-SC 16915.09. 73.54 111.92 6379.10 6277.90 -8285.28 12075.17 5960437.95 574364.39 MWD+IFR-AK-CAZ-SC 17010.46 74.12 111.19 6405.66 6304.46 -8318.93 12160.36 5960405.00 574449.85 MWD+IFR-AK-CAZ-SC 17105.48 74.69 110.05 6431.20 6330.00 -8351.16 12246.02 5960373.49 574535.77. MWD+IFR-AK-CAZ-SC 17200.49 74.07 109.81 6456.79 6355.59 -8382.35 12332.04 5960343.02 574622.03 MWD+IFR-AK-CAZ-SC 17290.91 73.50 109.52 6482.03 6380.83 -8411.57 12413.80 5960314.48 574704.02 MWD+IFR-AK-CAZ-SC 17391.48 75.71 103.82 6508.75 6407.55 -8439.34 12506.64 5960287.48 574797.09 MWD+IFR-AK-CAZ-SC 17485.63 74.95 100.69 6532.60 6431.40 -8458.68 12595.63 5960268.89 574886.23 .MWD+IFR-AK-CAZ-SC 17580.44 74.88 99.19 6557.28 6456.08 -8474.48 12685.80 5960253.83 574976.51 MWD+IFR-AK-CAZ-SC 17658.08 77.75 97.65 6575.64 6474.44 -8485.52 12760.41 5960243.41 575051.21 MWD+IFR-AK-CAZ-SC 17757.51 82.13 94.99 6593.01 6491.81 -8496.27 12857.69 5960233.46 .575148.56 MWD+IFR-AK-CAZ-SC 17805.97 86.25 94.81 6597.92 6496.72 -8500.39 12905.71 5960229.75 575196.61 MWD+IFR-AK-CAZ-SC 17848.22 88.29 94.74 6599.93 6498.73 -8503.90_ 12947.76 5960226.58:.. .575238.69: MWD+IFR-AK-CAZ-SC 17897.69 91.26 94.23 6600.12 6498.92 -8507.77 12997.08 5960223.12 575288.03 MWD+IFR-AK-CAZ-SC 17900.00 91.20 94.37 6600.07 6498.87 -8507.94 12999.38 5960222.97 575290.33 MWD+IFR-AK-CAZ-SC 17957.80 89.58 96.95 6599.68 6498.48 -8513.64 13056.89 5960217.75 575347.88 MWD+IFR-AK-CAZ-SC 18014.18 88.10 99.66 6600.82 6499.62 -8521.79 13112.66 5960210.07 575403.71 MWD+IFR-AK-CAZ-SC 18107.63 91.67 98.32 6601.01 6499.81 -8536.39 13204.94 5960196.24 575496.10. MWD+IFR-AK-CAZ-SC 18203.12 94.90 96.36 6595.54 6494.34 -8548.57 13299.48 5960184.84 575590.73 MWD+IFR-AK-CAZ-SC 18296.37 95.70 95.03 6586.92 6485.72 -8557.78 13391.87 5960176.40 575683.18 MWD+IFR-AK-CAZ-SC 18389.45 92.98 94.83 6579.88 6478.68 -8565.75 13484.33 5960169.19 575775.70 MWD+IFR-AK-CAZ-SC 18481.59 92.05 92.62 6575.84 6474.64 -8571.73 13576.18 5960163.97 575867.58 MWD+IFR-AK-CAZ-SC 18570.73 85.88 91.35 6577.45 6476.25 -8574.82 13665.21 5960161.62 575956.63 MWD+IFR-AK-CAZ-SC 18675.46 86.86 90.90 6584.08 6482.88 -8576.87 13769.71 5960160.44 576061.13 MWD+IFR-AK-CAZ-SC 18768.30 88.77 85.77 6587.62 6486.42 -8574.17 13862.40 5960163.90 .576153.79 .MWD+IFR-AK-CAZ-SC 18822.33 89.71 82.59 6588.33 6487.13 -8568.70 13916.14 5960169.83 576207.48 MWD+IFR-AK-CAZ-SC 18861.24 89.40 81.94 6588.64 6487.44 -8563.46 13954.70 5960175.38 576245.98 MWD+IFR-AK-CAZ-SC 18953.25 89.21 85.94 6589.75 6488.55 -8553.75 14046.17 5960185.85 576337.36 MWD+IFR-AK-CAZ-SC 19001.38 90.01 88.13 6590.08 6488.88 -8551.26 14094.23 5960188.74 576385.40 MWD+IFR-AK-CAZ-SC 19047.96 92.24 92.11 6589.17 6487.97 -8551.36 14140.79 5960189.03 576431.95 MWD+IFR-AK-CAZ-SC 19095.76 89.64 91.57 6588.38 6487.18 -8552.89 14188.55 5960187.89 576479.72 MWD+IFR-AK-CAZ-SC 19132.24 .88.47 92.52 6588.98 6487.78 -8554.19 14225.00 5960186.89 576516.18 MWD+IFR-AK-CAZ-SC 19191.29 91.06 92.60 6589.23 6488.03 -8556.83 14283.99 5960184.74 .576575.18 MWD+IFR-AK-CAZ-SC 19235,63 91.25 93.40 6588.33 6487.13 -8559.15 14328.26 5960182.79 576619.46. MWD+IFR-AK-CAZ-SC 19279.03 90.26 90.41 6587.76 6486.56 -8560.59 14371.63 5960181.71 576662.83 MWD+IFR-AK-CAZ-SC 19320.79 91.06 86.92 6587.28 6486.08 -8559.62 14413.36 5960183.03 576704.56 MWD+IFR-AK-CAZ-SC 19375.60 90.38 88.25 6586.59 6485.39. -8557.31 14468.12 5960185.79 576759.29 MWD+IFR-AK-CAZ-SC 19414.94 88.96 88.74 6586.82 6485.62 -855628 14507.44 5960187.15 576798.60 MWD+IFR-AK-CAZ-SC 19513.81 90.45 94.13 6587.33 6486.13 -8558.75 14606.24 5960185.49 576897.41 MWD+IFR-AK-CAZ-SC 19601.96 91.68 93.55 6585.69 6484.49 -8564.66 14694.18 5960180.32 576985.38 MWD+IFR-AK-CAZ-SC 19702.88 90.51 93.16 6583.76 6482.56 -8570.56 14794.90 5960175.25 577086.14 MWD+IFR-AK-CAZ-SC 19790.13 88.60 93.12 6584.44 6483.24 -8575.34 14882.02 5960171.19 57717328 MWD+IFR-AK-CAZ-SC 19884.99 86.12 91.62 6588.81 6487.61 -8579.26 14976.68 5960168.06 577267.97 MWD+IFR-AK-CAZ-SC 19976.32 86.87 93.66 6594.39 6493.19 -8583.46 15067.74 5960164.62 577359.05 MWD+IFR-AK-CAZ-SC 20027.63 91.06 95.71 6595.32 6494.12 -8587.65 15118.86 5960160.85 .577410.19 MWD+IFR-AK-CAZ-SC 20071.45 89.95 94.31 6594.93 6493.73 -8591.47 15162.51 5960157.39 577453.87 MWD+IFR-AK-CAZ-SC 20105.09 89.09 89.54 6595.21 6494.01 -8592.60 15196.12 5960156.54 577487.48 MWD+IFR-AK-CAZ-SC 20136.95 88.46 85.08 6595.89 6494.69 -8591.11 15227.93 596015829 577519.28 MWD+IFR-AK-CAZ-SC 20165.35 88.47 83.78 6596.65 6495.45 -8588.35. 15256.18 5960161.28 577547.51 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report (~omp.u~}: ConocoFhillipsAlaskalnc. I>:uc: 2~16/20D6 7imc 14:324 Pnc: G Ficl~l: Kup aruk River U nit Cu-ur~ iuatc(~i Fl Re ference: Weil_ 1 C-20, True N orth tine: Kup aruk 1C Pad ~ rrtia ~l ("IFI)) Refe rence: 1C-20. 10'1.2 ~~cll: 1 C-20 ticciiun (~ ti~ Referen ce: Well (O OON.O-OQE-9 0.50Azi) ~i~ellpath: 1C-20 Surce~ (calculation ~Icihorl: Minim um Curvature Uh: Oracle Sur~cc ~~~) ~IIC~ _ ~lI111 ~ ~' ~) ti~1 ~ ` ~) ~i1 I'.il~ ~~:1 ~1~ ~~a l1 ~'. 111111 ft deg deq ft ft ft ft ft ft 20258.04 86.93 81.22 6600.38 6499.18 -8576.27 15347.99 5960174.13 577639.21 MWD+IFR-AK-CAZ-SC 20350.85 88.41 86.10 6604.15 6502.95 -8566.03 15440.13 5960185.13 577731.24 MWD+IFR-AK-CAZ-SC 20445.02 85.50 83.47 6609.15 6507.95 -8557.49 15533.76 5960194.44 577824.79 MWD+IFR-AK-CAZ-SC 20535.96 90.01 89.63 6612.72 6511.52 -8552.03 15624.40 5960200.65 577915.37 MWD+IFR-AK-CAZ-SC 20575.43 88.90 89.19 6613.09 6511.89 -8551.63 15663.86 5960201.39 577954.83 MWD+IFR-AK-CAZ-SC 20635.07 85.44 87.77 6616.04 6514.84 -8550.05 15723.40 5960203.46 578014.35 MWD+IFR-AK-CAZ-SC 20676.67 85.69 87.77 6619.25 6518.05 -8548.43 15764.84 5960205.42 578055.77 MWD+IFR-AK-CAZ-SC 20721.52 84.89 88.08 6622.94 6521.74 -8546.82 15809.51 5960207.40 578100.42 MWD+IFR-AK-CAZ-SC 20822.23 83.21 86.34 6633.38 6532.18 -8541.94 15909.55 5960213.11 578200.41 MWD+IFR-AK-CAZ-SC 20909.40 86.18 93.40 6641.45 6540.25 -8541.76 15996.28 5960214.01 578287.13 MWD+IFR-AK-CAZ-SC 21008.62 83.40 94.05 6650.46 6549.26 -8548.18 16094.88 5960208.41 578385.76 MWD+IFR-AK-CAZ-SC 21081.00 ~ 83.40 94.05 6658.77 ~ 6557.57 -8553.25 16166.60 5960203.93 578457.51 PROJECTED to TD . Halliburton Company Global Report (~nmpan~~: ConocoPhillipsAlaska Inc. tlatc: 2/16/2006 Iiwc: 14 1559 Pa~,r. 1 r~icl~l: Kuparuk River Unit Cu-~~rdin:~tc(\I~:) Kefc rence: Well: 1C-20, True N orth tiitc: Kuparuk 1C Pad ~crticril (I'~I)~ Itcfcr cucc: 1C-20PBL 101.2 ~1'cll: 1 C-20 ~ectiun ~~~ti~ licfercur c Well (O OON,QOOE 0-OOAzii ~~cllpath: 1C-20P61 Surcc~(alculatiun>lcthod: Minimum Curvature Ub: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1C Pad Site Position: Northing: 5968522. 46 ft Latitude: 70 19 28.285 N From: Map Easting: 562372. 05 ft Longitude: 149 29 39.293 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 1 C-20 Slot Name: Well Position: +N/-S 100.82 ft Northing: 5968622. 03 ft Latitude: 70 19 29.277 N +E/-W -149.13 ft Easting : .562222. 10 ft Longitude: 149 29 43.646 W Posifion Uncertainty: 0.00 ft Wellpath: 1 C-20PB1 500292327370 Drilled From: Tie-on Depth: Well Ref. Point 40.60 ft Current Datum: 1 C-20PB1: Height 101. 20 ft Above System Da tum: Mean Sea Level Magnetic Data: 11/19/2005 Field Strength: 57569 nT Declination: Mag Dip Angle: 24.31 deg 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.60 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 11/22/2005 Validated: No Version: 7 Actual From To Survey Toolcode Tool Name ft ft 181.00 1058.00 1 C-20P61 gyro (181.00-1058.00) CB-GYRO-SS Camera based gyro single shot 1142.32 18505.24 1 C-20PB1 (1 142.32-1850 5.24) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ - 9 _..... _... _...... _ ~~~) ~Ill'~ _~%Illl ~~~) ti ~11~1) ~i~ l'.~~ X1.1 [1` X1:1 ~~', ~[IU~ ft deg deg ft ft ft ft ft ft 40.60 0.00 0.00 .40.60 -60.60 0.00 0.00 5968622.03 562222.10 TIE LINE 181.00 0.25 185.64 181.00 79.80 -0.30 -0.03 5968621.72 562222.07 CB-GYRO-SS 272.00 1.04 172.05 271.99 170.79 -1.32 0.06 5968620.71 562222.18 CB-GYRO-SS 362.00 3.18 144.11 361.93 260.73 -4.15 1.64 5968617.89 562223.78. CB-GYRO-SS 458.00 6.40 147.04 457.58 356.38 -10.80 6.11 5968611.28 562228.30 CB-GYRO-SS 558.00 10.08 158.17 556.54 455.34 -23.61 12.40 5968598.53 .562234.70. CB-GYRO-SS 658.00 13.79 164.64 654.36 553.16 -43.23 18.82 5968578.96 562241.27 CB-GYRO-SS 758.00 18.71 178.86 750.38 649.18 -70.79 22.30 5968551.44 562244.98 CB-GYRO-SS 858.00 22.72 178.32 843.89 742.69 -106.14 23.18 5968516.10 562246.16 CB-GYRO-SS 958.00 25.08 167.57 935.36 834.16 -146.16 28.31 5968476.12 562251.62 CB-GYRO-SS 1058.00 27.58 163.24 1024.98 923.78 -189.04 39.55 5968433.34 562263.22 CB-GYRO-SS 1058.60 27.58 163.24 1025.51 924.31 -189.30 39.63 5968433.08 .562263.30 CB-GYRO-SS 1142.32 32.38 160.60 1098.01 996.81 -229.03 52.68 5968393.47 562276.67 MWD+IFR-AK-CAZ-SC 1235.91 36.88 158.24 1175.01 1073.81 -278.78 71.42 5968343.88 562295.82 MWD+IFR-AK-CAZ-SC 1332.65 38.37 157.36 1251.63 1150.43 -333.45 93.74 5968289.40 562318.60 MWD+IFR-AK-CAZ-SC 1428.01 38.99 157.70 . 1326.07 1224.87 -388.53 116.52 5968234.52 562341.83 MWD+IFR-AK-CAZ-SC 1523.25 41.34 155.44 1398.85 1297.65 -444.87 140.97 5968178.39 562366.74 MWD+IFR-AK-CAZ-SC 1619.65 45.04 156.98 1469.12 1367.92 -505.24 167.55 5968118:25 562393.82 MWD+IFR-AK-CAZ-SC ,~ Halliburton Company. Global Report Couipan~: Conoco Phillips Alaska Inc. t)atc '?116;'2006 Tinic 14:15'59 Pa~,c: '_ I~iel~l: Kuparuk River Unit ('o-urdinaitclAI_) Rcfcrrucc: Well: 1C-20, Trua North ~Sitc: Kuparuk 1C Pad Vcrti~;~l (Il~il1 Kclircncc: 1C-20PB1: 101.2 ~1'cll: 1 C-20 ticctiun (BSI Kcfercncc: Well (O.OON.O-OOE.O OOAzi) ~i'ell~rith: 1G20P61 tiun~c~ ('alculatiou ~lcthn~l: Minimum Curvature Dh: Oracle ~ur~cc III) Intl ~zim l ~I) tips l ~ U V!.5 F:-1V ~la~iA llapl~. Maul ft deg deg ft ~ ft ft ft ft ft 1712.77 46.39 155.86 1534.14 1432.94 -566.33 .194.22 5968057.39 562420.99 MWD+IFR-AK-CAZ-SC 1809.03 -51.81 153.05 1597.15 1495.95 -631.90 225.64 5967992.08 562452.95 MWD+IFR-AK-CAZ-SC 1903.07 55.93 151.68 1652.59 1551.39 -699.17 260.89 5967925.12 562488.75 MWD+IFR-AK-CAZ-SC 1998.09 58.51 152.07 1704.03 1602.83 -769.62 298.54 5967854.99 562526.98 MWD+IFR-AK-CAZ-SC 2093.09 60.17 152.22 1752.47 1651.27 -841.87 336.72 5967783.07 562565.76 MWD+IFR-AK-CAZ-SC 2190.73 61.77 151.92 1799.85 1698.65 -917.29 376.71 5967707.98 562606.36 MWD+IFR-AK-CAZ-SC 2285.39 65.34 152.55 1842.00 1740.80- -992.28 416.18 5967633.33 562646.45 MWD+IFR-AK-CAZ-SC 2379.10 69.29 152.27 1878.13 1776.93 -1068.89 456.22 5967557.06 562687.12 MWD+IFR-AK-CAZ-SC 2474.47 72.34 153.21 1909.47 1808.27 -1148.95 497.46 5967477.35 562729.02 MWD+IFR-AK-CAZ-SC 2569.35 74.40 151.77 1936.63 1835.43 -1229.58 539.45 5967397.09 562771.68 MWD+IFR-AK-CAZ-SC 2664.61 75.95 147.49 1961.01 1859.81 -1309.00 586.01 5967318.06 562818.89 MWD+IFR-AK-CAZ-SC 2758.56 73.44 145.29 1985.81 1884.61 -1384.46 636.15 5967243.02 562869.65 MWD+IFR-AK-CAZ-SC 2854.35 72.31 143.19 2014.02 1912.82 -1458.74 689.64 5967169.19 562923.75 MWD+IFR-AK-CAZ-SC 2949.70 72.98 141.61 2042.46 1941.26 -1530.84 745.17 5967097.56 562979.87 MWD+IFR-AK-CAZ-SC 3046.00 74.25 140.87 2069.63 1968.43 -1602.88 803.01 5967026.01 563038.30 MWD+IFR-AK-CAZ-SC 3139.04 74.63 137.99 2094.59 1993.39 -1670.96 861.30 5966958.43 563097.14. MWD+IFR-AK-CAZ-SC 3234.22 73.91 138.22 2120.39 2019.19 -1739.15 922.48 5966890.75 563158.88 MWD+IFR-AK-CAZ-SC 3332.27 73.47 138.36 2147.93 .2046.73 -1809.40 985.09 5966821.03 563222.06 MWD+IFR-AK-CAZ-SC 3422.26 75.15 136.50 2172.261 2071.06 -1873.20 1043.70 5966757.73 563281.19 MWD+IFR-AK-CAZ-SC 3529.73 75.69 132.40 2199.33 2098.13 -1946.01 1117.93 5966685.54 563356.02 MWD+IFR-AK-CAZ-SC 3626.97 75.59 131.18 2223.45 2122.25 -2008.79 1188.17 5966623.35 563426.77 MWD+IFR-AK-CAZ-SC 3719.92 75.74 131.44 2246.46 2145.26 -2068.24 1255.81 5966564.47 563494.90 MWD+IFR-AK-CAZ-SC 3818.35 73.77 130.58 2272.34 2171.14 -2130.55 1327.47 5966502.76 563567.06 MWD+IFR-AK-CAZ-SC 3911.23 71.18 130.84 2300.31 2199.11 -2188.31 1394.60 5966445.56 563634.66 MWD+IFR-AK-CAZ-SC 4008.21 69.97 132.34 2332.56 2231.36 -2249.02 1463.00 5966385.43 563703.56 MWD+IFR-AK-CAZ-SC 4102.28 70.48 133.69 2364.39 2263.19 -2309.41 1527.72 5966325.59 563768.77 MWD+IFR-AK-CAZ-SC 4197.12 70.54 133.57 2396.03 2294.83 -2371.10 1592.44 5966264.45 563833.99 MWD+IFR-AK-CAZ-SC 4293.92 72.25 134.12 2426.91 2325.71 -2434.64 1658.60 5966201.45 563900.67 MWD+IFR-AK-CAZ-SC 4387.86 69.96 133.91 2457.33 2356.13 -2496.40 1722.51 5966140.24 563965.08 MWD+IFR-AK-CAZ-SC 4483.91 68.19 133.73 2491.64 2390.44 -2558.51 1787.24 5966078.67 564030.32 MWD+IFR-AK-CAZ-SC 4579.95 69.38 133.27 2526.39 2425.19 -2620.14 1852.18 5966017.59 564095.76 MWD+IFR-AK-CAZ-SC 4675.15 70.97 132.10 2558.68 2457.48 -2680.85 1918.01 5965957.43 564162.09 MWD+iFR-AK-CAZ-SC 4768.84 71.82 131.28 2588:57 2487.37 -2739.91 1984.32 5965898.93 564228.88 MWD+IFR-AK-CAZ-SC 4863.92 69.80 131.30 2619.82 2518.62 -2799.16 2051.79 5965840.25 564296.83 MWD+IFR-AK-CAZ-SC 4960.90 73.04 128.27 2650.72 2549.52 -2857.95 2122.42 5965782.05 564367.94 MWD+IFR-AK-CAZ-SC 5052.78 73.29 128.67 2677.33 2576.13 -2912.66 2191.28 5965727.92 564437.24 MWD+IFR-AK-CAZ-SC 5147.77 71.70 127.65 2705,90 2604.70 -2968.63 2262.50 5965672.55 564508.92 MWD+IFR-AK-CAZ-SC. 5238.03 75.52 125.66 2731.37 2630.17 -3020.30 2331.96 5965621.46 564578.80 MWD+IFR-AK-CAZ-SC 5339.98 74.44 125.70 2757.79 2656.59 -3077.73 2411.94 5965564.70 564659.25 MWD+IFR-AK-CAZ-SC 5431.85 72.69 125.69 2783.78 2682.58 -3129.14 2483.50 .5965513.89 564731.23 MWD+IFR-AK-CAZ-SC 5526.87 71.32 126.19 2813.14 2711.94 -3182.18 2556.67 5965461.46 564804.82 MWD+IFR-AK-CAZ-SC 5623.37 72.47 126.11 2843.12 2741.92 -3236.29 2630.73 5965407.97 564879.32 MWD+IFR-AK-CAZ-SC 5720.73 70.88 125.30 2873.73 2772.53 -3290.23 2705.78 5965354.66 564954.81 MWD+IFR-AK-CAZ-SC 5815.60 72.37 122.96 2903.64 2802.44 -3340.73 2780.30 5965304.79 565029.74 MWD+IFR-AK-CAZ-SC 5910.32 72.25 122.72 2932.43 2831.23 -3389.67 2856.12. 5965256.48 565105.95 MWD+IFR-AK-CAZ-SC 6004.89 71.64 119.86 2961.74 2860.54 -3436.36 2932.94 5965210.43 565183.15 MWD+IFR-AK-CAZ-SC 6098.99 69.75 119.98 2992.85 2891.65 -3480.66 3009.91 5965166.78 565260.48 MWD+IFR-AK-CAZ-SC 6191.59 68.52 121.21 3025.83 2924.63 -3524.69 3084.39 5965123.37 565335.32 MWD+IFR-AK-CAZ-SC 6286.94 69.41 122.37 3060.06 2958.86 -3571.58 3160.04 5965077.12 565411:34 MWD+IFR-AK-CAZ-SC 6389.25 71.40 122.94 3094.37 2993.17 -3623.58 3241.18 5965025.79 565492.90 MWD+IFR-AK-CAZ-SC 6484.10 71.58 124.13. 3124.48 3023.28 -3673.27 3316.15 5964976.73 565568.27 MWD+IFR-AK-CAZ-SC 6578.97 69.48 122.69 3156.10 3054.90 -3722.52 3390.80 .5964928.10 565643.33 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report Cumpam: ConocoPhillipsAlaska Inc. I);~tc: 2/16!2006 limn: id:15:59 P:~,~~: 3 Ficl~l: Kuparuk River Unit C~~-„r~linatclAF~~ Iicfcrcncc: Well: 1C-20, True North tiitc Kuparuk 1C Pad Vertical ("I ~~U~ Reference: 1G20PB1 ~ 101.2 Nell: 1 C-20 ticcliuu (~,~1 ltcfcrcncr. Well (0.OON O OOEO-OOAzij ~~~cllpath: 1 C-20PB1 tiurcc}~ (~alcu~stiun ~IMhu~l: Minimum Curvature I)b: Oracle Surccv X11) Incl ~ziui [ ~U S~, Ill) ~%~ti I.,l~ ~la~~A 11a~~F; i~nnl ft deg dey ft ~ ft ft ft ft ft 6675.50 72.87 120.03 3187.25 3086.05 -3770.04 3468.81 5964881.24 565721:72 MWD+IFR-AK-CAZ-SC 6770.76 73.66 119.96 3214.68 3113.48 -3815.65 3547.82 5964836.29 565801.09 MWD+IFR-AK-CAZ-SC 6865.88 74.08 121.00 3241.11 3139.91 -3862.00 3626.57 5964790.60 565880.22 MWD+IFR-AK-CAZ-SC 6960.71 74.07 116.12. 3267.14 3165.94 -3905.58 3706.63 5964747.69 565960.63 MWD+IFR-AK-CAZ-SC 7057.09 73.93 114.01 3293.71 3192.51 -3944.82 3790.55 5964709.15 566044.86 MWD+IFR-AK-CAZ-SC 7148.43 73.81 114.07 3319.08 3217.88 -3980.57 3870.68 5964674.07 566125.28 MWD+IFR-AK-CAZ-SC 7243.79 72.76 113.70 3346.51 3245.31 -4017.55 3954.19 5964637.79 566209.09 MWD+IFR-AK-CAZ-SC 7339.43 72.00 114.22 3375.46 3274.26 -4054.57 4037.49 5964601.47 566292.68 MWD+IFR-AK-CAZ-SC 7434.75 71.55 114.06 3405.27 3304.07 -4091.59 4120.11 5964565.13 566375.60 MWD+IFR-AK-CAZ-SC 7529.41 71.35 113.46 3435.39 3334.19 -4127.75 4202.24 5964529.66 566458.02 MWD+IFR-AK-CAZ-SC 7624.54 69.85 114.28 3466.98 3365.78 -4164.06 4284.29 5964494.04 566540.36 MWD+IFR-AK-CAZ-SC 7719.12 67.75 116.03 3501.19 3399.99 -4201.53 4364.11 5964457.23 566620.47 MWD+IFR-AK-CAZ-SC 7814.27 66.42 115.94 3538.23 3437.03 -4239.92 4442.89 5964419.49 566699.56 MWD+IFR-AK-CAZ-SC 7910.83 66.16 117.05 3577.06 3475.86 -4279.36 4522.01 5964380.71 566779.00 MWD+IFR-AK-CAZ-SC 8006.40 65.73 118.54 3616.02 3514.82 -4320.06 4599.21 5964340.67 566856.53 MWD+IFR-AK-CAZ-SC 8100.92 69.73 122.91 3651.85 3550.65 -4364.76 4674.34 5964296.59 566932.02. MWD+IFR-AK-CAZ-SC 8196.36 68.96 124.04 3685.51 3584.31 -4414.02 4748.83 5964247.96. 567006.91. MWD+IFR-AK-CAZ-SC 8292.64 73.90 122.89 3716.17 3614.97 -4464.32 4824.95 5964198.30 567083.43 MWD+IFR-AK-CAZ-SC 8386.46 76.72 122.22 3739.96 3638.76 -4513.14 4901.43 5964150.11 567160.32 MWD+IFR-AK-CAZ-SG 8478.18 75.89 120:16 3761.67 3660.47 -4559.29 4977.66 5964104.60 567236.91 MWD+IFR-AK-CAZ-SC 8576.86 75.77 117.97 3785.83 3684.63 -4605.77 5061.28 .5964058.82 567320.91 .MWD+IFR-AK-CAZ-SC 8672.06 75.94 117.60 3809.10 3707.90 -4648.80 5142:95 5964016.47 567402.93 MWD+IFR-AK-CAZ-SC 8766.27 74.62 116.31 3833.04 3731.84 -4690.11 5224.17 5963975.85 567484.47 MWD+IFR-AK-CAZ-SC 8861.85 73.91 116.89 3858.96 3757.76 -4731.30 5306.43 5963935.34 567567.06 MWD+IFR-AK-CAZ-SC 8957.42 73.69 118.54 3885.62 3784.42 -4773.98 5387.67 5963893.34 567648.65 MWD+IFR-AK-CAZ-SC 9052.78 74.07 117.07 3912.10 3810.90 -4816.71 5468.70 5963851.29 567730.02 MWD+IFR-AK-CAZ-SC 9148.85 71.77 114.00 3940.32 3839.12 -4856.30 5551.54 5963812.39 567813.18 MWD+IFR-AK-CAZ-SC 9244.49 71.09 115.93 3970.78 3869.58 -4894.56 5633.72 5963774.82 567895.67 MWD+IFR-AK-CAZ-SC 9338.95 70.99 117.03 4001.47 3900.27 -4934.39 5713.69 5963735.65 567975.96 MWD+IFR-AK-CAZ-SC 9433.97 71.15 116.46 4032.30 3931.10 -4974.84 5793.95 5963695.87 568056.55 MWD+IFR-AK-CAZ-SC 9528.87 71.06 116.54 4063.03 3961.83 -5014.90 5874.30 5963656.48 568137.22 MWD+IFR-AK-CAZ-SC 9624.49 71.12 116:19 4094.02 3992.82 -5055.07 5955.35 5963616.99 568218.59 MWD+IFR-AK-CAZ-SC 9719.73 71.16 115.82 4124.81 4023.61 -5094.59 6036.36 5963578.15 568299.91 MWD+IFR-AK-CAZ-SC 9813.38 69.82 117.46 4156.08 4054.88 -5134.16 6115.25 5963539.24 568379.13 MWD+IFR-AK-CAZ-SC 9909.33 69.31 117.62 4189.58 4088.38 -5175.73 6194.98 5963498.33 568459.19 MWD+IFR-AK-CAZ-SC 10004.85 70.10 119.92 4222.72 4121.52 -5218.85 6273.50 5963455.87 568538.05 MWD+IFR-AK-CAZ-SC 10099.96 70.56 120.16 4254.73 4153.53 -5263.69 6351.03 5963411.68 568615.95 MWD+IFR-AK-CAZ-SC 10194.89 72.56 119.83 4284.76 4183.56 -5308.71 6429.02 5963367.32 568694.30 MWD+IFR-AK-CAZ-SC 10290.98 72.89 120.29 4313.29 4212.09 -5354.67 6508.43 5963322.02 568774.08. MWD+IFR-AK-CAZ-SC 10386.15 72.17 119.10 4341.87 4240.67 -5399.64 6587.29 5963277.71 568853.30 MWD+IFR-AK-CAZ-SC 10481.12 71.59 118.53 4371.40 4270.20 -5443.14 6666.37 5963234.87 568932.74 MWD+IFR-AK-CAZ-SC 10576.69 71.41 117.97 4401.73 4300.53 -5486.04 6746.21 5963192.64 569012.92 MWD+IFR-AK-CAZ-SC 10672.42 71.69 117.55 4432.02 4330.82 -5528.34 6826.57 5963151.01 569093.62 MWD+IFR-AK-CAZ-SC 10767.77 71.70 117.21 4461.97 4360.77 -5569.97 6906.95 5963110.05 569174.33 MWD+IFR-AK-CAZ-SC 10863.81 71.67 117.20 4492.15 4390.95 -5611.65 6988.04 5963069.05 569255.76 MWD+IFR-AK-CAZ-SC 10957.88 71.70 116.87 4521.71 4420.51 -5652.24 7067.59 5963029.12 569335.63 MWD+IFR-AK-CAZ-SC 11048.00 72.18 117.38 4549.65 4448.45 -5691.31 7143.84 5962990.69 569412.20 MWD+IFR-AK-CAZ-SC 11063.09 71.94 117.22 .4554.30 4453.10 -5697.89 7156.60 5962984.22 569425.01 MWD+IFR-AK-CAZ-SC 11110.49 71.07 117.63 4569.33 .4468.13 -5718.59 7196.50 5962963.85 569465.08 MWD+IFR-AK-CAZ-SC 11205.17 71.72 117.74 4599.54. 4498.34 -5760.29 7275.96 5962922.82 569544.87 MWD+IFR-AK-CAZ-SC 11298.22 71.79 119.73 4628.68 4527.48 -5802.77 7353.44 5962880.98 569622.70 MWD+IFR-AK-CAZ-SC 11395.61 72.08 119.33 4658.88 4557.68 -5848.40 7434.00 5962836.02 569703.63 MWD+IFR-AK-CAZ-SC 11490.56 71.99 119.88 4688.16 4586.96 -5893.02 7512.53 5962792.06 569782.52 MWD+IFR-AK-CAZ-SC • Halliburton Company Global Report ('ompain: ConocoPhillipsAl~ska Inc. I)aic: 2;16!2006 Time: 14.15:59 Peer. ~ I~idJ: Kuparuk River U nit (~u-un linetclA1.) Rc fi~rencr. lNell: 1C-20. True North tiitr. Kuparuk 1C Pad ~crti r~l Il'~~I)I Kcte rcucc: 1C -20PB1: 101.2 ~~cll: 1 C-20 ticcliu n (~~) Rcfcrc ncc Well (O.OON,O OOE .O OOAziI 11~cllpeth: 1 C-20PB1 ~~n~~c } (alailatiun ~1cUu~d: Mi nimum Curvatur e Ilh: Oracle Sung ~IU Incl ltim 1~I1 tiffs IVU V'iti I~:'~1~ 11a~~S ~iapl~; I'nol ft deg deg ft ft ft ft ft ft 11585.02 71.86 120.25 4717.47 4616.27 -5938.01 7590.25 5962747.72 569860.59 MWD+IFR-AK-CAZ-SC 11681.83 70.80 117.38 4748.47 4647.27 -5982.22 7670.59 5962704.19 569941.30 MWD+IFR-AK-CAZ-SC 11777.73 70.70 116.82 4780.08 4678.88 -6023.46 7751.19 5962663.62 570022.22 MWD+IFR-AK-CAZ-SC 11872.35 70.29 116.10 4811.68 4710.48 -6063.20 7831.04 5962624.55 570102.39 MWD+IFR-AK-CAZ-SC 11966.36 70.76 115.78 4843.02 4741.82 -6101.97 7910.74 5962586.44 570182.40 MWD+IFR-AK-CAZ-SC 12061.02 70.61 115.31 4874.33 4773.13 -6140.49 7991.34 5962548.59 570263.31 MWD+IFR-AK-CAZ-SC 12154.77 72.13 115.88 4904.28 4803.08 -6178.87 8071.45 5962510.88 570343.73 MWD+IFR-AK-CAZ-SC 12251.44 72.01 116.50 4934.04 4832.84 -6219.46 8153.99 5962470.98 570426.59 MWD+IFR-AK-CAZ-SC 12346.01 73.43 118.80 4962.13 4860.93 -6261.37 8233.96 5962429.74 570506.91 MWD+IFR-AK-CAZ-SC 12441.41 72.93 120.49 4989.74 4888.54 -6306.54 8313.33 5962385.24 570586.63 MWD+IFR-AK-CAZ-SC 12536.94 72.95 120.02 5017.76 4916.56 -6352.55 8392.21 5962339.89 570665.89 MWD+IFR-AK-CAZ-SC 12631.61 73:47 118.15 5045.11 4943.91 -6396.60 8471.42 5962296.49 570745.45 MWD+IFR-AK-CAZ-SC 12727.00 . 73.47 116.60 5072.26 4971.06 -6438.65 8552.62 5962255.13 570826.99 MWD+IFR-AK-CAZ-SC 12818.67 72.84 117.89 5098.82 4997.62 -6478.82 8630.62 5962215.61 570905.32 MWD+IFR-AK-CAZ-SC 12918.89 72.57 118.41 5128.62 5027.42 -6523.96 8714.99 5962171.18 570990.05 MWD+IFR-AK-CAZ-SC 13014.13 72.05 118.67 5157.56 5056.36 -6567.31 8794.70 5962128.49 571070.11 MWD+IFR-AK-CAZ-SC 13109.16 71.55 117.44 5187.24 5086.04 -6609.77 8874.37 5962086.70 571150.12: MWD+IFR-AK-CAZ-SC 13204.36 71,08 117.24 5217.74 5116.54 -6651.19 8954.47 5962045.95 571230.56 MWD+IFR-AK-CAZ-SC 13299,57 70.56 116.63 5249.02 5147.82 -6691.92 9034.64 5962005.89 571311.05 MWD+IFR-AK-CAZ-SC 13395.43 71.10 117.30 5280.49 5179.29 -6732.98 9115.34 5961965.50 571392.08 MWD+IFR-AK-CAZ-SC 13489.97 70.70 116.81 5311.43 5210.23 -6773.61 9194.90 5961925.53 571471.97 MWD+IFR-AK-CAZ-SC 13585.29 72.06 119.51 5341.87 5240.67 -6816.24 9274.53 5961883.57 571551.93 MWD+IFR-AK-CAZ-SC 13681.18 72.24 119.58 5371.26 5270.06 -6861.25 9353.93 5961839.22 571631.70 MWD+IFR-AK-CAZ-SC 13776.06 71.87 119.62 5400.49 5299.29 -6905.84 9432.42 5961795.30 571710.55 MWD+IFR-AK-CAZ-SC 13868.80 71.28 119.05 5429.81 5328.61 -6948.94 9509.12 5961752.83 571787.60 MWD+IFR-AK-CAZ-SC 13963.33 71.42 117.97 5460.04 5358.84 -6991:69 9587.82 5961710.74 571866.64 MWD+IFR-AK-CAZ-SC 14060.04 71.09 118.96 5491.12 5389.92 -7035.34 9668.33 5961667.76 571947.50 MWD+IFR-AK-CAZ-SC 14154.65 70.88 117.63 5521.94 5420.74 -7077.74 9747.09 5961626.02 572026.60 MWD+IFR-AK-CAZ-SC 14249.04 71.09 117.42 5552.70 5451.50 -7118.98 9826.23 5961585.45 572106.07 MWD+IFR-AK-CAZ-SC 14344.09 72.25 117.49 5582.59 5481.39 -7160.58 9906.29 5961544.52 572186.47 MWD+IFR-AK-CAZ-SC 14439.72 72.32 116.60 5611.69 5510.49 -7202.00 9987.42 5961503.77 572267.94 MWD+IFR-AK-CAZ-SC 14535.46 71.82 118.26 5641.16 5539.96 -7243.96 10068.27 5961462.49 572349.12 MWD+IFR-AK-CAZ-SC 14630.71 71.43 118.50 5671.19 5569.99 -7286.92 10147.80 5961420.19 572429.00 MWD+IFR-AK-CAZ-SC 14725.61 70.96 118.01 5701.78 5600.58 -7329.45 10226.93 5961378.33 572508.47 MWD+IFR-AK-CAZ-SC 14820.15 71.16 117.71 5732.47 5631.27 -7371.24 10305.99 5961337.20 572587.86 MWD+IFR-AK-CAZ-SC 14915.48 71.53 120.38 5762.96 5661.76 -7415.09 10384.94 5961294.01 572667.1.7 MWD+IFR-AK-CAZ-SC 15011.31 71.54 120.23 5793.32 5692.12 -7460.95 10463.41 5961248.80 572746.01 MWD+IFR-AK-CAZ-SC 15105.96 70.11 118.53 5824.40 5723.20 -7504.81 10541.31 5961205.59 572824.26 MWD+IFR-AK-CAZ-SC 15201.73 71.08 118.99 5856.22 5755.02 -7548.27 10620.49 5961162.79 572903.79 MWD+IFR-AK-CAZ-SC 15289.35 72.44 117.63 5883.65 5782.45 -7587.73 10693.75 5961123.94 572977.37 MWD+IFR-AK-CAZ-SC - 15391.46 71.16 116.84 5915.54 5814.34 -7632.13 10780.00 5961080.27 573063.97 MWD+IFR-AK-CAZ-SC 15486.32 72.25 118.29 5945.32 5844.12 -7673.81 10859.83 5961039.26 573144.15 MWD+IFR-AK-CAZ-SC 15581.94 73.99 118.26 5973.08 5871.88 -7717.15 10940.41 5960996.59. 573225.07 MWD+IFR-AK-CAZ-SC 15678.02 73.81 117.46 5999.73 5898.53 -7760.29 11022.02 5960954.14 573307.03 MWD+IFR-AK-CAZ-SC 15772.75 73.53 116.94 6026.36 5925.16 -7801.84 11102.88 5960913.26 573388,22 MWD+IFR-AK-CAZ-SC 15867.93 73.49 116.83 6053.38 5952.18 -7843.11 11184.28 5960872.67 573469.95 MWD+IFR-AK-CAZ-SC 15963.13 73.61 116.43 6080.34 5979.14. -7884.04 11265.90 5960832.43 573551.90 MWD+IFR-AK-CAZ-SC 16058.13 74.12 115.73 6106.74 6005.54 -7924.15 11347.86 5960792.99 573634.19 MWD+IFR-AK-CAZ-SC 16151.94 72.19 116.84 6133.92 6032.72 -7963.91 11428.36 5960753.91 573715.01 MWD+IFR-AK-CAZ-SC 16248.58 69.76 118.45 6165.43 6064.23 -8006.28 11509.29 5960712.21 573796.27 MWD+{FR-AK-CAZ-SC 16342.65 70.45 118.49 6197.44 6096.24 -8048.45 11587.05 5960670.69 573874.37 MWD+IFR-AK-CAZ-SC 16439.47 70.91 117.18 6229.47 6128.27 -8091.11 11667.84 5960628.71 573955.51 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('nmp:u~): CrnocoPhiflips Alaska Inc. Ilatc: 2i16/20Gn Time: 14:15:59 Pa~c: Ficl~: Ku paruk River U nit (~u-ur diuatclAE) Itc fcrencc: Well: 1C-20. True North dire: Ku paruk 1C Pad ~'crtia il I"f~~U1 Itcfc rcncc: 1G~OPB1. 1012 1~c11: 1C -20 Jcctiu n (~~1 Rcfcrcu cr. JVell (O.OON,QDOC -O OOAzI) ~1'cllpath: 1 G 20PB1 tiurcev ('»Iculatiun ]Icthu~l: Mi nimum Curvatur e I)h: Oracle Surcrc ail) lucl ~zim Il U S~, l~'D \?S E,1i 11.~1~A ~lapF: fnnl ft deg deg ft ft ft ft ft ft 16533.77 71.10 116.78 6260.16 6158.96 -8131.56 11747.30 5960588.92 574035.29 MWD+IFR-AK-CAZ-SC 16629.12 71.19 116.75 6290.98 6189.78 -8172.20 11827.87 5960548.96 574116.19 MWD+IFR-AK-CAZ-SC 16724.26 71.20 115.78 6321.65 6220.45 -8212.05 11908.63 5960509.78 574197.27 MWD+IFR-AK-CAZ-SC 16819.78 72.59 113.63 6351.33 6250.13 -8249.99 11991.10 5960472.53 574280.05 MWD+IFR-AK-CAZ-SC 16915.09 73.54 111.92 6379.10 6277.90 -8285.28 12075.17 5960437.95 574364.39 MWD+IFR-AK-CAZ-SC 17010.46 74.12 111.19 6405.66 6304.46 -8318.93 12160.36 5960405.00 574449.85 MWD+IFR-AK-CAZ-SC 17105.48 74.69 110.05 6431.20 6330.00 -8351.16 12246.02 5960373.49 574535.77 MWD+IFR-AK-CAZ-SC 17200.49 74.07 109.81 6456.79 6355.59 -8382.35 12332.04 5960343.02 574622.03 MWD+IFR-AK-CAZ-SC 17290.91 73.50 109.52 6482.03 6380.83 -8411.57 12413.80 5960314.48 574704.02 MWD+IFR-AK-CAZ-SC 17391.48 75.71 103.82 6508.75 6407.55 -8439.34 12506.64 5960287.48 574797.09 MWD+IFR-AK-CAZ-SC 17485.63 74.95 100.69 6532.60 6431.40 -8458.68 12595.63 5960268.89 574886.23 MWD+IFR-AK-CAZ-SC 17580.44 74.88 99.19 6557.28 6456.08 -8474.48 .12685.80 5960253.83 574976.51 MWD+IFR-AK-CAZ-SC 17658.08 77.75 97.65 6575.64 6474.44 -8485.52 12760.41 5960243.41 575051.21 MWD+IFR-AK-CAZ-SC 17757.51 82.13 94.99 6593.01 6491..81 -8496.27 12857.69 5960233.46 575148.56 MWD+IFR-AK-CAZ-SC 17805.97 86.25 94.81 6597.92 6496.72 -8500.39 12905.71 5960229.75 575196.61 MWD+IFR-AK-CAZ-SC 17848.22 88.29 94.74 6599.93 6498.73 -8503.90 12947.76 5960226.58 575238.69 MWD+IFR-AK-CAZ-SC 17897.69 91.26 94.23 6600.12 6498.92 -8507.77 12997.08 5960223.12 575288.03 .MWD+IFR-AK CAZ-SG 17930.55 93.51 94.34 6598.75 6497.55 -8510.22 13029.81 5960220.94 575320.78 MWD+IFR-AK-CAZ-SC 17991.53 94.56 93.14 6594.46 6493.26 -8514.19 13090.51 5960217.48 575381.50 MWD+IFR-AK-CAZ-SC 18034.95 95.06 92.06 6590.82 6489.62 -8516.16 13133.73 5960215.87 575424.73 MWD+IFR-AK-CAZ-SC 18083.80 94.62 90.03 6586.70 6485.50 -8517.04 13182.40 5960215.39 575473.40 MWD+IFR-AK-CAZ-SC 18119.61 94.13 87.46 6583.97 6482.77 -8516.26 13218.09 5960216.47 575509.08 MWD+IFR-AK-CAZ-SC 18150.74 92.95 84.92 6582.05 6480.85 -8514.20 13249.09 5960218.79 575540.06 MWD+IFR-AK-CAZ-SC 18174.91 89.49 80.17 6581.53 6480.33 -8511.06 13273.04 5960222.12 575563.98 MWD+IFR-AK-CAZ-SC 18202.26 88.93 79.14 6581.91 6480.71 -8506.15 13299.94 5960227.26 575590.84 MWD+IFR-AK-CAZ-SC 18240.07 89.62 76.25 6582.39 6481.19 -8498.09 13336.88 5960235.62 575627.70 MWD+IFR-AK-CAZ-SC 18267.51 88.75 74.22 6582.78 6481.58 -8491.10 13363.41 5960242.83 575654.17 MWD+IFR-AK-CAZ-SC 18300.46 89.43 76.67 6583.30 6482.10 -8482.82 13395.29 5960251.37 575685.98 MWD+IFR-AK-CAZ-SC 18332.13 89.43 77.93 6583.62 6482.42 -8475.86 13426.19 5960258.59 .575716.81 MWD+IFR-AK-CAZ-SC 18362.83 88.50 74.94 6584.17 6482.97 -8468.66 13456.02 5960266.03 575746.59 MWD+IFR-AK-CAZ-SC 18395.62 89.37 76.74 6584.78 6483.58 -8460.64 13487.81 5960274.32 575778.30 MWD+IFR-AK-CAZ-SC 18426.49 88.56 78.15 6585.34 6484.14 -8453.93 13517.93 5960281.27 575808.37 MWD+IFR-AK-CAZ-SC 18455.50 88.19 81.43 6586.16 6484.96 -8448.79 13546.47 5960286.65 575836.86 MWD+IFR-AK-CAZ-SC 18505.24 90.15 84.44 6586.88 6485.68 -8442.68 13595.82 5960293.17 575886.15 MWD+IFR-AK-CAZ-SC 18683.00 90.15 84.44 6586.42 6485.22 -8425.46 13772.74 5960311.86 576062.91 PROJECTED to TD 01 /20/06 Schlumher~er NO. 3663 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # JAN 2 4 2006 ~II~GasC~mmi~slc~ AJtf.'~tOt'8~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL Kuparuk Color CD 1E-03 11144062 PROD PROFILE W/DEFT 01/14/06 1 1F-14 11144063 PRODUCTION PROFILE 01/15/06 1 2B-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 11166751 SBHP SURVEY 01/12/06 1 1 E-06 11154118 PROD PROFILE W/DEFT 01/11/06 1 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILE/WFL 01/13/06 1 36-05 11154115 INJECTION PROFILE 01/09/06 1 2X-18 11154114 SBHP SURVEY 01/08/06 1 2X-18 11154117 PROD PROFILE W/DEFT 01/10/06 1 2H-09 11154103 PROD PROFILE W/DEFT 12/29/05 1 1G-11 11154113 PROD PROFILE W/DEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 2Z-13 11141242 PROD PROFILE W/DEFT 01/01/06 1 1 C-20 11133212 SCMT 12/25!05 1 2C-11 11144065 PROD PROFILE W/DEFT 01/17/06 1 2N-339 N/A BHP SURVEY 12/01/05 1 2D-04 N/A BHP SURVEY 12/03/05 1 2U-13 11166753 PROD PROFILE W/DEFT 01/14/06 1 1E-05 11166747 PROD PROFILE W/DEFT 12!25/05 1 2M-01 11154119 PROD PROFILE W/DEFT 01/19/06 1 SIGNED: DATE: • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Re: 1 C-20 Update • ~ Subject: Re: 1C-20 Update From: Thomas Matmder <tom_maunder@admin,state.ak.us> Date: Fri, 06 Jan 2006 l fl:33: l ~ -0900 t~~ 5 ' ~ ~-~ To: "Billir~~Jsle~~, ['i~~i ~" ~_~1,iiT~.A.Bi11in~~slev~r~.ronocop}~illips.cum- Hi Tim, I think McKeever called me about this. I agree with your assessment that the orphan branch is "plugged" with the formaset. The blank liner and swell packer should complete the isolation. There is no need to submit a permit application for the orphan branch. Catch you later, Tom Maunder, PE AOGCC Billingsley, Tim A wrote, On 1/6/2006 10:16 AM: Tom, At 1C-20, we are currently trying to drill the production hole. The sequence of events in the production hole thus far is as follows: Drilled out 7-5/8" shoe at 17713' with a good FIT to 12.5 ppg EMW. Drilled to 18175' at which point had an unplanned 24 deg/100' dog leg probably due to bouncing off of a hard siderite nodule. Continued drilling to 18589' at which point losses to the formation went from 0 bbl/hr to 120+ bbl/hr. Pumped LCM pills with minimal success, drilled ahead to 18693' to make sure loss zone/fracture/fault was all the way drilled through. MWD/LWD tools failed probably due to rotating/tripping through high dog leg area. POOH to lay down damaged MWD tools. Decided to sidetrack at 17950' to go around high dogleg area at 18,175'. RIH with motor. Pumped a 100 bbl Formaset polymer plug which did some good. Losses were reduced to a manageable 30 bph at a drilling rate ECD's. (Static losses were <10 bph). Low-side sidetrack from 17950' with manageable losses of 30 bph indicating Formaset plug was still mostly plugging fracture/loss zone in the old well bore at 18,589'. Drill sidetack hole to 18641' at which point encountered same loss zone with 120+ bbl/hr losses at drilling rate. Pump LCM pills with minimal improvement in losses. Drill to 18,709'. Pump 2nd 100 bbl Formaset plug. Static losses were 0 after 2nd plug was in place. Dynamic losses have not been tested yet. POOH to LD motor. Test BOPS (2 days early) Plan forward- Trip in with rotary steerable assembly. Drill ahead with Formaset plug hopefully keeping losses manageable. The orphaned well bore from 17950' sidetrack point to 18693' has the first Formaset plug in it which was still reducing losses as the sidetrack hole was being drilled. Eventually a slotted liner will be run in the production hole with blank liner and swell packers isolating the orphaned lateral from 17950' to 18693'. I don't think the orphaned wellbore will be productive because it has Formaset in it and will be isolated by the blank liner and swell packers. Do we need to submit a permit to drill for the orpaned well bore? 1 of 2 1/6/2006 1:54 PM 1 C-20 Bond log, drill ahead plan Subject: 1C-20 Bond lob, drill ahead plan From: "Billingsley; Tim A" <Tim.A.Billingsley@conocophillips.com=~ Date:. Mon, 26 Dec 2005 12:02:46 -0~~00 ~Cr~: L)~~von 1 ~ Comhanv elan ~ [_)1 ~C~tii(~l con~~cohhillips.com:=. tom n~a~~naer~"u'•a~lmin.statc.ak.us CC: "!~IcKcc~tr. Ste~~e" °'Steve.l~leKce~~er~~~conoeohhilli~~.cony=~ "Seitz. Brian" <-Bruin.Seilz!u conoeo}~hillihs.rom= a0 S - ~ a-~ Tom Maunder, As we discussed on the phone, the SCMT cement bond log on 1 C-20's 7-5/8" intermediate casing does not indicate very good bond. There is a top of cement at appx 16,700' which is where the top should be but the bond quality is not very good below the TOC all the way down to the bottom of the log at 17500'. Operationally, the cement job went well with good returns and pipe reciprocation and centralizers. The float shoe was set at 17713'. The log was run on drill pipe in the memory mode so there was not an opportunity to pressure up to negate the effects of a possible microannulus. There was 3-1/2 days between the cement in place and the logging run. For now, we will proceed with drilling out the 7-5/8" shoe and perform a FIT to 12.5 ppg. Then drill the production hole and run slotted liner. Later this week, we will discuss with you if and how zonal isolation needs to be further proven on this injector. Tim Billingsley 265-6531 1 of 1 1/3/2006 1:11 PM RE: 1 C-20 BOP test delay request--again • • Subject:RE: 1 C-~~) BOP test delay request--main From: "Billinsley, Tint A" <Tim.A.Billin~sley~conocopl1i11ips.~oi» Dater Wed, 21 Dec 2005 14:07:16 -0900 "Co: `[homas ~1~~uuder ~-tot»_maunder(~r_adn~in.state.ak.us-- ~Q~- \~ '~ The 7-5/8" rams were installed in the upper BOP and a test plug was run. Then the stack was shell tested to 3500 psi and 250 psi on 12/19/05 at 07:45. The casing was run and the cement plug was bumped on 12/21/05 at appx 07:00. Tim Billingsley 265-6531 -----Original Message----- From: Thomas Maunder [mailtc:ton maunder~~admin.state.ak.us Sent: Wednesday, December 21, 2005 11:49 AM To: Billingsley, Tim A Cc: AOGCC North Slope Office Subject: Re: 1C-20 BOP test delay request--again Tim, On further examination over here, it would appear that there is no need for a test delay or an extension. By successfully setting, cementing and testing the 7-5/8" casing, the well construction satisfies the requirement of 20 AAC 25.035 (e) [A well must be equipped with BOPE...except if hydraulic communication to the open hole section is isolated...]. While drilling the 9-7/8" hole the 14 day test interval would have applied and based on your message, your last "drilling test" was on 12/7. It would appear that the timing for completing this hole section was pretty good, since you all were able to successfully TD prior to reaching the 14 day interval. Since you installed 7-5/8" casing rams, a pressure test would have been conducted due to the breaks but since all equipment was not likely tested this action would not meet the criteria of the "full" test". Caution should be exercised when the ongoing operations might crowd the required testing interval. One of the intents in establishing the 14 day test interval was that the operator would use their best judgment to conduct a BOP test sometime prior to 14 days when the opportunity presented itself. Please call or message with any questions. Also, I'd appreciate your providing some information regarding the installation of the casing rams and the testing conducted then. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 12/21/2005 8:59 AM: Tim, Successfully running and cementing the casing has isolated you from any open hole. It is acceptable to conduct the cased hole activities you plan prior to conducting the test on or about Monday 12/26. Call or message with any questions/comments. Tom Maunder, PE AOGCC Billingsley, Tim A wrote, On 12/21/2005 8:53 AM: Tom, On 1C-20 at Kuparuk, 7-5/8" casing was successfully ran to 17,713' last nite and cemented with good returns and good reciprocation throughout. The plug was bumped and the floats held. 1 of 2 1/3/2006 1:10 PM RE: 1 C-20 BOP test delay request--again • • The two-week BOP test is due today, 12/21/05. ConocoPhillips requests that the next BOP be performed just before ', drilling out the 7-5/8" shoe to maximize the two-week window before the subsequent BOP test is due. This would mean that 5" drill pipe would be laid down and 4" drill ', pipe picked up. Then run the SCMT bond log on 4" drill pipe as we discussed earlier. Then test the BOPS prior to RIH with the 6-3/4" production hole drilling assembly. That would put the BOP test probably Monday Dec 26. All of the above work would be done with the hole cased off with 7-5/8" casing. Thank you for your consideration and we are looking forward to your reply. Tim Billingsley 265-6531 office 230-9378 cell 2 of 2 1/3/2006 1:10 PM Re: 1 C-20 cement evaluation log • Subject: Re: 1C-20 cenlenl evaluation log From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 19Dec ?005 14:36: ~~) -~)~)Ofl ~~~_ ~-~ To: "Billin'~slcv, I'iili ,~" =Tim.A.Billin'~slw,cic~~i~ocophillihs.con~=' Tim. This confirms our discussion on Friday. Sorry the LWD sonic didn't work. Good luck with the well. Tom Maunder, PE AOGCC Billingsley, Tim A wrote, On 12/19/2005 2:29 PM: Tom, The approved 1C-20 permit to drill states that we would be using the LWD sonic log to evaluate the cement bond on the 7-5/8" casing for 1C-20 proposed injector. The sonic tool was going to be on the production hole drilling assembly. Unfortunately, the LWD Sonic log on Alpine well CD-2-11 did not prove accurate when compared to a more conventional SCMT log on the same well. So the LWD sonic log will not be run on 1C-20. We are currently running the 7-5/8" intermediate casing at 1C-20. ConocoPhillips proposes to run the SCMT memory log on drill pipe before drilling out the 7-5/8" shoe to obtain cement bond information on 1C-20. The float track will have 3 joints in it so the bottom of the logged interval in this proposal will be about 120' above the shoe. Logging before drilling out the shoe will allow us to drill ahead with the drill out assembly and not trip out to run the log. Also, if there is poor bond, remedial operations would be better conducted before exposing open hole. In addition, after drilling the production hole, there might be lost circulation occurring and it would not be as prudent to log the 7-5/8" for cement evaluation while sustaining significant losses in the well. However, if the SCMT fails to obtain useable cement bond information before the 7-5/8" shoe is drilled out, we would still have the option of trying another log after the slotted liner is run. Thank you for your consideration, Tim Billingsley 265-6531 1 of 1 1/3/2006 1:12 PM Re: Proposed LWD Sonic log for CBL on 1C-~ • Subject: Re: Proposed LWD Sonic log for CBL on IC-20 From; Thomas IVlaunder <tom. maunder@admin.state.ak.us=~ Datc: ~~lon, 0~ .~u~~ ?u0S 11 -Il :~? -0800 ~ ~~_ ~--~ 'I'~-: Etc Cribbs ~-l;ric.C'rihhsi~r)II;~LLIf3~-RTON.com CC: "13illin~~51e~~. ~I~ii1~ ,1" ~ _~fii~~.~~1.l3illin~~sl~~ ~icunoc~~hhillips.cum=~. ~~~hhoma~, IZ~uid_~~~ [,~~ ~~-Rancl~,~.L.~ homasi~r~conoa~phillips.coi7~~- "I~1cKce~~rr, Stc~~e^ ~~S~~v~.[~~1cK~~~ci~ricon~~c~~hhillih~.c~>>Yl~~~. "l~cill~, Patrick J" 'P~ltricl:.J.IZeill~~~r'coi~i~cophillips.cuil~~ . "Johnson, Vern" '-Vcrn..lohnson(rl conocophillips.com== Eric, et al: Yes, I will be interested in seeing how the logs compare. Keep me in the loop please. Tom Maunder, PE AOGCC Eric Cribbs wrote, On 8/8/2005 11:26 AM: Tom, As you may know, we are running the 4 3/" Bat Sonic LWD tool after the upcoming 7'° casing run on CD2-02 and doing a mad pass to see how the data looks on determining the cement top. The wireline bond log will be run later. This will be a very good chance to see what can be presented from our sonic tool and if it will satisfy all the needs that Tim needs on 1 C-28. We will keep you in the loop and if you require anything else, don't hesitate to give me a call. Thanks. Eric Cribbs M/LWD Service Coordinator Sperry Drilling Services Alaska Operations 6900 Arctic Blvd Anchorage, AK 99516 Office Phone: 907-273-3522 Fax: 907-273-3535 Cell: 907-748-3909 -----Original Message----- From: Billingsley, Tim A [mailto:Tim,A.Billingsley~conocophillips.com] Sent: Tuesday, August 02, 2005 5:10 PM To: tom maunder@admin.state.ak.us Cc: Thomas, Randy L; McKeever, Steve; Reilly, Patrick ); Eric Cribbs Subject: Proposed LWD Sonic log for CBL on 1C-20 Tom Maunder, We propose to log the cement job on 1C-20 injector with an LWD Sonic tool instead of conventional CBL or USIT log due to extreme depth and high tangent angle. I have an SPWLA paper on this subject if you would care for me to bring over a copy. Below is our draft proposal for the permit to drill package for your consideration. Thanks, Tim Billingsley 265-6531 1 of 2 1/3/2006 1:16 PM Re: Proposed LWD Sonic log for CBL on 1C-~ «1 C-20 PERMIT IT Sonic for CBL.doc» see page 7, step #14 in bold. «1C-20 PERMIT IT Cover Letter Sonic CBL.DOC» «1C-20 schematic BTC liner7-20-05.vsd» «1C-20 (wp09).pdfy> directional plan This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e-mail and delete all copies of this message. 2 of 2 1/3/2006 1:16 PM PRESSURE INTEGRITY TEST a©s-- `~ CC~NOCOPHILLIPS Alaska, Inc. Well Name: 1 C-20 Rig: Doyon 15 Date: 12/27/2005 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: Whitlock/Rizek Pump used: #z Mud Pump ~ Strokes ~ 0.1007 Bbls/Strk ~ 6.00 Strk/min ~ Type of Test: Casing Shoe Test LOT/FIT ~ , Pumping down annulus and DP. ~ asin Test Pressure In te rit Test Hole Size: 9-~/s" ~ ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 38.5 Ft 17713.0 Ft-MD 6586.0 Ft-TVD 17746.0 Ft-MD 6592.0 Ft-TVD Strks si Min si Strks si Min si Casino Size and De scription: ~-5/e" 29.7#/Ft L-80 BTC-MOD ~ 0 0 0 3510 0 0 0.00 840 Casin Test Pressure Int e rit Test 4 180 1 3485 1 35 0.25 800 Mud Weight: 10.0 ppg ~llud Weight: 10.0 ppg 8 335 2 3485 2 80 0.50 800 Mud 10 min Gel: 9.0 Lb/100 Ft2 Mini 10 min Gel: 0.0 Lb/100 Ft2 12 500 3 3485 3 120 1.00 800 Test Pressure: 3500.0 psi F2o•.ating Weight: ####### Lbs 16 720 4 3485 4 155 1.50 800 Rotating Weight: ###### Lbs Blocksf c p Drive Weight: 70000.0 Lbs 20 850 5 3485 5 190 2.00 80~'~ Blocks/Top Drive Weight 70000.0 Lbs De:~~ ~ed PIT EMW: 12.5 ppg 24 1000 6 3480 6 240 2.50 800 Estimates for Test: 10.1 bbls Estirr ates for Test: 856 psi 2.5 bbls 28 1150 7 3480 7 280 3.00 790 ~ ~ ' ~ 32 1305 8 3480 8 320 3.50 790 EMW = leak-off Pressure + Mud Weight = 870 _ + 10 PIT 15 Second 36 1430 9 3480 9 360 4.00 780 0.052 x TVD 0.052 x 6'86 Shut-in Pressure, si 40 1560 10 3475 10 400 4.50 780 EMW at 17713 Ft-MD (6586 Ft-TVD) = 12.5 ppg 800 44 1740 15 3475 11 430 5.00 775 aooo Lost 50 psi during test, held 48 1880 20 3470 12 460 5.50 775 1 98.6% of test pressure. 52 2040 25 3465 13 500 6.00 775 3500 3000 ~ 2500 N 2000 W lY n. lsoo looo soo 0 0 7 1 2 3 4 5 6 7 8 9 10 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST -f•LEAK-OFF TEST O PIT Point ume - n erme la a sg- - .x s Summary • f ~ l ~ ~ ~' '~ ~ ~ ~ ~ J ~~ i ~ ; ~ ~ ~ ~ x~ " ~ ~ ' b { ~~ ;a1~ ~~,s ~ 3'_ ~ Y ) ~ ~~ ~ ,jam ~`°;~ } ~ {`~~<,, ~ a! ~., ~~` FRANK H. MURKOWSKI, GOVERNOR I ~~~ 0~ ~ ~ j'J 333 W. 7T" AVENUE, SUITE 100 1~T C01`SFjRQAi101` CQ~IISSIO~ ;~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field 1 C-20 ConocoPhillips (Alaska), Inc. Permit No: 205-123 ,Surface Location: 1617' FNL, 1214' FWL, Sec. 12, T11N, RlOE, UM Bottomhole Location: 413' FSL, 2187' FWL, Sec. 16, T11N, R11E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Pleas ovide at least twenty-four (24) hours notice for a representative of the Commission to to ~ any required test. Contact the Commission's petroleum field inspector at 9~,QZ~659-3 a r). N DATED this~loday of August, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com August 4, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Injector, 1C-20 Dear Commissioners: ~~1 V ~~~ Q ~~QJ Alaska Qii has ~r~s, Co~i~nissiars Arscizne`aga ,~ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well, a horizontal well -' in the Kuparuk °C4/C3" sands. The well will be designated as iC-20. 1C-20 will be pre-produced before s being converted to injection later in 2006. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for this well. Since iC-20 will be an injector, the 7-5/8" cement bond quality needs to be logged. The top of the Kuparuk C-4 pay interval will be approximately 50' MD above the 7-5/8"shoe. ConocoPhillips proposes ~-. n~ml~ utilizing a LWD Sonic log to demonstrate cement bond quality above the 7-5/8" shoe. The log will be a ~ MAD pass run with the 6-3/4" production hole drilling assembly. Using Sonic log information to interpret ~ ,vq ~ cement bond quality is not currently an industry standard but there has been some recent examples where good qualitative cement bond results have been obtained from LWD Sonic log data (SPWLA paper LWD Sonic Logging in Cased Holes, June 6-2004). The LWD Sonic log would be run well above the top of cement so that a definitive difference between cemented and uncemented pipe would be observed. The extreme depth 17976' MD and high tangent angle of 72 degrees building to 85 degrees at the 7-5/8" shoe would make it very difficult to obtain a wireline bond log even with a tractor or with drill- ipe conveyed logging tools. ~~ ~ ~ ~,~.~~~~~ o ~~,~c-per The expected spud date of 1C-20 is September 30, 2005. ~-~~ S° ~t ~ ~ Qr° ~OS~S-~-cam If you have any questions or require any further information, please contact Tim Billingsley at 265-6531. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader .-.9~\\ca\s~ohc~.vcc~ e~, SS`T' \°~ %~~// l~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL cc~'s ` ~ ~~~ ~C~.x~~ V au~ a ~ zoos 20 AAC 25.005 4lartr~ flit ScT, f:oe t'nru: t'nmss 1 a. Type of Work: Drill / Redrill Re-ent tY ^ 1 b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Strati ra hic Test / Develo ment Gas kncht~rag~~ Sin le Zone / 9 P ^ Service ^ p ^ g ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1C-20 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 21605' ' ND: 6647' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1617' FNL, 1214' FWL, Sec. 12, T11 N, R10E, UM ~ 7. Prope Designa,~tion ~~- ~ ADL~2~2564~ 8243, 28244 Kuparuk Oil Pool Top of Productive Horizon: ~ 452' FSL, 1437' FEL, Sec. 17, T11 N, R11 E, UM s 8. Land Use Permit: ALK 2292, 3814, 2293 13. Approximate Spud Date: 9/30/2005 Total Depth: 413' FSL, 2187' FWL, Sec. 16, T11 N, R11 E, UM ~ 9. Acres in Property: 1920 14. Distance to Nearest Property: 3093' from KRU bndry 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562222 ~ y- 5968622 ~ Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to Nearest Well within Pool: 1 C-12 @ , 1924' 16. Deviated wells: Kickoff depth: 300 ~ ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3257 psig ~ Surface: 2526 psig 18. Casing Program S ecification Setting Depth Quantity of Cement Size p s Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 80' 40' 40' 120' 120' 9 cu yds High Eariy 13.5" 10.75" 45.5# L-80 BTC 11209' 40' 40' - 11209' - 4564' 1310 sx ASLite, 680 sx LiteCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 17976' 40' 40' - 17976' 6542' 240 sx Class G 6.75" 4.5" 12.6# L-80 IBT 4120' 17826' 6526' 21605' 6647' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Billingsley @ 265-6531 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` ` Phone Z(S~?f'3c Date ~(y~aS- P d 1 Commission Use Only Permit to Drill Number: ~v~^- j'2~ API Number: °~ ~~G. J 50-~~ r ~~Z / ~°"'~,yc„ Permit Approv I ~ Date: ~~ ~ See cover letter for other re uirements q Conditions of approval : ~ ~ ~ ~;~,~~~~-~~1~~ '~~ S mples required Yes No ud log required Yes ^ No H drogen sulfti2d~e,measures Yes ham' No ^ Directional survey required Yes ~ No ^ Other: 3 M~ 1 ~vr-~ Vly~ ~C~`~' ` ~~~~~"'~^(~~Cr ~ ~j~~~b'nG~~Ca~~Cjt~S t~GCC6~~Ct~~o act APPROVED BY ~ O~ Approved y: THE COMMISSION Date: Form 10-401 Revised 06/2004 ORIGINAL Submit in Duplicate .7 ~ication for Permit to Drill, Well 1 C-20 Revision No.O Saved: 29-Jul-05 Permit It - Kuparuk Well #1 C-20 "„~ r.~ ~~- Application for Permit to Drill Document •,r;, IIr+1c~We11 Mpxirriix~ well Vaiue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ....................................:.............................................................. 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI FloPro) ........................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 10.Seismic Analysis ..................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1C-20 PERMIT IT.doc Page 1 of 8 Q ~ ~ /~ ~ ~ A t Printed: 29-Jul-05 • ~lication for Permit to Drill, Well 1 C-20 Revision No.0 Saved: 29-Jul-05 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Summary ........................................................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (i) Each we/l must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). Far a well with multiple we/l branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-20. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (Z) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we/l at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1617' FNL 1214' FWL Section 12 T11N R10E UM ASPZone 4 NAD 27 Coordinates RKB Elevation 100.6' AMSL Northings: 5,968,622 Eastings; 562,222 Pad Elevation 60.6' AMSL Location at Top of Productive Interval (7- 452' FSL, 1437' FEL, Section 17, T11N, RilE, UM 5/8" shoe near top Ku aruk "C4" Sand ASPZone4 NAD27Coordinates Measured De th, RKB: 17,976 Northings; 5,960,249 Eastings: 575,152 Tots/ I/ertica/De th, RKB: 6,542 Total l/ertical De th SS.• 6 441 Location at Total De th 413' FSL, 2187' FWL, Section 16, T11N R11E, UM ASPZone 4 NAD 27 Coordinates Measured De th, RKB; 21,605 Northings: 5,960,247 Eastings: 578,776 Total vertical De th RKB: 6 647 Total l/ertical De th, SS.• 6,546 and 1C-20 PERMIT IT.doc Page 2 of 8 ^ ~ ~ ~ f Printed: 29-Jul-05 • ~ation for Permit to Drill, Well 1 C-20 Revision No.O Saved: 22-Jul-05 (D) other information required by 20 AAC 25,050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete well 1C-28. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Kuparuk sands in the iC-20 area vary from 0.42 to 0.49 psi/ft, or 8.1 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby 1C-12 Kuparuk well and modeling for non-depleted reservoir as 1C- 20 is drilled horizontally further to the east. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Kuparuk sand formation is 2,493 psi, calculated thusly: MPSP =(6,647 ft)(0.49 - 0.11 psi/ft) = 2,526 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. f and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(17; 1 C-20 PERMIT /T. doc Page 3 of 8 O R I G I N A L Printed: 22-Jul-05 ~ation for Permit to Drill, Well 1 C-20 Revision No.0 Saved: 22-Jul-05 A procedure is on file with the commission for performing LOT's. For 1C-20, the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs or 18.0 ppg EMW maximum is observed. (see step 6 in the procedure) 6. Casing and Cementing Program Requirements of 20 AAC 25.OO5(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MDlTVD MD/TVD OD in in Ib/ft Grade Connection ft ft ft Cement Pro ram 16 24 62.58 H4O Welded 80 40 / 40 120 / 120 Cemented to surface with 9 cu yd High Earl 10-3/4 13-1/2 45.5 L-80 BTC 11209 40 / 40 11209 /4564 Cemented to Surface with 1310 sx ASLite Lead, 680 sx LiteCRETE Tail 7-5/8 9-7/8 29.7 L-80 BTCM 17976 40 / 40 17976 / 6542 Cement Top planned @ 17126' MD / 6397' TVD. Cemented w/ 240 sx Class G + additives 4-1/2 6-3/4" 12.6 L-80 IBT 4120 17826 / 6526 21605 / 6647 Slotted- no slotted Lateral cement 7. Diverter System Information Requirements of 20 AAC 25.OO5(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1C-20. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 7C-20 PERMIT IT.doc ~~"~~ Page4of8 {t~~~ Printed: 22-Jul-05 • ~lication for Permit to Drill, Well 1 C-20 Revision No.O Saved: 29-Jul-05 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Interval Drilling Fluid System Spud Mud INTERVAL MUD PROPERTIES Properties Spud to Base of Permafrost Base of Permafrost to TD Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 - 8.6 9.4 - 9.6 9.4 - 9.6 9.6-10.0 Funnel Viscosity (seconds) 250 - 300 250 - 300 200 - 250 200 -250 Yield Point (cP) 50 - 80 50 - 80 30 - 60 30 - 60 Plastic Viscosity (Ib/100 sf) 8 - 15 11 - 22 12 - 30 12 - 30 10 sec Gels (Ib/100 sf) 15 - 30 15 - 30 15 - 30 15 - 30 10 min Gels (Ib/100 sf) 25 - 55 25 - 55 25 - 65 25 - 65 pH 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 API Filtrate(cc) 8-15 <8 <8 <6 Solids(%) 5-8 5-8 5-8 6-10 Intermediate Interval Drilling Fluid System ` LSND INTERVAL MUD PROPERTIES Properties Initial Value Final Value through HRZ Density (ppg) 9.4 - 9.5 10.0 - 10.2 Funnel Viscosity (seconds) 35 - 41 38 - 45 Yield Point (cP) 24 - 30 24 - 30 Plastic Viscosity (Ib/100 sf) 10 - 15 15 - 20 Chlorides <600 <600 pH 9-9.5 9-10 API filtrate <6 4 - 5 HTHP filtrate <10 <10 MBT <20 <20 Solids ppb <11 <12 a 1C-20 PERMIT IT.doc Printed: 29-Jul-05 O R 1 G 1 N A ~. Page 5 of 8 ~lication for Permit to Drill, Well 1C-20 Revision No.O Saved: 29-Jul-05 Production Drilling Interval Drilling Fluid System Flo Pro Drill-in Fluid PRODUCTION INTERVAL MUD PROPERTIES Kuparuk Sand. Properties Initial Vaiue Density (ppg) 9.2-9.5 Funnel Viscosity (seconds) 35 - 45 Yield Point (cP) 20 - 30 Plastic Viscosity (Ib/100 sf) 10 - 15 Chlorides <600 pH 9 - 9.5 API filtrate <6 HTHP filtrate <10 M BT <5 Solids ppb <3 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dril/ must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application; (9) for an exploratory or stratigraphic test we/% a tabulation setting out the depths of predicted abnorma/ly geo pressured strata as required by 20 AAC 25.033(x); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dri/l must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel% a seismic refraction or reflection analysis as required by 20 AAC 15.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Dril/must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the app/ication.• (11) for a well dril/ed from an offshore platform, mobile bottom-founded structure, jack-up rig, ar floafrng drilling vess% an analysis ofseabed conditions as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application; (12) evidence showing that the requirements of ZO AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1C-20 PERMIT /T.doc Page 6 of 8 Printed: 29-Jul-05 ORIGINAL • ~ation for Permit to Drill, Well 1 C-20 Revision No.O Saved: 1-Aug-05 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in /rig up Doyon Rig 15. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Run MWD tools as required for directional monitoring. 3. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. 5. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD (GR/RES) & PWD. RIH, clean out cement to top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results. 6. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. Do not exceed 18.0 ppg EMW. 7. Directionally drill to 7-5/8" casing point as per directional plan. 8. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud. 9. Install wellhead 7-5/8" packoff and test to 5000 psi. 10. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. il. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD (GR/RES/DENS-NEU and Sonic) logging tools. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 12. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. Do not exceed 16.0 ppg EMW. 13. Directionally drill 6-3/4" hole to TD as per directional plan. i 14. POOH, back reaming out of lateral. Log up with Sonic log (MAD pass) across 7-5/8" shoe and up above top of cement. POOH. Download Sonic log information and report cement top and bond information. 15. PU and run 4-1/2" slotted liner with swell packers as needed. 16. Set liner hanger and ZXP liner top isolation packer. Release hanger running tool. POOH. 17. POOH, laying down drill pipe as required. 18. P/U and run 4-1/2" completion equipment with one GLM with shear out valve in GLM, RIH to depth. Circulate corrosion inhibited brine into the 4-1/2" x 7-5/8"annulus. 19. Land tubing. Set BPV. 20. Nipple down BOPE, nipple up tree and test. 21. Shear out valve in GLM, freeze protect the tubing and IA with diesel. 22. Move rig off. 23. Pull BPV. Change out shear valve for dummy valve. MITIA. 24. Set live gas lift valves in mandrels. 25. Flow back well to portable test separator to clean up well. 1C-20 PERMIT IT Sonic for CBL.doc Page 7 of 8 n ~ ~ ~ ~ /~ ~ Printed: 1-Aug-05 • 24. Pull BPV. Change out shear valve for dummy valve. MITIA. 25. Set live gas lift valves in mandrels. 26. Flow back well to portable test separator to clean up well. 27. Secure well for facility hook-up. •lication for Permit to Drill, Well 1 C-20 Revision No.O Saved: 29-Jul-05 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. ©80 for an annular disposal operation in the wel%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1C Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iC Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Summary Attachment 4 Well Schematic 7C-20 PERMIT IT.doc Page 8 of 8 Printed: 29-Jul-05 ORIGINAL iC-20 Drilling Hazards Summarx 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce +' drillin fluid tem eratures Additions of Lecithin. Gravel /Sand Sloughing Moderate Increase mud weight /viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill (use of tri sheets Pum in out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur -reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Miti ation Strate Shale stabili in HRZ and K-1 Moderate Control with hi her MW and ro er drillin radices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fatl behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drillin a interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Miti ation Strate Trouble Sliding /Steering Moderate Bit/BHA design will take into account historical problems in offset horizontal wells with steering. Rotary steerable assembly will be used unless equipment failures occur. LOTAD's friction reduction devices will be used. Water based Mud lubricants will be used. Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended period of time. Lube pills will be ready to be spotted if a stuck i e incidents occurs. Difficulties getting liner to bottom Moderate Torque/drag will be monitored while drilling the interval. with swell packers Pump out of hole on final trip out prior to running liner to ensure hole is clean. Utilize torque rings to allow rotation of liner. S of tube ills in o en and cased hole if needed. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, pre-treat with LCM prior to drilling fault crossings. Use LC decision tree designed for production laterals. An extensive LC strategy will be documented in the well plan. 1C-20 Drilling Hazards Summary.doc prepared by Tim Billingsley 6/29/05 ORIGINAL ~ m 1C-20 Horizont~Well Proposed Completion Base Case Schematic 4-1 /2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT pin down (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required (Special Drift to 3.91") 4-1 /2" 12.6# L-80 IBT Tubing to Surface (Special Drift to 3.91") 4-1/2" Camco'DB' nipple w/ 3.875" No-Go Profile set at +/- 500' MD 6" conductor 78' BGL Surface csg. 10-3/4" 45.5# L-80 BTC Special Drift - 9.875" ~ 11209' MD / 4564' TVD (200' TVD below Base West Sak) Intermediate csg. 7 5/8" 29.7# L-80 BTCM ~ 17976' MD / 6542' TVD (App. 50' MD below top of C4) unc~ r~aam nury - a y - ..,+7 ., - Baker 5'/z' x 7 5/8" `ZXP' Liner Top Isolation Packer w/ HRD running profile Baker 5'/i' x 7 5/8" RS Nipple Baker 5'/s" x 7 5/8" `Flexlock' Liner Hanger Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore) 4'/z' 12.6# L-80 BTC with torque rings alternating slotted and blank pipe w/ swell packers (installation of blank pipe & swell pkrs TBD with well logs) 4'/s" ROT 'Silver Bullet' Shoe, IBT with torque ring and Xoverto BTC 4-1 /2" 12.6# L-80 IBT tubing to landing nipple (Special Drift to 3.843") 4-1/2" x 1" Camco'KBG-2' Mandrel w/ shear out valve (Max. OD 5.984", ID 3.833") Spaced out w/ 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as follows: GLM # ND-RKB MD-RKB 1 2600 4833 4-1/2" Camco'DB' nipple w/ 3.813" No-Go Profile set @ bottom of tangent section +/- 17,035' MD / 6357' TVD, 72.1 deg 4-1/2" 12.6# L-80 IBT tubing from 'DB' nipple to sliding sleeve (Special Drift to 3.843") 1 jt 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") 4.75" OD Baker casing seal assembly w/ 17 Ft. stroke, 4-1/2" 12.6 # L-80 IBT box up (landed 3-4' off fully landed position) • ConocoPhillips 4'/i' x 6.3" Swell Packers for isolation of potentially three conductive faults or wet intervals --- --~ Slotted Liner 4-1/2" 1 .6# L-80 BTC with torque --- ---T I ORIGINAL Tim Billingsley 7/20/05 C4/C3 Lateral to 21,605' MD Rig: DOYON 15 Location: KUPARUK Client: CPAI. Revision Date: 7/22/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com < TOC at Surface 1 Previous Csg. < 16", 62.6# casing at 78' MD < Base of Permafrost at 2,335' MD (1,793' ND) < Top of Tail at 8,235' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 11,209' MD (4,563' TV D) Mark of Schlumberger CemCADE Preliminary Job .Design 10 3/4" Surface reliminary Job Design based on limited input data. For estimate purposes only. Schl~mberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 8,235' MD. Lead Slurry Minimum pump time: 450 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (78') x 1.00 (no excess) = 49.8 ft3 0.3637 ft3/ft x (2335' - 78') x 3.50 (250% excess) = 2872.5 ft3 0.3637 ft3/ft x (8235' - 2335') x 1.35 (35% excess) = 2897.1 ft3 49.8 ft3 + 2872.5 ft3+ 2897.1 ft3 = 5819.4 ft3 5819.4 ft3 / 4.45 ft3lsk = 1307.7 sks Round up to 1310 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 300 min. (pump time plus 90 min.) LiteCRETE @ 12.5 ppg - 2.24 ft3/sk 0.3637 ft3/ft x (11209' - 8235') x 1.35 (35% excess) = 1460.2 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 1460.2 ft3 + 43.2 ft3 = 1503.4 ft3 1503.4 ft3/ 2.24 ft3/sk = 671.2 sks Round up to 680 sks BHST = 102°F, Estimated BHCT = 91 °F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (mint CW100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 75 15.0 40.0 Lead Slurry 7 1038 148.3 188.3 Tail Slurry 6 271 45.2 233.5 Drop Top Plug 8.0 241.5 Displacement 7 1055 150.7 392.2 Slow Rate 3 15 5.0 397.2 MUD REMOVAL Recommended Mud Properties: 10.1 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv~ 17-21, TY~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Rig: DOYON 15 Location: KUPARUK Client: CPAI Revision Date: 7/22/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com Previous Csg. ' < 10 3/4", 45.5# casing at 11,209' MD < Top of Tail at 17,126' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 17,976' MD (6,541' ND) * Mark of Schlumberger CemCADE Preliminary Job Design 7.625" Intermediate Casing reliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 850' shoe tack. Tail Slurry Minimum thickening time: 250 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.02%6155, 0.40% D167 -1.16 ft3/sk 0.2148 ft3/ft x 850' x 1.40 (40% excess) = 255.6 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 255.6 ft3 + 20.6 ft3 = 276.2 ft3 276.2 ft3/ 1.16 ft3/sk = 238.1 sks Round up to 240 sks BHST = 153°F, Estimated BHCT = 118°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (mini CW100 5 20 4.0 4.0 Drop Bottom Plug 15.0 19.0 MudPUSH II 5 30 6.0 25.0 Tail Slurry 5 50 10.0 35.0. Drop Top Plug 10.0 45.0 Displacement 6 802 133.7 178.7 Slow Rate 3 20 6.7 185.4 MUD REMOVAL Recommended Mud Properties: 10.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* II, Pv ~ 19-22, TY ~ 22-29 Centralizers: Recommend 1 perjoint across zones of interest for proper cement placement. ORIGINAL • ~ . ConocoPhill~ps ~~ CanocaPhillips Alaska (Kuparuk Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-2D 1C- 20 Permit Plan Proposal Report 20 July, 2005 • ~~ ~1'tj~t~~ .~@I~VC$$ ORIGINAL ~`~ ./1/ +~+~.~ 1 ~110CC.~~~11~~i~5 Aiaska PIIX1]t3Cts KuPatuk River tlnft Bites Kuv~-aruk 1C Pad 1Ak~lls Plans 10.30 Weilbore: P~n;1~-20 Plan;.. 1C-30 (wPQB- CASING DETAILS No TVD MD Name Stie 1 4563.80 11209.18 /0 314" 10+3!4 2 854L83 17978.09 7 518'• 7-8/8 3 6848.80 21804.58 4112" 41!2 i REFERENCE INFORMATION I SNL@1817ftFNL1214ftFWL-Sac 12-T1iN-810 KOP @ 300ft MD, 300ft TVD - 8ulid @ 3°/10 CoMlnuo tiulld @ 4/100ft , 633tt MD, 8328 JVy~py~V... ' /_ _ Sall @ 66°Ino 8 785°Azf : 2038ft MD, 1881ft TV tr-_ ~- _. _ _ - ~ ~ Continue Build @41100fl, 2183ft MD, 9752ft .- - . - - ' ~ ~~ _ _ SaII @ 72°I nc & 18b°AZl : 2334ft MD, 18078 TV~ 1ti~ - - ' - f ~g1f'--'--- ---------- _ - ~ - - _ - ~ -- - " Cotttlnue Turn @ 3/100ft , 2834ft MD, i981ft TV ti~ *ry$ _ Sall @ 72Wnc 8117.7°AZl :43308 MD, 2447ft T C S .~.. ~p Z ~~.. -1 T M Azimuths to True North Magnetic North: 24.65° Magnetic Field Strength: 57560.2nT Dip Angle: 80.80° Date: 12131fZ004 Model: BGGM2005 Mi11 LL E3l.,f F3"F'C3tV iperry bdgiwa 8~rolcra'..., 1000 2000 3000 West(-)!East(+) (2000 Nin) Co-ordinate (N/E) Reference: Well Plan: 1 C•20, True North Vertleal (TVD) ReTorenee: Doyon 15 RKB @ t00.60ft {{40+80.6}) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Doyon 16 RKS @ t00.60ft ((40180.6}) CalculatlonMethotl: MinlmumCurvature ~ WELL OETAILa: Poon: 1G20 i 80.60 +N/-9eE/-W Northi~ Ea~irig Latlttude Lor~tude 9bt 0.00 0.005882230 5822221070°18'28.28N1d9`29'43848W 10 3l4" CSG -11208ft MD, 4584ft ~-- Cantinas GeoSteering INZONE : 18565ft MD, 6578ft ~ i i ,' Sail @ 88.58°Inc & 90.!13°AZI : 78048ft MD, 8547ft ` ' ~BHL 1C-20 {Wp09) - 21605ft MD, 6647ft~N ~ ~ ~ i ., ~ i I ~ i I ~ I ~ i I ~ ~ I C)yy~yt P~oiy de~ixrx~eyw a Ccmrrr~)tar 14flp" NyL~rth and T 1tP~4 m~tlUttl Qa 6i 1R. ~ft~~W*.~ ~~1~l~l~t~t ~i a ` ~ 4 vz'; ~ g., I , wild 8 Turn @ 31100ft , 17035ft MD, 8357ft ' _ - J ' _ - ~ ~ ~ ~ ` ~ ~ r 'i r r i ~~ ~ ~ ~ i :' ~ ~ 7 t/8" CSG - 178768 MD, 6542ft ~ ~ i i ~ i (' ~ 4000 500p 600p 7000 8000 9000 10000 11000 1200p 13000 1400p 1500p 160p0 '-°~''~ N 4{ALLtE3 1lATQttf __ Project; Ku~aruk Ft(ver Unit °" ~"11~~ 1 '~O~ s w++y ~~ no ~~ Situ; KlaparWk 1 C Paid i CO ~ Wall; F~ian; 1 C-20 ~ _ SHL ~ 1617ft FNL 1214ft FWl_ -Sec 12 - T11 N - R10E~ ~ 1Ne((bore; plart;1 ~- ~¢ -3oao - ~ -- Plan, t G-20 (wp09) _ I^~ @ 300ft MD, 300ft TVD - Build ~ 3°1100ft'~ 1 -2000 Continue Build @ 4/100ft , 633ft MD, 632ft TVD ~~ ~ Sail ~ 66°Inc & 165°A~i ; 2033ft MD, 1691ft 7VD~ ~ -' Continue Build ~ 4/100ft , 2183ft MD, 1752ft TVD 1000 ,' ,' -' Sail @ 72°Inc & 165°Azi : 2334ft MD, 1807ft TVD .~ _ " _ - Continue Tum ~ 3/100ft , 2834ft MD, 1961 ft TVD 0 0° - _ 20' ' 1000 - "" ' AO' ~ ~ - " " Sail @ 72°1nc & 117.7°Azi : 4330ft MD, 2447ft TVDj ~~-' 2000... °~~ "- _ _ --- LBase of Permafrost - 10 3/4" CSG - 11209ft MD, 4564ft TVD Build & Turn ~ 3/100ft , 97035ft MD, 6357ft TVD ' ~ ~~ 7 518" CSG - 17976ft MD. 6542ft TVD ~ 3000 i i "-- _ Top Ugnu~ ---.-...----.-...-... __-._._....._..______...___.._....__._.,_..---_..........__.i..._. ~ ~' ~ _.._ - ------------------- -- 4000 Tcp West Sak D n,`~ ,' ~~ r `' ~ Base West Sa~ ~ ~ ~ BHI.1C-20 (wp09} - 21605ft MD, 6647ft TVD ~ 5000 ~ i ~' TopHRZ~ r - ~ Base Hinz ' - i , ~~ < ; `~ 41/2" , ` 6000... ~- ---_ , _ f- ~- ~_ r~ _ : .~- ~ _ ~ w _ _ _s_~_-...-___ _ _ _ ---_ ____r_-~--.------._.42 __,~ __ C4I D-Shale i F{~FMATICJN IC;t'C7CvfAILE3 i N3Y'pFath htDPath Ponnafiert 1 i?Db 6D «334 t D Base ct Parmatrost 2 61`35 50 689r -~' 7op Ugnu U -3 1494 FjQ gD'3 ~$ TOp'tlU~rSC 9ak D 4 9863.50! 0589 82 base Wiest Sa k 5 61RA.6DIS378.`3f Top HR? 6 5365.5'017D6~21 Bese Ht2Z 7 r451.50173t39.~'•0 K1 8 P5:~~.501778E-70 0.Shale 9 6537.60178^6.09 C4 i i ~ ~~ 1C :} b = ~.'.1 i' ~ i ~ ~' ~i ~ C =t:i T1 + i+i ~ ~~ ~ ~ i 1 ~ ~' ; ~ iGrYi ri (wyp0`?) rrt ?(~ rl {:, nf's9k Sail ~ 86.58°Inc & 90.53°Azi . 18046ft MD, 6547ft TVD ~ L Continue GeoSteering INZONE : 18565ft MD, 6578ft TVD -1000 0 1000 2000 3000 4000 5000 600p 7000 8000 9000 10000 1 14000 15000 16000 17000 18000 ~ ~•' ~ Halliburton Company ~ f~u~Tt~nr ,~-~ ~OI"IC3CC~~111~ ~p~5 Planning Report - Geagra~nic . . -- _ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 1C-20 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyon 15 RKB ~ 100.6QR ((40+60.6)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB ~ 100.60ft ((40+60.6)) Site: Kuoaruk 1C Pad North Reference: True hell. Plan: 1C-20 Survey Calculation Nletttod: Minimum Curvature Weilbore: 1C- 20 Permit Plan Design: 10-20 (vvp09) Plan Summary Measured Vertical Dogleg Build Turn depth Inclination Azimuth Depth +NIS +E!-W Rate Rate Rate -t"FO (>~) ~°} (°) (ff) (ft? (ft) (°F10fltt) (°1iUQft} (°1906ft) ~°} 40.00 0.00 0.00 40.©0 0.00 0.0o O.oO 0.00 0.00 0.00 300.00 0.00 0.00 300.E a.o0 0.~ 0.00 0.00 0.00 0.tm 633.33 10.00 165.00 631.64 -28.03 7.51 3.00 3.00 0.00 i65.Q0 2,033.33 66.00 165.00 1,691.47 -827:84 221.82 4.00 4.00 0.00 0.00 2,183,33 66.00 165.00 1,752.48 -960.20 257.28 0.00 0.00 0.00 0.00 2,334.33 72:04 165:00 1,806.52 -1,096.32 293.76 4:00 4:fl0 0:00 0.00 2,834.33 72.04 165.00 1,960.69 -1,555.75 41fi.86 0.00 0.00 O.tIO 0.00 4,329.93 72.08 117.70 2,446.50 -2,629.06 1,275.24 3.00 0.00 -3.16 -97.64 17,035.31 72.08 117.70 6,356.59 -8,248.96 11,978.27 0.00 000 0:00 0.00 18,045:62 86.58 90..53 6,546.62 -8.,4$2..56 12,930,34 3.00 1.44 -2.69 -64.59 18,095.62 86:58 90.53 6,549.60 -8,4$3:02 12,980.25 0:~ 0:00 0:00 0. 18,565.34 86.58 90.53 6,577:60 -8,487.38 13,449.12 0.00 4.00 0:00 0.00 18,745.84 92.00 90.53 6,579.84 -8,489.06 13,629.53 3.~ 3.00 0.03 0.(M? 19,096.85 92.Q0 90.53 6,567.60 -8,492.32 13,980.31 Q,08 0.00 0.00 0.00 19,120.35 91.29 90.47 6,566.92 -8;492.52 14,003.80 3.00 -2.99 -0.25 -175.26 19,665J2 91.29 90.47 6;559.60 -8,497:03 14,549:01 0.00 0:00 0:00 0.00 19,790..01 87.57 90.48 6,555.$4 -8,498.06 14,673.27 3.00 -3:00 0.00 179.98 20,349.65 87.57 90.4$ 6,579.60 -8,502.70 15,232.3$ 0.00 0.00 0.00 0.~ 20,370.71 86.93 90.48 6,580.61 -$,502.87 15,253.42 3.00 -3.00 0.00 -179.99 21,604.56 86.93 90.48 6,646.60 -8,513.~J 16,485.46 0.00 0.00 0:E?0 O.OU 7!2012+705 72: t3:25Ph~, Page 3 of 10 CpNlPASS 20©3.17 Buitzt ~ ORIGINAL ~~ C~nacoP'hillips Alaska Database: EDM 2003.11 Single User Dt; Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 C Pad Welt: PIan:1C-20 Weiibare: 1C- 20 Permit Plan Design: 1C-20 (wp09j Halliburton Company ~ t-~1~~L,t#31.~:1~tTL'~!v Plsr!ning deport - ~eogfapnic __ _ _ --____-- 8psrry Seevilates Local Coordinate Reference: Welt Plan: 1C-20 7VD Reference: Doyon 15 RKB Gdi 100.60ft ((40+60.6)) MD Reference: Doyon 15 RKB ~ 100.64ft ((40+60.6}) North Reference: True - Survey Calculation Method: Minimum Curvafure - Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Gea Datum: NAD 3927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well flan: 1C-20, Planned from slot between 1G-02 and 1C=15 Well Position +Nl-S 0:00 ft Northing: 5,968,622.30 ft ~ Latitude: 70° 19' 29.280" N +E/-W 0.00 ft Easting: 562,222.10 ft ~ Longitude: 349° 29' 43.646" W Position Uncertainty O.QO ft Wellhead Elevation: ft Ground Level: 6Q.60ft Welibore iC- 20 Permit Plan l Magnetics Model Name Sample Date Declination Dip Angie Feld Strength { BGGM2005 12/31/2004 24.65 80:80 57,560 ~__ -___ ~~ Design _ -- bC-20 (wtp09) --- Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 l Vertical Section: Depth From (TVD) +N/S +E/-W Direction I (ft) (it} (ft) (°} ~~ i 40:00 0.00 0:00 80.50 j 7120120(15 12,13:25Pltd Page 2 of 10 CU1Mf'ASS 20Q3.11 Build 48 ORIGINAL ~ ~ ~ ~ Hal liburton Compan y a ~~ t~ ~'r~nr ~~C)1'IUCC~~"11~~ Piar:.n ing Report - Gea~rapn ic . - $~r ,. *Y Dr~!'~g - -- - Serviaiss Database: EDM 2003.11 Single user Db Loc at Co-ordinate Reference: Well Plan: 'C- 2G Company: Conoco Phillips Al aska (Kuparuk) TVD Reference: Doyon 15 RKB @ '100.608 (( 40+60.6)) Project: Kuparuk River Und MD Reference: Doyon 15 RKB @ 100.60ft (t 40+60.6}} Site: Kuparuk 1 C Pad No rth Reference : True Well: Plan: 1C-20 Survey Calculation Method: Minimum Curvature Wellbore: 1C- 20 Permit PEan Design: 1 C-20 (wp09) Planned Survey 1C-20 (wp09} Map Map ', fAD tnclination Azimuth TVD SSTVD +N{S +E{-W Nortteing Fasting DLSEV Vert Section (ft} (°} (°} (ft) (ft) tft} (ft) (ft} (ft} (°/106ft} (ft} '. 40.00 0.00 0.00 40.00 -60.60 0.00 0.00 5,968;622.3fD 562,222.10 0:00 0.00 SHL @ 161 7ft FNL 1214ft FWL -Sec 12 -T11N - 890E ~ 100;00 0:00 0:00 100:00 X0.60 0:00 0:00 5,968;622.30 562,222.10 0.00 0.00 200.00 0:00 0:00 200:00 99.40 0:00 OAO 5,968,622.30 562;222.10 0..00 0.00 300.00 0.00 0,:00 300.00 199.40 0.00 0:00 5,968,622.30 562,222.10 0:00 0.00 KOP @ 300ft MD, 300ft ND - Buiid @ 3°1100ft 400.00 3.00 165.00 399.95 299.35 -2.53 0:68 5,968,619:78 562,222.80 3.00 0.70 500.00 6.00 165.00 499.63 399.03 -10.11 2.71 5;968,612.22 562,224.89 3A0 2.80 600.00 9.00 165:00 598.77 498.17 -22.71 6:09 5;968,599:64 562,228.37 3.00 6.28 633..33 10:00 165.00 631:64 531..04 -28:03 7.51 5,968,594.34 562,229.84 3:00 7.75 Continue Build @ 4f100ft , 633ft MD, 632ft TVD 700.00 12.67 165:00 697.00 596:40 -40.68 10.90 5,968;581.72 562,233.34 4.00 11.25 800.00 16.67 165:00 793.73 693.13 -65.13 17.45 5;968;557.32 562;240:09 4,00 18A2 900,00 20.67 165.00 $88.45 7$7.85 -96.04 25..73 5,968,526.48 562,248.63 4:00 26:57 1,000:00 24:67 165.:00 980.70 880.10 -133.26 35.71 5;968,489.36 562,258..91 4:00 36.87 1,100.00 28.67 165.00 1,070A5 969.45 -176.60 47.32 5,968,446.12 562,270,88 4.00 48.86 ' 1,200.00 32.67 165.00 1,156.05 1,055.45 -225.86 60.52 5,968,396,98 562,284.48 4.00 62.49 1,300.00 36.67 165.(10 1,238.28 1,137.68 -280.79 75.24 5,968,342.17 562;299.65 4.00 77.68 1,404.00 40.67 165.00 1,316.34 1,215.74 -341.12 91.40 5,968,281.98 562,316.32 4.00 94.38 1,500:00 44.67 165.00 1,389,86 1,289.26 -406.57 108.94 5,968,216.68 562,334.40 A.00 112.49 1,600:00 48:67 165:00 1,458.47 1,357.87 -476.82 127.76 5;968,146:60 562,353.80 4.00 131.92 1,700.00 52.67 165:00 1,521:84 1;421.24 -551.52 147.78 5,96$;072:08 562,374.43 A:00 152.59 1,800.00 56.67 165.00 1,579:66 1,479.06 -630.30 168,89 5,967,993.48 562,396.19 4.00 174.38 1,900.00 60.67 165.00 1,631.65 1,531.05 -712.79 1.99 5,967,911.19 562,418.98 4.00 197.20 2,000.00 64.67 165.00 1,677.56 1,576.96 -798.58 213.98 5,7,825.60 562.,442.67 4.00 220.94 2,033.33 66,00 165.00 1,691.47 1,590.$7 -827.84 221.82 5,967,796.41 562,450.75 4.Q0 229:03 Sail @ 66°Inc & 165°Azi : 2033ft MD, 1691ft TVD 2,100.00 66.00 165.00 1,718.58 1,617.98 -886.67 237.58 5,967;737.72 562,467.E 0.00 245.31 2,183:33 66.00 165,00 1,752.48 1,651.88 -960.20 257.28 5,967,664.36 562,487.31 0.00 265.65 Continue Build @ 4/100ft , 2183ft MD. 1752ft ND 2,200.00 66.:67 185.00 1,759.17 1;658.57 -974.95 261.24 5,967;649:65 562,491.39 4.00 269.73 2,300:00 70.67 165:00 1,795:54 1;694:94 -1,064.90 285.34 5,967,559.90 562,516.23 4.00 294.62 2,334.33 72.04 155:00 1,806.52 1,705.92 -1,096.32 293.76 5,967,528:56 562,524.99 4.00 303.39 Sail @ 72°Inc & 165°Azi : 2334ft MD, 1807ft TVD 2,334.60 72.04 1'65.00 1,806.60 1,706.00 -1,096,57 293.82 5,967,528.31 562,524.98 0.00 303.3$ Base of Perma#rost i 2,400.00 72.04 165.00 1,826.77 1,726.17 -1,156.66 309.93 5,967,468.36 562;541:58 0.00 320.01 i 2,500.00 72.04 165.00 1,857.60 1,757.00 -1,248.55 334.55 5,967,376.69 562,566.96 0.00 345.43 2,600.00 72.04 165:00 1,888.44 1,787.84 -1,340.43 359.17 5,967,285.02 562,592,33 0.00 370:85 2,700.00 72.04 165.00 1,919.27 1,818.67 -1,432.32 383.79 5,967,993.35 562,617.71 0-00 396.27 2,800:00 72:04 165.00 1,950.11 1,849:51 -1,524.20 408.41 5;967,101.68 562,643.09 0.00 421.69 2;834.33 72:04 165:00 1,960:69 1;860.:09 -1,555.75 416.86 5,967,070.29 562,651..81 0.00 430,42 Continue Turn @ 3t109ft , 2834ft MD, 1961ft TVD 2,900.00 71,79 162.94 1,981.08 1,880.48 -1,615.74 434.10 5,967,010.36 562,669.54 3.00 448.18 3,000.00 71.45 159.80 2,012.62 1,912.02 -1,70.5.66 464.40 5,966,920.71 562,700.58 3,00 479.26 3,100.00 71.16 156.65 2,044.68 9,944.08 -1,793.61 499.53 5,966,833.06 562,736.43 3.00 515.16 7/20/2005 12:13:25PA~ Page 4 of 10 GO1btPASS 2003. i1 Swld 48 ORIGINAL ,~[~.. t1 ~ Hailiburton Company • ~~.t.tc~u~~r~~t CAC1QCt3Rh1~~ Planning Report - geographic r ~ ____ Seevia~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kup~Nk) Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: Pion: iG20 Weilbore: 1C- 20 Permit Plan Design: iC-20 (v~09) Planned Survey 1C-20 (wp09) MD terclination Azimuth TVD eft) (°1 (°~ (ft1 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: SST1/D +NlS +E!-W %ft) eft? tft) Wel? Plan: 1C-<~ Doyon 15 RKB ~ 1 W.60ft ((40+60.6)) Doyon 15 RKB @ 100.6C~ft ((40+60.6)) True Minimum Curvature i i Map Map Northing Fasting DtSEV Vert Section eft) (~} (°MQOft} (ft} 3,200.00 70:93 153.49 2,077.17 1;976.57 -1,879.36 539.38 5,966.,747:65 562,777.00 3.00 555.76 3,300.00 70.75 150.32 2,110.01 2,009.41 -1,962.68 583.86 5,966,664.72 562,822.16 3.~ 600.97 3,400:00 70.62 147.14 2,143:10 2,042.50 -2,043.33 632.84 5,966,584.48 562,871.80 3.00 650.64 3,500.00 70.55 143.96 2,176.35 2,075.75 -2,121.Q9 686.1.8 5,966,507.17 562,925:77 3.00 704.66 3,600.40 70.53 140.78 2,209.67 2,109.07 -2,195.75 743.74 5,91fi6,433:00 562,9$3.94 3,00 762.$7 3,700.00 70.57 137:60 2,242.97 2.,142.37 -2,267.11 805.35 5,966,362..16 563,046..15 3:00 825.11 3,800.00 70.67 134.42 2,276.15 2,175:55 -2,334.97 870.86 5,966,294.85 563,112.21 3:00 891.21 3,900.00 70.82 131.25 2,309.14 2.,208.54 -2,399.14 940.08 5;966,231.26 563,181.95 3.:00 960.98 4,000.00 71.02 128.08 2,341.83 2,241.23 -2,459.46 1,012.83 5,966,171.56 563,255.19 3.00 1,034.25 4,100.00 71.28 124.92 2,374.t4 2,273.54 -2,515.74 1,08$.89 5,966,115.92. 563,331.71 3.00 9,110,80 4,200.00 71.59 12.1.77 2,405.9$ 2,305.38 -2,567.84 1,16$.07 5,966,064.48 563,411.31 3.00 1,190.43 4,300.00 71.96 118.64 2,437.26 2,336.66 -2,615.62 1,250.15 5,966,017.38 563,493.77 3.00 1,272.92 4,329.93 72:fl8 117.70 2,446.50 2,345.90 -2,629.06 1,275.24 5,966;004.15 563,518.98 3.fl0 1,298.14 Sail ~ 72°Inc & 117.7°Azi : 4330ft MD, 2447ft ND 4,400.00 72.08 117:70 2,468.06 2,367.46 -2,660.05 1,334.27 5,965,973.65 563,578.25 0.00 1,357.43 4,SOO.W 72.08 117.70 2,498.84 2,398.24 -2,704.29 1,41.8.51 5,965,930.13 563,662.85 0.00 1,442.05 4,600.00 72..08 117.70 2,528.61 2,429:01 -2,748.52 1,502.75 5,965,886,60 563,747.44 0,00 1,526.68 4,700.00 72.08 117.70 2,560.39 2,459.79 -2,792.75 1,586.99 5,965,$43,07 563,832.04 0,00 1,611.3(? 4,800.00 72:08 117:70 2;591.16 2,490:56 -2,836.98 1,671:23 5,965,799:54 563;916:63 fl.fl0 1,695:92 4,900.00 72.08 117:70 2;621:94 2,521,34 -2;881.22 1,755.47 5;965,756:01 564;001.23 0.00 1,780.55 5,000.00 72:08 197.70 2,652.71 2,552.11 -2,925.45 1,839.71 5,965,712.48 564;085.83 0.00 1,865.17 5,100:00 72:08 197.70 2,683:49 2,582:89 -2,969.68 1,923:95 5;965;66$:96 564,170.42 0:00 1,949.79 5,200.00 72.08 117.70 2,714.26 2,613.66 -3,013.91 2,008.15 5,965,625.43 564,255.02 0.00 2,034.41 5,300.00 72.08 117.70 2,745.04 2,644.44 -3,058.15 2,092.43 5,965,581.90 564,339,61 0.00 2,118.04 5,400.00 72.08 117.70 2,775.81 2,675.21 -3,102.38 2,176.67 5,965,538.37 564,424.21 0.00 2,203.66 5,500.00 72.08 117.70 2,806.59 2,705,99 -3,146:61 2,260.91 5,865.,494.84 564,50$.80 0.00 2,2$8.28 5,600.00 72.08 917.7fl 2;837.37 2,736:77 -3,190.84 2,345.15 5,965,451.32 564;593:40 0.00 2,372.91 5,7fl0.00 72:08 117.70 2;868.14 2,767:54 -3,235.08 2,429.39 5,965,407.79 564,678:00 fl:Ofl 2,457.53 5,800.00 72:08 117.70 2;898.92 2,798.32 -3.,279.31 2,513.63 5,965,364.26 564,762:59 O.Ofl 2,542.15 5,900.00 72.08 117.70 2,929.69 2,829.09 -3,323.54 2,597.87 5,965,320.73 564,847.19 0:00 2,626.77 6,000.00 72.08 117.70 2,960.47 2,859.87 -3,367.77 2,682.11 5,965,277.20 564,931.78 0.00 2,711.40 6,100.00 72.08 117.70 2,991.24 2,890.64 -3,412.01 2,766.35 5,965,233.67 565;016.38 0.00 2,796.02 6,200.00 72.08 117.70 3,022:02 2,921.42 -3,456.24 2,850.59 5,965,190.15 565,100.98 0.00 2,880.64 6,300.00 72.08 117.70 3;052.79 2,952,19 -3,500.47 2,934.83 5,965,146.62 565,185:57 0.00 2,965.27 6,400.00 72:08 117.70 3,083:57 2,982:97 -3,544.70 3;019:07 5;965,103.09 565,270.17 0.00 3,049.89 6,SOfl:00 72:08 117:70 3,114.34 3;013.74 -3,588.93 3,103.31 5,965,059.56 565,354.76 0.00 3,134.51 6,600.E 72A8 117.70 3,145.12 3,044.52 -3,633.17 3,187.55 5,965,416.03 565,439.36 0.00 3,219.13 6,700.00 72.08 117.70 3,175.89 3,075.29 -3,677.40 3,271.79 5,964,972.50 565,523.95 0.00 3,303.76 6,800.00 72.08 117.70 3,206.67 3,106.07 -3,721.63 3,356.03 5,964,928.98 565,608.55 0.00 3,388.38 6,897.27 72.08 117.70 3,236.60 3,136.00 -3,764,66 3,437.97 5,964,886.64 565,690.83 0.00 3,470.69 Top Ugnu G 6,900.00 72.08 11.7.70 3,237.44 3,136.84 -3,765.86 3,440.27 5,964,885.45 565,693.15 0.00 3,473.00 7,000.00 72.08 117.70 3,268.22 3,167.62 -3,810.10 3,524.51 5,964,841.92 565,777.74 0.00 3,557.63 7,100.00 72.08 117.70 3,298.99 3,198.39 -3,854.33 3,608.75 5,964,798.39 565,862.34 0.00 3,642.25 7,200.00 72.08 117.70 3,329.77 3,229.17 -3,$98.56 3,692.99 5,964,754.86 565,946.93 0.00 3,726.87 7,300: 72:08 117.70 3,360.54 3,259:94 -3,942.79 3;777.23 5,964;711.34 566,031:53 0.00 3,811.49 7,400.:00 72.08 117.70 3,391.32 3,290.72 -3,987:03 3;861.47 5,964,667.81 566,116 93 0..00 3,896.12 7,500.00 72:08 117.70 3;422:09 3,321.49 -4,031.26 3;945.71 5;964;624.28 566.,200.72 0.:00 3,880.74 7;600:00 72:08 117.70 3,452:87 3,352.27 -4,075.49 4;029:95 5,964,580.75 566,285.32 0.00 4,065:36 712012005 12:13.25PM Page 5 of 10 ORIGINAL COMPASS 20(13. i1 Build 48 ~ ~-~' ~ Hai iiburton Company s~-~ tt~ua ~TC~nr ConcxoP'hi~ti~ps Alaska.. ~,~~n;l,~ ~,r~~ _ ~~~~~~;,~~ . _ ___ nr ___ _ ----__ . seroioies Database: EDM 2003.11 Single User Db local Co-ordinate Reference: Well Pian. 1C-20 Company: Con oco Phillips Al aska (Kupaestk) Nd Reference: Doyon 15 RKB ~ 100.60ft ((40+60.6}) Project: Kup aruk River Unit Md Reference; Doyon 15 RKB @ 100.60ft ((40+-60.6}} Site: Kup aruk 1C Pad No rth Reference: True Well: Plan: 1 C-20 Survey Cafculatian INethad: Minimum Curvature Weittwre: 1C- 20 Perrnit Plan Design: 1C-20 (wp09} Planned Survey 1 C-20 (wp09) _ _.- -- Map Map Md inclination ALimuth TYd SSTVd +N/S +FJ-W Northing Fasting dt_SEV Pert Section {ft} {°} (°) (ft} (ft} (ft) (ft} ~~? (ft} (°MOOftj (ft} j 7,700.00 72:08 117.70 3,483.64 3,383A4 -4,119.72 4,114.19 5,964,537.22 566,369.:91 0:00 4,149.98 7,800.00 72.08 117.70 3,514.42 3,413.82 -4,163.96 4,198.43 5,964,493.69 566,4S4.S1 0.00 4,234.61 7,900.00 72.08 117.70 3,545.19 3,444.59 X1,208.19 4,282.67 5;964,450.17 566,539..10 0.00 4,319.23 8,000.00 72.08 117.70 3,575.97 3,475.37 -4,252.42 4,366.91 5,964,406.64 566;623.70 0..6M) 4,403.85 8,100.00 72.0$ 117.70 3,606.74 3,546.14 -4,296.65 4,451.15 5,964,363.11 566,70$.~l 0.(?0 4,488.48 8,200.00 72.08 117.70 3,637..52 3,536.:92 -4,340.89 4,535.39 5,964;319.58 566;792.89 0.00 4,573.10 8,300.00 72:08 117.70 3,668.29 3;567.69 -4,385.12 4,619.63 5,964,276:05 566,877.49 0.00 4,657.72 8,400.00 72.08 117.70 3,699:07 3,598.47 -4,429.35 4,703.87 5,964,232:53 566,962.08 0:00 4,742.34 8,500.00 72.08 117:70 3,729.84 3,629,24 -4,473.58 4,788.11 5,964,189.00 567,046.68 0.00 4,826.97 8,600.E 72.08 117.70 3,760.62 3,660.02 -4,517.82 4,872.35 5,964,145.47 567,131.28 0.00 4,9t 1.59 8,700.00 72.08 117.70 3,791.39 3,690:79 -4,562.05 4,956.59 5,964,101.94 567,215.87 0.00 4,9.21 8,800.00 72.08 117.70 3,822.17 3,721.57 -4,606.28 5,040.83 5,964,058.41 567,300.47 0,00 5,080.84 8,900:00 72:08 197.70 3,852:94 3,752.34 -4;650.51 5,125:07 5;964;014.88 567,385:06 0.00 5,165.46 9;000:00 72.:08 117.70 3;883.72 3,783.12 -4,694.75 5;209.31 5,963,971:36 567;469:66 0.00 5,250.08 9,035.36 72..08 117.70 3,894.60 3,794.E -4,710.39 5,239.10 5,963,955:96 567,499:57 0.00 5,280:00 ~ Top West Sak D 9,100.1%1 72..08 117.70 3,914.:49 3;813:$9 -4,738.88 5,293.:55 5,963;927:83 567;554..25 0..00 5,334.70 9,200.00 72.08 117:70 3;945.27 3;844:67 -4,783.21 5,377.79 5;963;884.30 567.;638.85 0.00 5,419.33 ~ 9,30fl:00 72.08 117.70 3,976:04 3,875.44 -4,827.44 5,462.03 5,963;840.77 567;723.45 0.00 5,503.95 9,400.00 72..{)8 117:70 4,006:82 3,906.22 -4;871.67 5,546.27 5,963,797.24 587,808.04 0.00 5,588.57 9,500.00 72.08 117.70 4,037.59 3,936.99 -4,915.91 5,630.51 5,963,753.71 567,892.64 0.00 5,673.20 9,600.00 72.08 117.70 4,068.37 3,967.77 -4,960.14 5,714.75 5,963,710.19 567,977.23 Q.00 5,757.82 9,700.Q0 72.08 117.70 4,099.14 3,998.54 -5,004.37 5,798.99 5,963,666.66 568,06.1.83 0.00 5,842.44 9,800,00 72.08 117,70 4,129.92 4,029.32 -5,04$.60 5,883.23 5,963,623,13 568,146,43 0.00 5,927.06 9,900.00 72.08 117.70 4,160:69 4,060:09 -5;092.84 5,967.47 5,963,579:60 568,231:02 0.00 6,011.69 10,000.00 72:08 117:70 4191.47 4,090.87 -5,137:07 6,051.71 5,963,536:07 568,315.62 0:00 6,096.31 10,100:00 72.08 117.70 4,222.24 4,121.64 -5,1$1.30 6,135:95 5,963,492.55 568,400:21 0.00 6,180.93 10,200.00 72A8 117,70 4,253.02 4,152.42 -5,225.53 6,22Q19 5,963,449.02 568,484.81 0.00 6,265.56 10,300.00 72.08 117.70 4,283.79 4,183.19 -5,269.77 6,304.43 5,963,405.49 568,569.40 0.00 6,350,18 10,400.00 72.08 117,70 4,314.57 4,213.97 -5,314.00 6,388.67 5,963,361.96 568,654.00 0.06 6,434.80 10,500.00 72.68 117.70 4,345.34 4,244.74 -5,358.23 6,472.91 5,963,318.43 56$,738.60 O.f~l 6,519.42 10,559.32 72.:08 117.70 4,363..60 4,263.!x1 -5,384..47 6,522.88 5.;963,292.:61 568,788.78 fl00 6,569.62 Base West Sak I 10,600.00 72.08 117.70 4,376.12 4,275.52 -5,402.46 6,557.15 5,963,274.90 568,823.19 0.00 6,604.05 10,700.00 72.08 117.70 4,406.89 4,306.29 1x,446.70 6,641.39 5,963,231.38 568,907.79 0.00 6,688.67 10,800.00 72.0$ 117.70 4,437.67 4,337.07 -5,490.93 6,725.63 5,963,187:85 568,992.38 0.00 6;773.29 10,900.00 72.08 117.70 4,46$.45 4,367.85 -5,535.16 6,809.87 5,€3,144.32 569,076.98 0.00 6,857.92 11;000.00 72.08 117:70 4,499.22 4,398:62 -5;579.39 6,894.11 5;963,100:79 569;161:58 fl:00 6,942.54 11,100.:00 72:08 117.70 4;530:00 4,429.40 -5;623:63 6,978.35 5;963.;057.26 569,246.17 0.00 7,027..16 11,200:00 72:08 117.70 4,560.77 4,460.17 -5,667.86 7,062.59 5,963,013.74 569,33fl.77 0.:00 7,111.78 11,209:19 72.08 117.70 4,563:60 4,463:00 -5;671.92 7,070.33 5;963,009.73 569,338.54 0.00 7,119.56 10 314" CSG - 2011ft FNL 8, 4934ft FEL -Sec 18 - T11 N - R11 E, 11209fY fdD, 4564ft Nd 11,3.00 72..08 117.70 4,591:55 4,490,95 -5,712.69 7,146:83 5,962,970.21 569,415.36 0.:00 7,996.41 11,400.:00 72:08 117.70 4;622.:32 4;521.72 -5,756.32 7,231:07 5;962;926:68 569,499.:96 OAO 7,281.03 11,500:00 72.08 117.70 4;653.10 4,552.50 -S,$00.56 7,315.31 5,962,883.15 569;584.56 0.00 7,365:65 11,600.00 72:08 117:70 4,683.87 4;583.27 -5;844.79 7,399:55 5;962;839,62 569;669.15 0.00 7,450.28 11,700.00 72.08 117.70 4,714.65 4,614.05 -5,889,02 7,483.79 5,962,796.k?.9 569,753.75 0.00 7,534.E 11,800.00 72.08 117.70 4.,745,42 4,644.82 -5,933.25 7,568.03 5,962,752.57 569,838,34 0.00 7,619.52. 11,90.00 72.08 117.70 4,776.20 4,675.60 -5,977,49 7,652.27 5,962,709.04 569,922.94 0.00 7,704.14 7/20/2005 12, 13:25PM Page 6 of fA COA9PASS 2003. i1 &uild 48 ORIGINAL ~ Ct3~'tlf~i S Of'1t3 p Alaska Database: EDM 2003:11 Single User Db Company: C:onocoF'hillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 C Pad We{l: Ptan:1C-20 Wellbore: 1C- 20 Permit PEan Design: 1C-20 (wp09i Planned Survey 1C-20 (wp09} Halliburton Company P4arning Report - ~eograp5ic local Co-ordinate Reference: TVD Reference: l49D Reference: North Reference: Survey Ca~ulatien Method: Sperry DrNti+y~ Services Well Plan: 1C-20 Doycn 1~ RKB @ 100.60ft ((40+60.6)) Doyon 15 RKB ~ 100.60ft ((40#60.6)) True AAinimum Curvature Idlap Map MD lnctination Azimuth TVD SSTVD +Nt-S +E/-YV tdorthins} Fasting DlSt='1f Vert Section ' '~ fft1 f°? (°? j8~ (0) (01 f~3 jg) ~~~ ('HtKlft} ttt) I 12,000.00 72..08 117.70 4;806.97 4,706..37 -6,021.72 7,736.51 5,962,665.51 570,007..53 0:00 7,788.77 42,100.00 72.08 117.70 4,837.75 4,737.15 -6,065.95 7,820.75 5,962,621.98 570,492.13 4.00 7,873.39 12,200.00 72.08 117.70 4,868.52 4,767.92 -6,110.18 7,904.99 5,962,578.45 574,176..73 4.00 7,958.41 12,3(k1.04 72.08 117.70 4,899.30 4,798.70 -6,154.41 7,989.23 5,2,534.92 570,261.32 0.(?0 8,042.64 12,400.00 72.08 117.70 4,934.07 4,829.47 -6,198.65 8,473.47 5,2,491.40 574,345.92 0.00 8,127.26 12,500.00 72..08 117:70 4,960:85 4;860.25 -6,242:88 8,157.71 5;962,447:87 570,430.51 0.00 8,211.88 12,600.00 72.08 117.70 4;991.62 4,891:02 -6,287.11 8,241:95 5,962,404.34 57fl,515.11 0.00 8,296.50 12,700.00 72..08 117.70 5,022.40 4,921:80 -6,331.34 8,326.19 5,962,360.$1 570;599.71 0.00 8,381.13 12,800.00 72.08 117.70 5,453.17 4,952.57 -6,375.58 8,410.43 5,962,317.2$ 570,6$4.30 4.00 8,465.75 12,900.00 72.08 117.70 5,083.95 4,883.35 -6,419.81 8,494.67 5,962,273.76 570,768.90 0.00 8,554}.37 13,000.40 72.08 117.74 5,114.72 5,014.12 -6,464.04 8,578.91 5,962,230:23 570,853.49 0.00 8,635.Q0 13,100.00 72.08 117.70 5,145.50 5,044.90 x,508.27 8,663.15 5,962,186.70 570,938.09 O.QO 8,719.62 13,200.fl0 72..08 117.70 5,176:27 5,075.67 -6;552.51 8,747.39 5;962,143.17 571;022.:68 0.00 8,804.24 ~ 13,300.00 72:08 117.70 5,207:05 5,106:45 -6,596:74 8,831.63 5,962;099.64 571,107.28 0.00 8,888.86 13,400:00 72.08 197.70 5,237.82 5,137.22 -6,640.97 8,915.87 5,962,056.11 571,191.88 OAO 8,973.49 13,500.00 72:08 197.7fl 5;268:60 5,168:4H) -6,685.20 9;000.11 5;962;012.59 571,276.47 0.00 9,058.11 13,600.00 72.08 117.70 5,299.37 5,198.77 -6,729.44 9,()84.35 5,1,969.06 571,361.07 4.Q0 9,142.73 13,700.00 72.48 117.70 5,330.15 5,229.55 -6,773.67 9,168.59 5,961,925.53 571,445.0 O.t}Q 9,227.36 13,800.00 72.08 117.70 5,360,92 5,260.32 -6,817.90 9,252,83 5,969,882.E 571,530.26 0.00 9,311.98 13,900.00 72..08 117.70 5,391.70 5.,299.10 -6,862.13 9,337.07 5,961.;838:47 571.;614..86 0.00 8,396.60 14,000.flO 72.08 117:70 5,422.47 5,321:87 -6,906.37 9,421.31 5,961,794:95 579;699.:45 0..00 9,481.22 14,1{x.00 72.08 117.70 5,453.25 5,352.65 -6,950.60 9,505.55 5,961;751.42 571,784.05 0:00 9,565.85 14,200.00 72:08 197.70 5;484.02 5,383:42 -6,994.83 9,589.79 5;961,707.$9 571,868.54 0.00 9,650.47 14,300.00 72.08 117.70 5,514.$0 5,414.20 -7,039.06 9,674.43 5,961,664.36 571,953.24 O.Q4 9,735.09 14,400.00 72.08 117.70 5,545.57 5,444.97 -7,083.30 9,75$.27 5,961,620,83 572,037.83 0.00 9,819.72 14,500.00 72.08 117.70 5,576.35 5,475.75 -7,t27.53 9,842.51 5,961,577.30 572,122.43 4.00 9,904.34 14,600.00 72.08 117.70 5,647.12 5,506.52 -7,171.76 9,926.75 5,961,533.78 572,247.03 0.00 3,988.96 14,700.00 72.0$ 117.74 5;637,90 5,537.30 -7;215.99 10,010.99 5,961;490.25 572,291.62 0..00 10,073.58 14,8fl0.00 72:08 117.70 5,668.67 5;568:07 -7,260.22 10,fl95.23 5;961,446.72 572,376.22 0.00 10,158.21 14,900.00 72..08 917.70 5;699.45 5,598.85 -7,304.46 10,179.47 5,961,403.19 572,460:81 0.04 14,242.83 15,000.00 72.08 117.70 5,730.22 5,629.62 -7,348.69 10,263.72 5,961,353.66 572,545.41. 0.00 10,327.45 15,100.00 72.08 117.70 5,761.00 5,660.40 -7,392.92 10,347.96 5,961,316.13 572,630.01 0.00 14,412.08 15,204.04 72.08 117.74 5,791.77 5,691.17 -7,437.15 10,432.20 5,961,272.61 572,714.60 0.00 10,496.70 15,300.00 72.08 117.70 5,822.55 5,721.95 -7,481.39 10,516,44 5,961,229.08 572,799.20 0.00 10,581.32 15,400.40 72:08 117.70 5,853.32 5,752:72 -7;525.62 10,604.68 5;961,185:55 572;883.79 0.00 10,665.94 15,500.:00 72:48 117.70 5;884.10 5,783.50 -7;569:$5 10,684.92 5,961,142:02 572,968.39 0..00 90,750.57 15,600:00 72.08 117.70 5;914.87 5;814.27 -7,614:08 10,769..16 5;961,098.49 573;052.98 0.00 10,835:19 15,700.00 72:08 117.70 5,945:65 5,845:05 -7;65$.32 10,853:40 5,961,054.97 573,137.58 0.00 90,919.81 15,800.00 72.08 117.70 5,976.42 5,875.82 -7,702.55 10,937.64 5,961,011.44 573,222.18 4.00 11,004.44 15,900.00 72.08 117.70 6,047.20 5,906.60 -7,746.78 11,Q21.88 5,960,967.91 573,346.77 4.00 11,089.4fi 16,000.40 72.08 117.70 6,437.98 5,937.38 -7,791.01 11,106.12 5,960,924.38 573,391.37 0.04 11,173.68 16,100 A0 72.08 117.70 5;068.75 5,968.15 -7,$35.25 11,190.36 5.,960,880.85 573,475..96 0.00 11,258.30 16,200:00 72.08 117.70 6;099:53 5,998.93 -7,879.48 11.,274.:60 5,960,837.32 573;560.56 0.00 11,342:93 1fi,300.00 72:08 197.70 &,130.30 6,029:70 -7,923.71 11,358:84 5,960,793.80 573;645.15 0;00 11,427.55 16,378:96 72.:08 117.70 6,154:60 6;054:00 -7,958:64 11,425.35 5,964,759.43 573,719:95 0:00 11,494.37 { Top HRZ 16,400:00 72.:08 197.74 6,161:08 6;060:48 -7,967.94 11,443:08 5,964,750.27 573,729.75 0.00 11,512.17 16,500:00 72.08 117.70 6,191.85 6;091.25 -8.,012..18 11,527.32 5,960,706.74 573;814.:35 0..00 11,596.80 16;600:00 72 A$ 117.70 6;222.63 6,122.03 -$,056.41 11,611.56 5;960,663.21 573,$9$.94 0.04 11,681..42 16,700:00 72:08 197.70 6,253.40 6,152:80 -8,1.64 13,695:80 5,0,619:6$ 573;983:54 0..00 91,766:04 7t2(tl2t)()S 72: f3:25P+V+ Page 7 of i0 Ct?MPASS ZDt)3. i i Build 48 ORIGINAL • an Halliburton Com ~ - y p ~,~~~.~~~~~ ~~,1 AI'~OCC3~'1~~~1~15 Planning Repots -Geographic - -_--- - --- -- °ril~ i 9t alaska erv aes Spsrry ng Database: EDM 2D03.11 Single User Db Local Co-ordinate Reference: Well Plans 1C-20 Company: ConocoPhitlips Alaska (Kuparuk) TVD Reference: Doyon 15 RKB @ 100.60ft ((40+60.6)} Project: Kuparuk River Unit MD Reference: Dayan 15 RKB @ 100.60ft ((40+50.5)} Site: Kuparuk 1C Pad North Reference: True Wetl: Plan: iC-20 Survey Calculation AAetttod: Minimum Curvature Wetibore: 1C- 20 Permit Plan Design: 1C-20 (wp09) Planned Survey 1 C-20 (wp09} - --- __ -- _ - -- - - ~ ~I Map Map MD tnclinatian Azimuth ND SSTVD +tVJS +E!-W Northing Fasting DLSEV Vert Section I (ft) (°) (°) (ft} Eft) (ft} (ft} (ft) (ft) (°h904ft} (ft} 16,$00.00 72.08 117..70 6;284.18 6,183.58 -8,144.87 11,780.04 5,960,576.16 574,068.13 0.00 11,850.66 16,900.00 72.08 117.70 6,314.95 6,214.35 -8,189.11 11,864.2$ 5,960,532.63 574,152.73 0.00 11,935.29 17,000.00 7208 117.70 6,345.73 6,245.13 -8,233.34 11,948.52 5,960,48$.10 574,237.33 0.(ftY 12,019.91 t7,035.3t 72.08 117.70 6,356.59 6,255.99 -8,248.96 11,97827 5,960,473.73 574,267.2Q 0.~ 12,049.79 k Build & -ru m @ 3l100ft , 1?035ft MD, 6357ft ND fl 17,068.21 72.50 f 16.77 6,366.60 6,266.00 -8,263.30 12,006.12 5,0,459.62 574,295.17 3.00 I 12,077.78 Base tiRZ ti 17,100.:00 72..92 115.87 6,376:05 6,275:45 -8,276..76 12;033.33 5,960,446.39 574,322.49 2.99 12,105.10 17,200:00 74.25 113.07 6.,404.32 6,303.72 -8,316:47 12,120.63 5;960,407.40 574.;410.11 3A0 12,192.75 17,300:00 75:62 110.30 6,430,31 6,329.71 -8,352.14 12,210.35 5;960,372.48 574,500.12 3..00 12,2$2.77 17,389.50 76.87 107.86 6,451.60 6,351:00 -8,380:55 12,292.51 5,960,344.76 574,582.49 3:00 12,365.17 K1 17,400:00 77:02 107:57 6,453.97 6,353.37 -8,383.66 12,302..25 5,960,341.73 574,592..26 2.98 12,374.94 17,500.00 78.44 104.87 6,475.22 6,374:62 -8,410.95 12,396:06 5;960,315.22 574;686.29 3.fl0 12,468.99 17,600.fl0 79.90 102.20 6,494:01 6,393.41 -8,433.92 12,491.55 5;960,293:04 574,781,95 3.:00 12,564.67 17,700:Ofl $1.37 99.55 6;510.29 6,409:69 -8,452.53 12;588.43 5,960.,275:24 574;878.97 3.00 12,661.71 17,788.79 82.69 97.21 6,522.60 fi,422.00 -8,465.35 12,675.42 5,960,263.15 574,966.06 3.00 12,748.81 D-Shale 17,800:00 82.88 96.92 6,524:01 6;423.41 -8,466.71 12;686.45 5;960,261.87 574,977.90 2.98 12,759.85 97,900.:00 84.37 94.31 6,535.13 6;434..53 -8;476.43 12,785.34 5;960.,252.97 575,076:06 3.00 12,858.$3 17,926.09 84.76 93.63 6.,537.60 6,437.00 -$,478.23 12,$11.25 5,960,251.39 575,101:98 3.01 12;884.75 C4 17,976.09 85.52 92.33 6.,541.83 6,441.23 -8,480.83 12,861.01 5,~i0,249.21 575,151.75 3.00 12,934.52 7 518" CSG - 452ft FSL & 1437ft F EL -Sec 17 - T11 N - T11 E, 1797tift MD, 6642ft ND ~ 18,000.00 85.89 91.72 6,543.62 6,443.02 -8,481.67 12,884.83 5,960,24$.56 575,175.58 2.99 12,958.36 18,045.62 86.58 90.53 6,546.62 6,446.02 -8,482.56 12,930.34 5,960,248.05 575,221.E 3.00 13,003.88 Sail @ 86.58°tnc 8 90 .53°Azi : 18046ft MD, 6547 ft TVD 18,095.62 86.58 90.53 6,549:60 6,449:00 -$,483.02 12,980.25 5,960,248.00 575,271.00 0.00 13,053.79 1C-20 Heel (wp09} - t C-20 DD Pol y (wp09} 18,100.00 86.58 90.53 6,549.86 6,449.26 -8,483.06 12,984.63 5,960,248.00 575,275.37 0.00 13,058.16 f 1$,200.00 86.58 90.53 6,555.82 6,455.22 -8,483.99 13,084.44 5,960,247.90 575,375.18 0.00 13,157.98 18,300.00 86.58 90.53 6,561.7$ 6,461.48 -8,4$4.92 13,184.26 5,960,247.$0 575,475:00 0.00 13,257.80 18,400.00 86.58 90.53 6,567.74 6,467.14 -8,485.85 13,284.08 5,960,247.70 575,574.81 0.00 13,357.63 18;500:00 86:58 90:53 6;573.71 6,473.11 -8,486..77 13,383:90 5;960,247.60 575;674:62 O.fl0 13,457.45 18;565:00 86.58 90..53 6,577.58 6;476.98 -8,487.38 13;448.78 5,960,247.53 575,739.50 0:00 13;522.33 Continue GeoSteering INZONE : 18565ft MD, 6578ft ND 18,565.34 86.58 90.53 6,577.60 6,477.00 -8,487.38 13,449.12 5,960,247.53 575,739.$4 0.00 13,522.67 1C-20 Ti (wp09} 18,600.00 87.62 90..53 6,579.35 6,478.75 -8,487.70 13.,483.73 5;960,247:50 575,774.45 2.99 13,557.29 18,700.00 90.62 90.53 6,580.88 6,480.28 -8,488:63 13;583.70 5.;960,247.40 575,874.42 3.00 13,657.26 18,745.84 92,00 90.53 6;579.84 6,479..24 -8,489:06 13,629.53 5,960,247.35 575;920.24 3:00 13,703.09 18,800.00 92.00 90.53 6,577..95 6,477.35 -8,489:56 13,683.65 5,960,247.30 575,974.36 0:00 13,757.22 18,900.00 92.00 90.53 6,574.46 6,473.86 -8,490.49 13,783.59 5,960,247.20 576,074.29 o.oa 13,$57.16 19,000.00 92.00 90.53 6,570.98 6,470.38 -8,491.42 13,883.52 5,960,247.10 576,174.22 O.QO 13,957.10 7!20!2005 12: 13:26PM Page 8 of 10 COMPASS 2003.11 Build 48 ORIGINAL ~ ~ ~' Haliiburton Company ~~~~~~~~-~ f t~~)11000~~1[~1p5 Alaska Planning Re;7orf - GeagraphiC -- -------- _ __-_ ~- ~~~ Database: EDM 2003.11 Single User Db Local Co-ardinatE Reference: Well Plan: 1C-20 Company. ConoroPhittips Alaska (Kuparuk) T\fD Reference: Uoycn 1S RKB ~ 100.60fE ((40+60.6}) Project: Kuparuk River Unit MD Reference: Doyon t5 RKB ~ 100.6EKt ((40+60.6)} Site: Kuparuk 1 C Pad North Reference: True Well: Plan: 1C-20 Survey Calculation Method: Minimum Ci.irvafure Wellbore: iC- ZO Permit Plan Design: 1C-20 (vvp09) Planned Survey 1 C-20 (wp09) Map MaP MD Inclination lkzemuth TVD SSTYD +PffS +Et-W Northirxt Fasting D~~ Uert Section j tft) f°? (°) tft? f~l trt} (~l fft? (~> (°Mao~) 4ft1 ~~ 19,096.85 92:00 90.53 6,567.60 6,467.00 -8,492.32 13,980.31 5,960,247.00 576,271.00 0.00 14,053:88 1C-20 T2 (wp09} 19,1310:00 91.99 90.52 6,567.49 6;466:89 -8,492.34 13,983.46 5,960,247.DD 576.,274.15 2.93 14,D57.04 19,120.35 99.29 90.47 6,566:92. 6,466.32 -8,492.52 14;003:80 5;960,246.99 576,29449 3.01 14,077.38 19,200.00 91:29 90.47 6,565.12 6,464.52 -8,493.18 14,0$3.43 5,960,246.99 576,374.11 0.00 14,157.01 19,300:00 91.29 90.47 6,562.86 6,462.26 -8,494.01 14,183.40 5,960,246:99 576,47408 0.00 14,256.98 19,400.00 91.29 90A7 6,560.W 6,460.00 -8,494.83 14,283.37 5,960,246.99 576,574.04 0.00 14,356.96 19,500.00 9129 90.47 6,558.35 6,457.75 -8,495.66 14,383.34 5,960,247.fMT 576,674.01 0.00 14,456.93 Possible Fault Crassi ny : i8500ft MD, S558ft TVD 19,600:00 91.29 90.47 6;556:09 6,455:49 -8;496:49 14;483.31 5;960,247:00 576;773:97 0.00 14,556.91 19;665.72 91:29 90.47 6;554.60 6,454.00 -8,497:03 14,549:01 5,960;247:00 576;839.fi7 0.00 14,622.61 1C-20 T3 (wp09) 19,700.00 90.27 90.47 6,554.13 6,453.53 -8,497.32 14,5$3.29 5,960,247.00 576,873.94 2.99 14,656.88 19,790.01 87.57 90.48 6,555.84 6,455.24 -8,498.06 14,673.27 5,960,247.(10 576,963.92 3.00 14,746.87 19,800.00 $7.57 90.48 6,556.26 6,455.66 -8,498.14 14,683.25 5,960,247.00 576,973.9(1 0.00 14,756.85 19,900.00 87.57 90.48 6,560.51 6,459.91 -8,498.97 14,783.16 5,960,247.00 577,073.80 0.310 14,856.76 20,000:00 87.57 90.48 8,564.75 6,464.15 -8,499.80 14,883.06 5;960,247:00 577,173.70 O.DD 14,956.67 20,100:00 87.57 90,48 6;569:00 6,468.40 -8,500.63 14,982.97 5;960,247:00 577;273.60 0:00 15,056.58 20,200.00 87.57 90.48 6.;573.25 6,472.65 -8,501.46 15,082..88 5,960,247.00 577,373:50 0.00 15,156.49 ~ Possible Fault Crossing : 20200ft MD, 6573ft 7VD 20,300:00 87.57 90.48 8,577:49 8,476:89 -8,502.29 15,182.78 5,960,247.OD 577,473:40 0:00 15,256.40 20,349.65 87:57 90.48 6,579.60 6,479:00 -8,502:70 15,232:38 5;960,247:00 577;523:00 0.00 15,306.00 j 1C-20 T4 (wp09) I 20,370.71 86.93 90.48 8,580.61 &,480.01 -$,502.87 15,253.42 5,960,247.00 577,544.04 3.00 15,327.04 20,400.00 86.93 90.48 6,582.18 6,481.58 -8,503.12 15,282.67 5,960,247.00 577,573.28 O.E10 15,356.29 20,500.00 86.93 90.48 6,587.53 6,488.93 -8,503.94 15,382.52 5,960,247.00 577,673.13 0.00 15,456.15 20,600.00 86.93 90.48 6,592..87 6,492.27 -8,504.77 15,482.38 5,960,247.00 577,772.98 0.00 15,556.00 2D,700:00 $6:93 90.48 8,598.22 6,497:62 -8;505:60 15;582.23 5;960,247.00 577;872..82 0.00 15,655.86 ~ 20,800:00 $6:93 90.48 fi;603:57 fi,502:97 -8;506.43 15,682.318 5;96D,247:00 577,972:67 0.00 15,755.72 20;900:00 86.93 90.48 6;608.92 6,508.32 -$,507.26 15,781.94 5,960,247:00 578;072:52 0.00 15,855.57 21;0330.:00 86..93 90.48 6.;614.27 6,513.67 -8,508.08 15,881.79 5;960,247:00 578,172.37 0.00 15,955.43 21,100.00 86.93 90,48 6,619.61 6,519.01 -8,508.91 15,981.64 5,960,247.OD 578,27221 000 16,05529 Possible F ault Crossing : 21100ft MD, 6620ft TVD 21,200D0 86.93 90..48 8.,624.96 8;524.36 -8;509.74 18;081:5D 5;960,247.00 578,372.:06 0.00 18,155.14 21;300:00 86..93 90.48 6,630.31 8,529.71 -8,510.57 16,181.35 5;960,247:00 578,471.99 0:00 16,255.00 21;400.00 86.93 90.48 6,635.66 6,535.06 -8,511:4fl 16,281.20 5,960,247,0(3 578,571.76 0.00 16,354.8fi 21,500:00 86.93 90.48 6,641.01 6;540.41 -8,512.22 16,381:06 5,960.,247;00 578.;671.60 0.00 16,454.71 21,600.00 86.93 90.48 6,646.36 6,545.76 -8,513.05 16,480..91 5,960,247.00 578,771.45 0.00 16,554.57 21,604.56 86.93 90.48 6,648.60 6,546.00 -8,513.09 16,485.46 5,960,247.00' 578,776.00 0.00 16,559.12 BHL 1C-20 (wp09} - 413ft FSL 8 2187ft FWL - Sec 16 - T1iN - R1i E, 21605ft MD, 664 7ft TVD - 41/2" - tC 20 Toe (wp0 9j 7/20f2005 12:13:25PM Page 9 of 431 COMPRSS 213313.19 Build 48 ORIGINAL ! ~ ~' Halliburton Company 1Biu~T® MFAf~ L ~Ot1t7Ct?~"11~ Planning Report -Geographic . . _ ___- --___ ~ ~ 8erv~ees Database: EDM 2003.11 Single User.Db LocafCo-ordinate Reference: Well Plan: 1C-20 Company: ConocnPhillips Alaska (Kuparuft~ TVD Reference: Doyon 15 RKB ~ 100.60fF ((4Q+60.6}) Project: Kuparuk River Unit ftAD Reference: Ooyan 15 RKB @ 100.60ft{(40+60.6}) Site: Kuparuk 1G Pad North Reference: True WeN: Plan: 1C-20 Survey Calculation Method: Minimum Curvature Welltmre: 1C- 20 Permit Pfan Design: 1 C-20 (wp09) C3eologic Targets 1 C- 20 Permit Ptan i _- - -- - _ - - ~ ~i TtfD TargFY Narne +N{-S +E! W Northing Fasting (ft) I - shape ft fE eft} (ft) I 6,577.60 '" T? %w{; "ui: -$,487.38 13,449.12 5,960,247.53 575,739.84 - Point 6,567.60 ~ C -2r' i t f ~'.`;~G3 ` -8,492.32 13,980.31 5,960;247.00 576,271.00 -Point t 6,549.60 ;;-["u n -e~[ iF~c>:=:3t -8,483.02 12,980.25 5,960,248.00 575,271.OD -Point 6,554.60 ~ ': -;~ n ' ? ;:,v c,9 ~'? -8,497.03 14,549.01 5.960,247.(10 576,839.67 - Point 6;579.60 ~-24 ~~ (wl~~}~ -8,502.70 15,232.38 5,960,247.00 577,523.00 - Point 6,646.6(1 ~ .,,,~ ~ ?,.--:~u!" -8,513-09 16,485.46 5,96(?,247.00 578,776.00 - Point 6;549.60 2". O^v P~ ; ,~ -8,483.02 12,980.25 5,960,248.00 575,271.00 ~ -Polygon ~ Point 1 -100.00 100.00 5,960,347.99 575,171.01 Point 2 -100.00 -100.00 5,960,148.01 575,171.01 Point 3 3,505.25 -103.77 5,960,147.00 578,776.00 Point 4 3,505.41 96.25 5,960,347.00 578,776.00 Prognosed Casing Points -- Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft} {ft} (") (") 11,209..19 4,563.60 10-3;4 13-1 t2 17,976.09 6,541.83 7-518 9-718 21,604.55 6,646.60 4-1/2 6-314 Prognosed Formation Intersection Roirrts !~ Measured Vertical Depth inclination Azimuth Depot +N!-E +E!-W {ff} (~ (°) jft) Eft? (ft) 2,334.60 72.04 165.00 1,806.60 -1,096.57 293.82 6,897-27 72.08 117.70 3,236.60 -3,764.66 3,437.97 9,035.36 72.08 117.74 3,894.60 -4,710.39 5,239.10 10,559.32 72.08 117.70 4,363.60 -5,384.47 6,522.88 16,378.96 72.08 117.70 6,154.60 -7,958.64 11,425.35 17,068.21 72.50 116.77 6,366.60 -8,263.30 12,006.12 17,389.50 76.87 107.86 6,451.60 -8,380.55 12,292.51 17,788.79 82.69 97.21 6,522.60 -8,465.35 12,675.42 17,926.09 84.76 93.63 6,537.60 -8,478.23 12,811.25 -- - _ _t ~I Name Base of Permafros4 Top Ugnu C Top West Sak D Base West Sak Top HRZ Base HRZ K1 DShale G4 7120120t~5 92:13:25PM Page 70 of t0 COA9P,4SS 213D3. i? BuiJd 48 ~~~~~~w • ConocoPhillips Alaska GonocaPhillips Alaska (Kuparuk~ Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-20 1 C- 20 Permit Plan Antcatlis~an Summary zo .~u~y, ZoaS C Spey t~~i11~~$ a~'Vr[~es ORIGINAL ~-' ~ • Haiiiburton Company ~ ~~~~~~~.~. CAC1000tP~IlI~pS ~ntiLof!isior. Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1C Pacf Site Error O.OOft Reference Well: Plan: 1C-2C Weft ErFOr: O.OOft Reference 1Nellbore 1 C- 20 Permit Plan Reference Design: I G-20 (wp09) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are of Database: Offset TVD Reference: WeII Plan: 1C-20 Doyon 15 RtCB @ i00.60ft ((40+60.6)) Doyon 15 RKB ~ 100.6(3f! ((40+60.6)) True Minimum Curvature 2.58 sigma EDM 2003.11 S~ngie User ~b Offsat Datum Reference 1 C-ZO (wp09) Fiker type: NQ GLOBAL.. FILTER: Using user defined selection & fi{tering criteria Interpolation Method: MD lnterva125.00ft Enrar Model: ISCIlV°SA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximumcenter-center distance of 1,338.24ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.{30 Sigma Survey Toot Program Date From Ta (ft) (ft) Survey (YJellbore) Tool Name Description 40.00 800.00 1C-20 (wp09) (1C- 20 Permit Ptan) CB-GYRf~-SS Camera based gyro single shot { 800.00-21,604°56 1C-20 (vep09) (1C- 24 Perrrut Plan) MWD+IFR-AK-CAZ-SC MWD+IFRAYC CAZ SCC Summary j Reference Offset Centre to No-Go AlEowabfe f IJleasured Measured Centre Distance Deviation yyarr~ing Site Name Depth Depth Distance (ft) from Plan i Offset Wetl - Weilbore -Design (ft) (ft) (ft) (ft) Kuparuk 1C Pad 1C-01 - 1C-01 - 1C-01 999.88 975:00 118:01 18:09 99.92 Pass -Major Risk iC-02 - 1G-02 - tC-02 734.07 725.00 38.97 14.26 24.71 Pass -Major Risk 1C-03 - 1C-03 - 1G-03 355.26 350.00 61,01 6.80 54.21 Pass - Major RLsk 1C-04 -1C-04 - 1C-04 352.65 350.00 188.91 6.26 182.65 Pass -Major Rik 1C-12 - 1C-12 - 1C-12 15,631.42 16,100.00 885.19 850.62 34.57 Pass -Major Risk 1C-133 -1C-133 -1C-133 548.22 550.00 228..45 9.35 219.09 Pass -Major Rik 1C-135 - 1G135 - 1C-135 185.09 175.00 213.79 3.30 210.49 Pass -Major Rik 1C-135 - 1C-935PBt - 1C-935PB1 185:09 175.00 213.79 3.35 210.44 Pass -Major Risk 1C-14 - 1C-14 - 1C-14 442.82 450A0 84.38 8.21 76.17 Pass -Major Risk 1 C-15 - 1 C-15 - 1C-15 425.14 425.00 3129 7.67 23,62 Pass -Major Risk 1C-15 -1G15L1 - 1C-15L1 424.94 425.00 31.29 7.66 23.62 Pass -Major Risk 1 C-172 - 1 C-172 - 1C-172 312.07 300.00 217.07 5.92 211.15 Pass -Major Risk 1 C-174 - 1 G174 -1C-174 263.38 250.00 180.73 4.75 175.98 Pass -Major Rsk 1C-178 - 1 C-178 - 1C-178 33620 325.00 116.08 6.11 109.96 Pass - Mater Rik 1C-178 - tC-178L9 -1 C-978L1 336.20 325.00 116:08 6.11 109.:96 Pass -Major Risk 1G178-1C-178L1PB9-1C-178L1PB1 336.20 325.00 116:08 6.11 109:96 Pass-Major Risk 1C-178 - 9 C-178L1 P62 - 1C-178L1 PB2 336:20 325.00 116.fl8 6.11 1(19.96 Pass -Major Risk 1C-184 - 1 C-184 - 1G184 412.03 400:00 93.16 7.54 85:62 Pass -Major Risk 1 C-19 - 1 C-19 - 1 C-19 616.58 600.00 139.92 10.82 129.10 Pass -Major Risk 1C-190 - 1C-190 - 1C-19D 238.59 225.00 181.24 4.32 176.91 Pass -Major Risk 1C-21 -1C-21 - 1C-21 373.01 375.00 26.62 6.94 19.72 Pass -Major Rrsk 1C-21 -1C-21 L7 - 1G-21 L1 373.01 375.00 26.62 6.913 19.72 Pass -Major Risk 1C-21 - 1C-21L2 - 1C-21 L2 373:Ot 375.00 26:62 6.:90 19.72 Pass -Major Risk 1C-21 - 1C-21 L3 - 1C-21 L3 373:01 375:00 26:62 6.90 19.72 Pass -Major Risk 1C-22 -1C-22 -1C-22 390.85 350.00 115.42 7.12 108.30 Pass -Major Risk 1C-23 - 1C-23 - 1C-23 534.93 525.00 74.36 9.48 64.:87 Pass -Major Risk 1C-23P61 -1G23P61 -1C-23PB1 534.93 525.00 74.36 9.48 64.87 Pass -Major Risk 1C-24 -1C-24 - 1C-24 958.98 950.00 39.06 15.95 22.11 Pass -Major Risk iC-25 - 1C-25 - 1C-25 747.51 725.04 118.54 12.73 1'05.81 Pass -Major Risk 1 C-26 - 1 C-26 - 1 C-26 1,103.78 1,075.00 84.83 1.9.39 65.44 Pass -Major Risk 1 C-27 - 1 C-27 - 1 C-27 723.90 700:00 164:22 13.50 150.:72 Pass -Major Risk Plan: 1 C-28 -Plan 1C-28 (wp12) - 1 C-28 (wp12) 347.74 350.00 121:67 7:35 114.32 Pass -Major Risk Kuparuk 1 D Pad 1 D-28 - 1 D-28 - 1 D-28 ©ut off range CC -Min centre tc ceroter distance or ceverger:t point, SF - rrrin separation factor: ES -min ellipse separation 7/2DJZDDS 72~2D:16PM !'age 2 of 3 COMPASS 2DD3, i P Build 48 O W)'1L DETAIiS AN1l-COLLISION SEI'nNG4 C'069rA.W DETAa6 SUIIVEY PaoCi.Ml 'SettPnTH DDTAIts Nmc -N'-S +Ei~W' Nortluvg EWi~ I,atimmds Lonkiluds 615 Int la1- McShadhID LHerval' 23.00 CaweoPhill UF.du lm rps Fnkirsennk Depili Dip _ "`~~' T !S.a IGN Nm: IC ~20 100.82 179.17 596862207 56222_'.10 ~"l9?9.2TT 149'29'47.64641' N'A Dep[ Ra18. F5wn: 40.00 Tu- +160639 Afarvnnm Aalge: _500.00 Aefermce. PIS: PIm: 1C-20 (wp091 AI Pnc .er.5 .arw. Nr .~.o !,. t .'-:.F: :nz :: ._¢.~ Dti(eo.ba 6) Im a.... '" Cdavlwon Method: Mrurm®C4uvmmc s 1 -D" ~:6~ UNn Fmn P.;n Erar Sy : 6CW'SA Sem Method: Trrv C'ylinMr Norio ... ,, a t.' o cu .~ ua Ertar Srr6a: I.71iPeed a Caing Womvk Method 166n Bud From Colour To MD 40 250 250 500 500 750 Fran Colour To MD' 730 ---- 1000 40 i 230 1000 --- 1250 2 0 500 1250 1500 0 5 750 1500 1750 31.4 1000 1750 2000 3p.p 1230 2000 3000 IS00 (j 3000 ------ 4000 1730 117 r? r-]'"~ 4000 5000 5000 6000 25.0 2000 s - ~ ~~ ~ ~ 6000 7000 4000 ~ ~ 7000 8000 5000 15X1 331 ~~ ~ ~ ~ !~ 8000 9000 21L1 6 ~- .. i ~„~= .~°." rG~'S ~. ~ _ ~~ ~J' -~! y ~~'' i a, 9000 10000 10000 11000 000 I 00 ~7 ^ . ~f rl • s ~fG ! ~ ~'~" ~ 11000 12000 00 r w ; /"~~- k~ •- ' ` ~. !i ,..~ f 12000 .~. 13000 IS.O 0 ` _ ~ -~ ~~•~, .± .i ~i'~~ i(~ ~~ i/~wiZ.~.'. ' 13000 15000 0 ~ :~.. 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Ic-n- - 1cn1 IC-171 IC-171 lC-t?I IC-18 IC-191 ~~ IC-19 IC-ZI I C'-21 IC 11 1(.22 -• IC-Li IC-ZS I('-Z4 ~ IC,ZS I C-2b I C-2' Nm linder Azimuth (TF(1~ AZI) [ds;g] vs Centre; u3 Cen[re Separation [SOfl/inJ C Travellin - lo:za y g n..I Travelling Cylinder Aamuth (TFO*AZI) [deg vs Centre to Centre Separation [15ft'in~ Sec MD Nc Aa 'ND +N/-8 +El-W' Disk TFace VScc Tg94 1 eom 0.00 0.00 m.oo om o.SD aa0 0.00 0.00 7510.60 0.0o D.XO JQO.oo om o.a0 aao o.o0 0.00 l 67].33 lOm 165.W 67164 -28m ].31 7.00 163m 19.57 4 201173 66.W 165.00 3 218137 66.00 165,W I®1.4'1 1]32.48 52189 -460.20 32182 25'118 100 0.00 0.00 Om 3]69! 669-18 6 2714.87 :2716 165m IN166] -1096.'18 24188 1.00 Om '693] 18148) RA6 165.00 1960.68 -133676 91].00 0.00 Om 10X9.59 X 4310.38 ]1D'1 11'A 21/6.70 .2629.74 127s50 7.00 .41.66 ]9]9.94 9 1"/0!!.92 :2D'1 I17.A 10 18W3.66 86.36 90.57 6736.39 6516.62 5248.97 -8482.33 119]8.16 12410.18 0.00 7.00 Om 6/.38 1442?]8 153HI1.W Il 18095.66 86.fB 90.33 6349.60 -8487D1 12980D9 0.00 OAU 15425A0 IG20 Hed fwp09) 12 18363.38 86.38 90.53 65x1.60 -848778 11448.95 0.00 OUO 15847.00 IC~20 Tl 1wp09) 17 18743.&5 92.00 90.41 l4 19096.R9 92.00 90.51 659.84 636].60 54X9.06 $19272 136299] 13980.14 7.00 0.00 0011 0.011 16005.0 16318.24 I C-20 T2 (wp09) IS 19120.7!1 9129 90.48 6366.92 5492.57 1400763 3.00 175.26 16119.20 16 19663.]fi 9129 90.98 7 7 A 6534.60 89 6555 5441.03 549X 08 145488A 146]1 10 0.00 7 00 9fp 17998 16825'1 iC'-20'17 fwP09) 16916 39 1] 19]90.03 8 .1 90 X IB ]0349.68 81.37 90.48 . 659.60 . 5502.'x! . 15232.22 . 0.00 000 . 1773530 IC~20 T4 (wp09) 19 201A.75 8691 90.48 63X0.61 550391 1325]:26 7.00 -IA99 174541E 20 21609.59 86.91 90.48 6616.60 5313.15 16483.'9 Q00 0.00 18333.6' IC-30 Toe (wp09) • Plan: I V D Iw 1 D-1 ~ -4000 ,~-,9Q -90~ \1 -10000 p; /~ ~~ A -11000 <~ ~. -12000 ^O, -13000 ~1 A6 1D -14000 0 1000 2000 ~ Project: Kuparuk River Unit p; d : N ~ ° Slte: Kuparuk 1C Pad 20 ll Plan: 1 C W ; .~ ~ N ~ w - e : Wellbore: 1C- 20 Permit Plan Plan: 1C-20 (wp09) /~ti 1/4 Mile Radius Plan View ~ 1C-20 vs Existing Wells and Planned wells Scanned ND 6549 - 8646 Cirlcles are 1324' radius .;, . located at heel and toe of ~~~ ~ ~ " 1 ,production interval N l N1 j' ~ l ~l \ ,1 ~ N \ ~ ~~ \ ~ - ~ ColnocoPhillips ~ ~ ~ AIBSIC ~ \b\ \\ \ / N ~ ~: n w , ~! ~1 ~~/ ~~ `-~ 5000 6000 7000 8000 1C-20 Heel (wp09) 1 C-20 Tce (wp09) ro m v ^~ !, ~ ~/ ~ j Azi~uths Lb True North agnetic North: 24.65" Magnetic Field Strength: 57560.2nT Dip Angle', 80.80° Date: 12/312004 Model: BGGM2005 11000 12000 13000 14000 15000 16000 17000 18000 19000 ConocoPhillips ~I l4 ire Radius---~ -20 ~wp09} Alaska .~ - (~ V I ~?W ~^ V l ~r 1 MP 1 17-11-11, MP 1 1'-11-11 MP 1 17-~ 1-11 V1 • 0 _ r._ 2500 5000 I '~ '7500 `~ 10-2s,1o-26,10-28 va ~aooo ------y= - 0 -•- 1 M-17, 1 M-17, 1 M-17 V6 -_ / ` ~ /2500 / ,/ /SDDD ~ l 1G20 Heel (wp09) 75DD 20DOD % \ 1C-12, 1G12, 1C-12 1C-21, 1G21, 1C-21 V7 ` 1 C-20 Toe (wp09) - - - _ _ _ Plan: 1C-28, Plan 1G28 (wp12), 1C-28 (wp12) VO 1C-20 (wp09) 2~SOD ~ / / - / - ---- ~ ~ O ~ _O N cn ~ o ~ ~ ~ o N O 0 0 ~ O O O U7 O 0 O 0 ~ ~ O O O o 0 0 0 •i z 0 c~ z D r -5000 \\ ,~~~ 103/4"--------------- Closest Approach in Production Zone 1C-12 approximately 1924' @ 6549' TVD 1 C-26 approximately 3900' @ 6549' TVD 1 D-28 approximately 2775' @ 6549' TVD o~ ~ ~ 1G26 r i ~ I ', ~ a~ o ~~ ~, ~~ - ,- ~, laze -1 1-1401 0 1000 2000 3000 4000 5000 6000 7000 8000 ~ `O~j~~ 1C-12 i ~ i ~ ~ ~ ~ ~ ~~ I ~ I ~ 1 ~ ~ f ~, ~ 1 ~~~ ' r ~,, ~, 7 s/e" 1C-20 Heel (wp09) 11000 12000 13000 1 1/4 Mile Radius Plan View iC-20 vs Closest Existing j Wells Scanned ND 6549 - 6646 Cirlcles are 1320' radius located at heel and toe of production interval I C ,, ., ,. ~ 41n° Co-wcoPhillips 1 G20 Toe (wp09) Az~uths to True North agne4c North: 24.65` Magnetic Field Strength: 57560.2nT Dip Angle: 80.80' Date: 12!312004 Model: BGGM2005 15000 16000 17000 18000 19000 -~~1. KRU 1 C-20 ~ ~!, R1 QE, U.M. T11 N, R11 E, U.M. t ~ Proposed 1-Winj ~; ; \~ Kuparuk River Oil Pool ~\ I GZ, ~ 2051230 ~_, oP , ; / ~« °~~~~ =•t Confidential wells shown as red Ic o ~ • ~~1 ~ SFD 819/2005 ~ ~`, - - - ~ ~ r ~~ r / ~ C ~Z3 '_ ti t - r ~4 ~ ~~ ,..j a ,,G o _` ~ ~ $ 8 I c z ^v ^ri~ $ O O d O Ii6-'I~ 1 1tl~fn~ili ~ ~ ~ ~ O ~ IG-1 1 i,08 tG 14~ Ib- 4ril.t '~ ~ ~, ~ to of to 1107 f ~' • ~.IO oI ~ f i - _ y1 j 16 ''~`~m \ ` ~ , ' ~~-28 Slotted Liner ~,r`fi,~.'~~•~!~~.,~!/ .~',r6~o4 Ic-too Ic-I Ha ~, ~ '..1'15- 117 , ~ -, .~ S~ i;,,l t~~ ~~~~ ~~ -:~~.. - ,' ~~ i '`r, _ ~ ~' III Il i, ~ip1~,1\' ~~ 1 D- ~ y ~~ - - `ti~~. ~~ ,'IC' Ili~+ ~ ~a<nl~~ l X111 ~\~ ~~`.. ,~' • TD: 21,605' __ `~,~1 a o-z a Feet ~ 0 1 ,000 2,000 3;;00 4,000 ti RE: Proposed LWD Sonic log for CBL on 1C-20 Subject: RE: Proposed LWD Sonic log for CBL on 1C-20 From: Eric Cribbs <Eric.Cribbs@HALLIBURTON.com> Date: Mon, 08 Aug 2005 11:26:59 -0800 To: "Billingsley, Tim A" <Tim.A.Billingsley@conocophillips.com>, tom_maunder@admin. state. ak.us CC: "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com>, "McKeever, Steve" <Steve.McKeever@conocophillips.com>, "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com>, "Johnson, Vern" <Vern.Johnson@conocophillips.com> Tom, As you may know, we are running the 4 3/e" Bat Sonic LWD too{ after the upcoming 7" casing run on CD2-02 and doing a mad pass to see how the data looks on determining the cement top. The wireline bond log will be run later. This will be a very good chance to see what can be presented from our sonic tool and if it will satisfy all the needs that Tim needs on 1 C-28. We will keep you in the loop and if you require anything else, don't hesitate to give me a call. Thanks. Eric Cribbs M/LWD Service Coordinator Sperry Drilling Services Alaska Operations 6900 Arctic Blvd Anchorage, AK 99516 Office Phone: 907-273-3522 Fax: 907-273-3535 Cell: 907-748-3909 -----Original Message----- From: Billingsley, Tim A [mailto:Tim.A.Billingsley@conocophillips.com] Sent: Tuesday, August 02, 2005 5:10 PM To: tom_maunder@admin.state.ak.us Cc: Thomas, Randy L; McKeever, Steve; Reilly, Patrick J; Eric Cribbs Subject: Proposed LWD Sonic log for CBL on 1C-20 Tom Maunder, We propose to log the cement job on 1 C-20 injector with an LWD Sonic tool instead of conventional CBL or USIT log due to extreme depth and high tangent angle. I have an SPWLA paper on this subject if you would care forme to bring over a copy. Below is our draft proposal for the permit to drill package for your consideration. Thanks, Tim Billingsley 265-6531 «1 C-20 PERMIT IT Sonic for CBL.doc» see page 7, step #14 in bold. «1C-20 PERMIT IT Cover Letter Sonic CBL.DOC» «1C-20 schematic BTC liner7-20-05.vsd» «1C-20 (wp09).pdf>> directional plan 1 of 2 8/9/2005 1:43 PM a ~:~ - ,~~~ ~ ~ ~E~~fVEL~ ~~_ .~=-- ~-~ I ~,~:, AuG 0 4 Zoos ~~ ~~. ~"''~~ ~~~ SPWLA 45a`Annual Logging Sy§IJmte~9o~~0A0mtmisSion !2s ~ Anchorage ~s rkG~v" i y L ,'~Sf.C ~,~ ~ S~~;e LWD Sonic Logging in Cased Holes /' ~5"~ 1 tise~ I , ;;, J. Mazket, D.P. Schmitt, and R. Deady, Halliburton Energy Services, Houston, Texas Copyright 2004, held jointly by the Soaety of Petrophysicists and Well Log Analysts (SPWLA) and the submitting authors. This paper was prepared for presentation at the SPWLA 45'~ Annual Logging Symposium held in Noordwijk, The Netherlands, June f3-9, 2004. ABSTRACT While LWD sonic logs have been routinely used in open holes for nearly a decade, LWD sonic logging in cased holes can also provide useful information, including cement evaluation logs and formation velocities. Though it is common practice to acquire wireline sonic data through casing, it is a relatively unexplored facet of LWD sonic logging. While much of the theory is the same for both environments, there are critical differences related to the presence of the large LWD tool and the resulting small fluid annulus which modify the properties of the guided waves and multiply reflected waves. Some of the differences aze theoretically illustrated through full wave synthetic seismograms and field data examples. Well-bonded and poorly bonded situations are discussed. In the latter case, examples of a poor casing-cement bond or cement-formation bond are both investigated. Examples of compressional velocity data acquired through casing are presented along with comparisons to wireline data. Examples of qualitative cement bond logs based on the attenuation characteristics of the compressional wave train aze also presented. Finally, operational recommendations and processing techniques for casing bond logs and compressional velocities through casing are discussed and quality control displays illustrated. INTRODUCTION Sonic logging in cased holes is an established wireline service. Cased hole logging is commonly used to provide compressional wave velocities for the formation behind casing and cement evaluation logs. The sheaz, flexural, and screw wave velocities are sometimes measured also. In the well-bonded case, compressional and refracted shear logging is little affected by the presence of the casing. In the partially bonded to completely unbonded cases, the presence of the casing and the aggregate layers between casing and formation affect the ability to detect the formation arrivals as well as the character of the casing arrivals. The "interface waves" such as Stoneley, flexural, and screw modes aze affected by the presence of the casing and cement and by the quality of the bond. Cement evaluation logs can be anything from a gross indicator of top of cement to a finely resolved image of the casing itself with 3-dimensional information about the cement itself, including microannulus evaluation, channelling, and trapped gas using azimuthal receiver type data. In their more basic forms, cement evaluation logs primarily evaluate the amplitude response of the casing arrival, based upon the concept that unbonded casing will ring freely with high amplitude, while well-bonded casing will be dampened by the cement/formation and have a lower amplitude response. These technologies, while fairly commonplace in the wireline environment, have been little explored in the Logging While Drilling (LWD) environment. Whereas acoustic scanning image tools have not yet been .developed for LWD, open hole LWD sonic logging tools have been producing compressional and shear logs for nearly a decade. In many cases, these LWD sonic tools have completely replaced wireline logging runs, saving time and expense (Deady et al, 2001). There are many conditions, however, where cased hole information could be an addition to the logging programme: 1) the shallowest runs aze often not logged with a full suite of tools, leaving a gap in the sonic log. Filling this gap could improve seismic tie-ins. 2) often the operator would like to know where top of cement is located but is not willing (or is unable) to make a wireline run. LWD sonic logs can provide these services as part of a deeper open hole run or as a special cased hole trip. Since the LWD sonic tools must trip through the cased hole section in order to get to the deeper section being drilled, cased hole data aze often acquired but are lazgely disregazded. • • SPWLA 45`s Annual Logging Symposium, June 6-9, 2004 In the sections below, we will discuss the challenges of LOUD sonic logging through casing, presenting modelling and field results for a variety of formations and bonding situations. The primazy focus is on compressional and refracted sheaz logs, with a compazison of monopole, dipole, and quadrupole data type. A detailed analysis of the fundamental modes is out of the scope of this paper. Basic cement evaluation services aze discussed, presenting modelling and field results. Finally, best practice recommendations for acquiring LOUD sonic logs through casing and LOUD cement evaluation logs aze suggested. BACKGROUND Detecting the compressional velocity through the casing is dependent on several factors such as the quality of the bonds, the impedance contrast between the cement and the formation and the frequency of the signal.. First, the better the bond, the less the casing ringing will dominate the signal and interfere with the fast formation velocities. Second, if the compressional velocity is close to or slower than the cement compressional velocity, most of the acoustic energy is refracted into the formation and little is reflected back through the cement layers to the receivers. In the latter situation, cases of a poor casing-cement bond or cement-formation bond aze investigated. Finally, the frequency of the signal is important. Higher frequency signals (15+ kHz) tend to favour excitation of the relatively thin casing, particularly if it is unbonded. Well bonded casing, which responds as a system (of casing and cement), tends to ring at lower frequencies. The formation itself will generally favour lower frequencies. Most wireline and LOVD tools fire a signal with a centre frequency of -12 kHz, but some (e.g. Varsamis et al, 1999) excite amid-frequency range signal which can be advantageous in exciting formations through casing and separating the formation signal from the casing or cement signals. By firing both frequencies at each depth, the high frequency data will yield information about the casing ring (and thus the cement bond), while the lower frequency firing allows for logging the formation behind casing. Modelling the LWD cased hole environment In order to investigate the physics of LWD cased hole sonic logging, we present modelling results and comparisons with field data. In the wireline configuration, several modelling studies considered the cased hole situation, typically omitting the presence of the actual tool (e.g., Chang and Everhart (1983), Tubman et al (1984, 1986), Schmitt and Bouchon (1985), Schmitt (1993), Valero et al. (2000)). Such an assumption cannot be performed in the LOUD situation: the presence of the steel drill collar, which greatly decreases the distance from the tool to the casing and affects the behaviour of the fundamental (interface) modes, cannot be omitted. The position of the transmitters and receivers, now located on the outside of the collar, can lead to mode contamination. It is also unlikely that the tool will be centralised in the well bore, due to practical drilling constraints. In addition, it can be difficult to maintain balanced sources and receivers in the LOVD downhole environment, due to variations in pressure and temperature as well as mud/cuttings building on the tool. The transmitter-to-receiver spacing can be shorter than in wireline, making the sepazation of modes travelling at close velocities more difficult. Data acquisition also differs in that it is time-based, not depth-based (as in the wireline case), so data are sampled at irregular depth intervals. The synthetic seismograms presented throughout have been calculated using a discrete wave number method. The model consists of a vertical borehole embedded in a radially layered medium which is vertically homogeneous (Figure 1). Axisymmetry is assumed, including a centred tool with a fluid core. Anelastic attenuation is accounted for in each radial layer through quality factors associated with the P and S-waves (e.g. Aki and Richazds, 1980). In the presence of an LOVD tool, the sources and the receivers are located on the outer wall of the tool. A monopole source corresponds to a ring source or a collection of point sources. A dipole source corresponds to two sources 180 degrees apart and opposite in phase. A quadrupole source corresponds to four sources 90 degrees apart and alternate in sign. The simulation allows for unbalanced sources and/or receivers. The resulting waveforms can be returned as the individual response at each azimuthal receiver, or properly combined as a function of the source (for a dipole, the wavefield of the diametrically opposed receivers is subtracted, while for a monopole excitation, all the azimuthal receivers aze summed). The described models do not take into account irregulaz borehole shape and/or azimuthal variations in the cement thickness and the quality of the bonds, 2 • but those situations are beyond the scope of this work. A well-bonded case is modelled as four concentric layers, with the tool in the centre. The inner layer is the bore fluid followed by the casing, the cement, and the formation. The formation arrival should be readily detectable, while the casing arrivals should have little (or no) energy. The top waveform of Fig. 2 shows a single receiver response for such a case. The other extreme situation, i.e., the completely unbonded (free pipe) case, also includes four concentric layers but the elastic cement is replaced by a fluid layer. In such a situation, a strong casing arrival is expected that can overshadow the formation signal (Fig. 2, bottom waveform). The partially bonded configuration is more complex: the cement may not be bonded to the casing or the formation. Such configurations are modelled through the introduction of an intermediate fluid layer between the casing and the cement or between the cement and the formation. The thickness of the intermediate fluid layer plays a role. Depending upon the characteristics of the partially bonded case, some formation and some casing arrival can be expected (Fig. 2, middle waveform). In the sections below, the effects of partial bonding are investigated. We first explored a simple well-bonded case with an LWD tool in the centre of the borehole. The LWD tool is modelled as a modified steel drill collaz (with an inner fluid annulus) for these studies (Table 2). The case of a (nominal) 6 3/a-in. tool in 9 5/8-in. casing is presented. Since LWD tools are available from 4 3/a-in. to 9 ~/z-in. and regularly log 30-in. to 6 1/8-in. holes and casing comes in numerous sizes and weights, the effects of various combinations were investigated but cannot be presented here due to space constraints. Figure 3 shows the semblance VDL results for a partially bonded case with a centralised LWD tool, monopole source and three different formations. The left plot is computed from high frequency data (12 kHz source), while the right is from lower frequency (6 kHz source) data. The top sample is from a fast formation, the middle from a "medium" formation, and the bottom from a "slow" formation (Table 6). It is reminded that a fast formation is one for which the sheaz slowness is less than that of the borefluid, while the shear slowness of a slow formation is greater than that of the bore fluid. We show semblance plots for ~J SPWLA 45a' Annual Logging Symposium, June (~9, 2004 the synthetic data examples in addition to the standazd waveform displays as it is common to produce slowness logs using them. In the presence of a fast formation (top), casing, compressional and sheaz arrivals are visible in the waveforms and VDLs. However, in the waveform plot (especially the low frequency); it is not easy to sepazate the casing and formation P-wave arrivals. Semblance over multiple receivers can be better at resolving two waves close in velocity. The high frequency semblance (left) is dominated by the casing arrival, but the semblance from the lower frequency data (right) better distinguishes the two arrivals. For the medium formation, only the compressional arrival is present but with good coherence and energy. The casing and formation compressional arrivals aze easily sepazated both on the waveform and semblance plots, and the amplitudes/semblances for the low and high frequency data sets aze similaz. In the slow formation, the casing and formation compressional arrivals are again easily distinguished, but note that due to the lower resonant frequency of the formation, the low frequency data shows higher amplitude compressional arrivals as well as better semblance. Figure 4 displays a field data example of a LWD dipole cased hole log. The left track shows the semblance VDL from a high frequency (12 kHz) source while the right shows semblance results from a low frequency (6 kHz) source. In this case, the low frequency source is cleazly better for exciting the formation modes. Since there are commercially available monopole, dipole, and quadrupole LWD tools, we investigated the relative responses of each in cased holes. For detecting formation compressional and refracted sheaz arrivals (low or high frequency), modelling shows that the monopole response is generally strongest, and the dipole a bit weaker, and the quadrupole response even weaker for detecting refracted modes behind casing. The monopole behaviour of the partially bonded case can be seen in the field data examples of Figures 5 and 6, which were obtained from the same data set collected with a LWD dipole tool. The data of Figure 5 were collected in a partially bonded cased section of the hole while those of Figure 6 were collected a few hundred metres away in the open hole section. The hole was neazly vertical, and the .tool was 3 • SPWLA 45a' Annual Logging Symposium, June 6-9, 2004 reasonably centralised in both cases. However, note the very cleaz monopole chazacter of the poorly bonded cased hole waveforms (Figure 5) compazed to the clearly dipole behaviour of the open hole data (Figure 6). This is a commonly observed phenomenon with data collected by a dipole tool: in open holes, the data are predominately dipole in character, but in poorly bonded cased holes, the formation arrivals are nearly always in phase (monopole chazacter). The complexity of the LWD environment favours non pure mode excitation. In the open hole and well bonded cases, the compressional waves excited by a monopole or dipole source can have very. close amplitudes.. In partially bonded cased holes, a monopole source excites a much stronger formation compressional wavetrain than a dipole source. Conceptually, the observed compressional wavetrain can be predominately monopole in character in situations where the monopole component of the pseudo-dipole source is the most efficient. The behaviour of the fundamental, or "interface" modes in cased holes can be complicated considerably from the already complex LWD open hole situation. Figure 7 shows monopole (a), dipole (b), and quadrupole (c) synthetics from a low frequency source (6 kHz) in the presence of a slow formation. The top sample of each track is relative to the open hole situation, the middle one to the well- bonded situation, and the bottom to a poorly bonded case. Note that in all three cases, the fundamental mode propagates significantly faster in the well- bonded cased hole than in the open hole but not in the poorly bonded case. The conditions and position of the bond will also affect the velocity of the fundamental modes Given the amount of variables in cased hole conditions, slower than fluid sheaz logging, which is complex enough in the LWD open hole environment, can become even more difficult in the LWD cased hole. Considering the predominant monopole character of the observed compressional data in the poorly bonded situations, only the monopole simulations aze presented in the remaining discussions. With respect to the compressional part of the wavetrain, dipole and quadrupole results aze not in contradiction. There aze two relatively straightforwazd ways to envision partially bonded cases. The first is to • consider the case where there is good formation- cement bonding but no bond between casing and cement. This is the "free pipe" scenario. The corresponding model includes a fluid layer between the casing and the cement. Figure 8 shows synthetic monopole data obtained in the presence of a slow formation with increasing thickness of the fluid layer from top to bottom. As the thickness of the cement layer decreases, it becomes increasing difficult to detect the formation arrival while the amplitude of the casing arrival increases. The second way to model poorly bonded cased holes is to place a fluid layer between the formation and the cement. This is generally. referred to as the "unbonded" case. Figure 9a shows, from top to bottom, a fully bonded (no-fluid) case to a completely unbonded (no-cement case). There is a clear evolution of the casing-cement first arrival. The thicker the cement bonded to the casing, the slower the velocity of the "casing" arrival. Figure 9b and 9c aze the same partially bonded examples as illustrated in figure 9a, but with different cement pazameters (see Table S). For a given thickness, faster cement leads to a faster casing- cement arrival. The slowness value observed in casing is traditionally used to "validate" sonic tool performance. (Dewan, 1983) It is important to recall that only free pipe (no cement bonded to the casing), faz from the source (so as not to read plate modes instead of body modes), will arrive with the sonic velocity of steel, as many factors can affect the velocity (and frequency) at which cemented casing will ring. The effects of vazying annular size and casing thickness have been found to be minimal on the measured casing velocity. However, as expected, the amplitude of the casing arrival is affected. Over the drilling time, the source and receivers aze most likely going to be unbalanced, amplitude wise. Such effects have been theoretically investigated and found to be minimal on the quality and reliability of the processing. The model used in this study cannot take into account the tool eccentricity. However, careful examination and processing of a lazge quantity of data tend to prove that the slowness determination is little affected and that qualitative detection of cement-bonding quality can still be performed. It is advantageous to analyze sepazately 4 • the receiver arrays available at different azimuths prior to their combinations. LWD cased hole logging field data examples and practical operational recommendations Due to the nature of LWD logging, a few practical operational considerations should be kept in mind when planning to acquire cased hole data. Since LWD tools acquire data by time and not depth, it is important to consider the need to adequately sample (populate the depth grid) over the primazy zone(s) of interest. Frequently, tripping in over the cased intervals can approach instantaneous pipe speeds of nearly 3000 ft/hour. Even with a four second sample data acquisition rate this would yield a sample every 3.3 feet. For logging through casing or detailed cement-bond information, this would not be adequate. However, for gross top-of-cement information, this could well be sufficient. For more fully detailed through-casing results or cement- bonding information, it is recommended to ideally acquire data over the interval of interest at the rate of one data point per foot. Figure l0a displays a typical LWD acquisition sequence with well-cemented casings. As the tool is tripped into the hole at a rapid speed, low density data is acquired (yellow) with higher density data acquired when the pipe is held still during the time connections are made (black). High-density data will also be acquired while drilling out of the shoe (red) and in the open hole (green). Often it will be decided "on the fly" to perform cement evaluation with LWD tools as problems have been encountered with a recent cement job. It is becoming common to acquire these data on a trip out of the hole after the next section has been drilled as a validation check (assuming an adequate leak-off test). Another alternative is to run the LWD tool in a scraper/cleanout assembly when the cement has set up prematurely inside of the casing. In either case, adequate information must be acquired over the critical zone of interest, as illustrated in Figure lOb (blue). Best practice "common sense" recommendations aze to 1) identify the potential logging objective zones of interest. In order to validate the top of cement this may be only the last couple of hundred feet above the shoe and into the open hole (i.e. roughly the last 2-3 stands of drillpipe) 2) match the pipe movement • SPWLA 45a' Annual Logging Symposium, June 6-9, 2004 speed with the downhole tool's acquisition rate to insure an adequately populated depth grid, and 3) communicate to all rigsite operations personnel the nature of the operation and the precise depth range over which to acquire the high density data in order to minimise any potential time impact on the rig. Figure 11 shows an example of an interval logged through casing. The compressional velocity was of primary interest and was identified as a logging objective prior to the run so that a high density data set was acquired on the trip in the hole. The sonic slowness curves (i.e., compressional, shear (if present) and casing) aze displayed in the leftmost track. To the right of the depth track is a semblance VDL from the high frequency firing of the tool (the low frequency one can also be displayed). The slowness curves of the left track are superimposed on the VDL. The next track is the amplitude (energy) of the casing arrival which can be used as a visual check of the quality of the cement bond quality. The rightmost tracks display the waveforms from a single receiver displayed as a VDL (track 5) or as waveforms (track 6). The amplitude changes that aze seen in the casing energy curve can also be followed in these waveform displays. Figure 12 shows an example of a lazger interval of the same well. Most of the cased interval was logged on the normal trip in, yielding sparse data sampling. Nonetheless, the casing energy curve yields the fact that the casing is more than likely unbonded at -3300-3700 feet. In addition, the compressional log through casing (magenta curve in the leftmost track) though spazse, matches the more densely sampled wireline curve (black) over the same interval. If it had been impossible to acquire wireline data over this interval, the sparse compressional log behind casing would have provided seismic tie-in data for the cased hole section. Figure 13 is another example showing both compressional log data behind casing, as well as casing bond information. By examining the casing energy curve (red curve, middle track), and the behaviour of the compressional curve, it is readily seen that the casing is very poorly cemented above approximately 1735 feet, where the energy of the casing arrival is large and the compressional curve undetectable. The interval from 1735 feet to about 1900 feet is partially bonded, as we see both a good formation arrival and weaker casing arrivals. Finally, ,7 SPWLA 45u' Annual Logging Symposium, June 6-9, 2004 at about 1900 feet the casing arrival abruptly attenuates, indicating that this is the location of the top of cement. CONCLUSIONS Cased-hole sonic logging, while more complex than open-hole logging, can nonetheless be well chazacterised by modelling to understand the physics of the system. The special LWD situation is an extension of the wireline cased hole modelling that is well developed. Many times, LWD sonic cased hole data aze acquired as a by-product of logging a deeper open-hole objective and have simply been disregazded. Thus, a potential wealth of data exist that needs only be explored. With minimal impact to operations LWD logs in cased holes can often provide sonic velocities through casing as well as basic cement evaluation services, including top of cement and cement bond information. ACKNOWLEDGMENTS The authors wish to thank the management of Halliburton Energy Services for permission to publish this work. REFERENCES Aki, K., and Richazds, P.G., 1980, Quantitative Seismology. Theory and Applications. Vol. I, W.H. Freeman and Co. Chang, S.K., and Everhart, A.H., 1983, A study of sonic logging in a cased hole: J. Petr. Tech., 35, 1745-1750. Chen, S.T., Eriksen, E.A,1991, Compressional and shear wave logging in open and cased holes using a multipole tool: Geopyhsics 56, 550-557. Deady, R., Bourke, A., Higgins, C., Smith, N., 2001, Next Generation LWD Sonic Tool Overcomes a Major Hurdle to Full Wireline Replacement for a Northwest Shelf Australia Operator, SPE Asia Pacific Oil and Gas Conference. • Dewan, J.T., Essentials of Modem Open-Hole Log Interpretation., 1983, Chapter 5, Porosity logs, 139- 170. Schmitt, D.P., 1993, Dipole logging in cased boreholes: J. Acoust. Soc Am 93 ,640-646. Schmitt, D.P., Bouchon, M., 1985, Full wave acoustic logging: synthetic microseismograms and frequency-wavenumber analysis: Geophysics 50 , 1756-1778. Tubman, K.M., Cheng, C.H., Cole, S.P., and Toksoz, M.N., 1986, Synthetic full-waveform acoustic logs in cased boreholes, II -poorly bonded casing: Geophysics 51, 902-913. Valero, H.P., Skelton, O. And Cao, H., 2000, An overview of sorric slowness evaluation behind casing. Paper I presented at the 6's Well Logging Symposium of Japan. Vazsamis, G., Wisniewski, L., Arian, A., and Althoff, G., A New Full Wave Dual Mode Sonic Tool Design and Case Histories: SPWLA 40s' annual logging symposium, May 30-June 3, 1999. ABOUT THE AUTHORS Jennifer Market is the LWD acoustics specialist for Halliburton. Denis P. Schmitt joined Halliburton Technology in March of 2002 as a scientific advisor for acoustic and borehole seismic related issues. He is a member of SPWLA and SEG. Ron Deady is the global product champion for Sperry-Sun Halliburton's acoustic LWD services. Deady has over 20 years experience in numerous field operations, R&D and petrophysical support roles for several of the major LWD suppliers. He is a member of the SPWLA, SPE and SEG. 6 ._ • SPWLA 45~nnual Logging Symposium, June 6-9, 2004 Table 1: Tool Parameters F~ures Inner Di. (in.lcm) Outer Di. (in/cm) Otc us/ft Ots us/ft p lkg/m3) Q~ ~ 3,7,8,9 1.92/4.876 7.25/18.415 52.6 122 5900 5.0 2.0 *Inner bore fluid, in all cases, is equal to outer bore fluid (see table 2). Table 2: Bore Fluid Parameters Fi utgu es Inner Di. (in./cm) Outer Di. (in/cm) Otc us/ft Ots uslft p (k m3) ~ ~g 3,7,8,9 7.25/18.415 8.68/22.04 189 - 1198.3 100 - Table 3: Casin¢ Parameters Figures Inner Di. (in./cm) Outer Di. (in/cm) Otc us/ft its us/ft P (k~ Q~ Q~ 3,7,8,9 8.68/22.04 9.63/24.46 50 91 7500 1000 1000 Table 4: Intermediate Fluid Laver Properties F~ Inner Di. (in./cm) Outer Di. (in/cm) etc us/ft Ots us/ft P (k~ ~ Q~ 3,7(bottom) 9.63/24.46 10.63/2? 189 - 1198.3 100 - 8 9.63/24.46 various 189 - 1198.3 100 - 9 various 12.25/31.15 189 - 1198.3 100 - Table 5: Cement Properties FiQUtes Inner Di. lip./cm) Outer Di. (in/cm) etc us/ft its us/ft p (k m3) ~ Q~ 3,7(bottom) 10.63x17 12.25/31.15 108 176.2 1920 40 30 7(middle) 9.63/24.46 12.25/31.15 108 176.2 1920 40 30 8 various 12.25!31.15 108 176.2 1920 40 30 9a 9.63/24.46 various 108 176.2 1920 40 30 9b 9.63/24.46 various 80.2 169.4 1720 40 30 9c 9.63/24.46 various 67.8 122 1920 40 30 Table 6: Formation Properties Figures Inner Di. (inJcm) Outer Di. (in/cm) 3a 12.25/31.15 00 3b 12.25/31.15 00 3c,7,8,9 12.25/31.15 00 Otc us/ft Ots us/ft p (kg/m3) ~ Qg 70 116.3 2300 1000 1000 90 185.1 2100 1000 1000 120 240.1 2100 1000 1000 7 ~L- SPWLA 45a' Annual Coggin S m o~m, June 6-9, 2004 g Y P ~,{FI~1~1~1~1~1~1~1~1~1~1~/I~P., Y'1'1'I'1i1'1'1'1'1'I'I'1'l l 1'1'1'1{f'., "t.ement" ~1y I11'I'Ill'1'i,1,1,1,1,1,1,1,1,1,1,1,1,1,1,1 ti 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 illlll 111111 llllllllllllllll liillllllllllllllllll ly 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 I 1 1 1 1 1 1 1 1 1 1. 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 7 1 1 1 1 1 1 1 1 1 vvv 1 1 1 1 1 1 1 1~•. 9111111111 vvvvvvv 111 11111. ! 1 1 1 1 1 1 1 1 vvv vvv- I 1 1 1 1 1 Y 11111111 v vv vvvv Illlllr '1 1 1 1 1 1 1 1 vvv v 1 1 1 1 1 1 1 1{ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1; '1 1 1 1 1 1 1 ~~ ~ =v 1 1 1 1 1 1 1 I 111111111'111 = 1111111111111 f ~~~ 1 1 1 1 1 1 1 v 1 1 1 1 1 1 1 1 1 1 1 v 1 1 1 1 P.. 111'1111111 =v 1 1 1 II111115 111111 v Illlllr 1'1'1'1'1' 1 11 1 1 1 1 1 1'1'1'1'1' ' ' ' ' ' _ 1 1 1 1 1 1 1 1 1 1 1 1 = 1 1 1 1 1 1 1111111111 v 111111111' v 1 1 1 1 1 1 ~\ = / 1 1 1 1 1 1 ) v 1~1~1~1~1~1~1 1'1'1'1'11 1111111111 v ~ v l l l l l l l 1 1 1 1 1 1 1 1 1 1 1 1 1 TOO1- ~ u 1 1 1 1 1 11111111111 iv 1 ' ' ' ' ' 1 1 1 1 1 1 1 lllllllilll'1F v 1 1 1 1 1 1 . 1111111 v ~ 1 1 1 1 1 1 1 vv - . 1'1'1'1'1'1'1'4 vv 1111111- ~ 1 1 1 1 ~ ~ 1 1 1 1 1 1 1 vv 1 1 1 1 1 1 1 vv 1 1 1 1 1 1 1 1 v 1 1 1 1 1 1 1 1 n vv 1 1 1 '.' vv 1 1 1 1 1 1 1 {• ~'~'~'~ vv 1 1 1 1 1 1 1 1 v vvv 1 1 1 1 1 1 1 1~ avy vvvv 1 1 1 1 1 1 1 I S 711'1'111'1'1'1'111 __ vvvvvvvv I I I I I I I I L Y 111111111111111111 X1 1 rvvv 1111~1~1~1,1'1~1~1i~` ,1 1 1 1 1 1 1 1 1 '111111'11111'1'11 . 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11111'1'I'1'III'1'1'1'1'1'1'1'1'1'1'f 1 . •{1'1'1'1'1'1'1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I,t '11111111111'I'1'1'1'1'1'1'1'111~Y {,111111'1'i llllllllllllllllllllllllllllil!: ~~ Full bond Fuur Bond ~.~7R No BUnd Casing Arrival Formation /rival '{'+!~;,i'~'i'i'i'i'i'i'~'i'~'~:~ t D D2 D.4 Q6 O B 1 12' . 1.4 1 6 1 8 2-- Time (rns) Figure 1.6 3/a-in. LWD tool in 9 5/8-in. cased hole Figure 2. Single receiver waveforms showing fully bonded (top), poorly bonded (middle), and unbonded (bottom) cases. 5 .~ 1 f ~ $ ~ ~ 's _ 40 -6~~ _.;:1b0 %1~9-~ 7~- os ~ Is 4D E0-_."BO 1C'0--120. 110-~- os i i.5~. SIOYT B56 (LL$I~I) - Tirt~l'~'I - Su MIBES 1LL5~1) 'in i~lt-i- ~~- _ -_. - a b Figure 3 - Waveforms and semblance VDL modelling results for a LWD tool with a monopole source in fast, medium, and slow formations, partially bonded. The left plot illustrates high frequency data (12 kHz), which favours the casing arrival over the formation arrival. The right display shows low frequency (6 kHz) data for the same pazameters, where the formation arrivals aze easier to pick from the semblance VDL. All data are scaled and aze the same. 8 - • SPWLA Annual Logging Symposium, June (>~9, 2004 Figure 4. Semblance VDL display of high frequency (left) and low frequency data (right) through casing. Figure 5 -Example of LWD data in a cased hole illustrating monopole behaviour. Aso -- }o x -icon `; _ - 1A x S ~~ 1~ ~ ;x 130'~I ~ "'"- ~; ~'~ ~ d~ :.100' ~ c ~ o. BD S ed` ~ x ao 0.2;.',0.4" ,~ 6:j-.,D 8 ~-'.1 `.~ .1 2 ~'s1.4 ~ 1 6 ~. D'4 , D,B -0.'8..' 1 7,2 1~4 1'6 1'8 .. 'time (rr s}'~~` ~~ ~ ~ time ems) , '--0ate: 1B-Mar-200420A129 Figure 6. Open hole data for same tool and same well, showing clear dipole characteristics. 9 ~SPWLA 45a' Annual Logging Symposiuli; June 6-9, 2004 -.,,- ...............' . s z ~` s ! ~ ~t ~ 1~ ~ ~_~ , s im ka _ro , ~ _. I«mness (~ ;~~iU 1 ~ .~.-.._._. _ _ _ i a b c Figure 7. Open hole (top), fully bonded (middle) and poorly bonded (bottom) examples of the interface mode behaviour. Monopole source(a), dipole source(b), and quadrupole source(c). 0 .~ ~+ r ~« Figure 8: Waveform and semblance VDL results from modelling the free pipe scenario. LWD tool with a monopole source in a slow formation. The topmost case is completely bonded, and the lowest case is completely without cement. The amount of cement bonded to the formation decreases from top to bottom. It is replaced by fluid, as illustrated on the left. . 10 • E e io ,4 a b c Figure 9: Waveform and semblance VDL results from modelling unbonded scenario. LWD tool with a monopole source in a slow formation. The topmost case is completely bonded, and the lowest case is completely without cement. The amount of cement bonded to the casing decreases from top to bottom. It is replaced by fluid as illustrated on the left. ,z a 1 r ~ ~~ ~ .~ ~~ '~ "*~ s 3 xr ~ ~ - ~- 4 a 4 } i ~' .. t~'1 ~ =3 ~ {~ ~ a b_ Figure 10. Illustration of casing strings and data acquisition sequence scenarios. (a) Low density data is acquired (yellow) with higher density data acquired when the pipe is held still during the time connections aze made (black). High- density data acquired while drilling out of the shoe (red) and in the open hole (green). (b) High data density planned for and acquired over critical zone of interest (blue). SPWLA~ Annual Logging Symposium, June 6-9, 2004 11 • SPWLA 45u` Annual Logging Symposi~June 6-9, 2004 • 12 Figure 11. Example of well-sampled cased-hole data acquired by a LWD dipole tool. Wireline data is presented for comparison. - ' • SPWLA~Annual Logging Symposium, June 6-9, 2004 Figure 12. Example of sparsely sampled cased-hole data acquired by a LWD dipole tool. Wireline data (left track, black) is presented for comparison. 13 . SPWLA 45th Annual Logging Sympos~ June 6-9, 2004 Figure 13. Example of cased-hole data acquired by a LWD dipole tool. The top of cement is easily seen at ~ 1900 feet. 14 .. ,, . , . , .: - T.. . . '~ SHARON K, ALLSUP-DRAKE 1109 CONOCOPHILLIPS - ATO 1530 u S 700 G ST. DATE 62-14J311 ANCHORAGE AK 99501. PAY TO THE Q ~T~ F' 1~Lf~5~ JCL $ /x.00 o ORDER OF .~/ VKi ~ C`'^"- ~ d la OLLARS 8 0:. ~¢a~k 3 CHASE Chase Manhattan Bank USA, N.a: Valid Up To 5000 Dollars ® ~ r 290 Whlt¢ CIaY C¢nter Dr.. Newark, DE 19111 /~. / MEMO _. _.:- -------~- ---- --"j ' < / ~; is03L100L44~:2L847L90 7 9 2 7 6-1'-LL09 { _.R.r ~y.~•w.ngrwp~ '~ tiP. a r ,r,~....~ a~.n-f.;. 4 .Z. / ~. - .,....,.,.. •s . \ \\~ • _. ~ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,(%~(,C ~C~ -~ PTD# ~b~ ~ /Z~ - evelopment Service Exploration Stratigraphic CHECK WIiAT ADD-OHS "CLUE"~ APP IES OP770NS) • MULTI The permit is !or a new wellbore segment of LATERAL eYisiing well . Permit No, API No. (lf API number Production. sbould continue to be reported as • last two. (2) digits a funciion'of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired, for the pilot bole must be clearly differentiated •in both • name (name on permit plus P]EI) and API Dumber (50 - 70/80) from records, data and logs acquired • for well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliaace with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comuanv Hamel assumes the liability of any • protest to the spacing .exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater thaw 30' . sample intervals from below the permafrost or from where samples are first caught and ] 0' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL -490100 Well Name: KUPARUK RIV UNIT 1C-20 Program SER Well bore seg ^ PTD#:2051230 Company CONOCOPHILLIPS ALASKA INC Initial ClassRype SER! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit fee attached Yes 2 Lease number appropriate_ _ _ - - ---- Yes - _ _ - _ _ Correction made to_ 10,4.07: well bore will not pass thru_ADL-28242; it willpaSS through ADL 25650. SFD . _ - - 3 Uniquewell_nameandnumbe[____________________________________ __ Yes_ __--__--_ 4 Well located in a_defnedpool_____ _________________________________ Yes_ _-___Kuparukftiver Oil Pool,g4vernedbyCO432C._____,___------________----_____-- 5 Well located proper distance from drilling unitboundary- - - - _ - Yes Conservation Order No. 4320 contains no spacing restrictions with respe~ to drjlling unit boundaries. - 6 Well located proper distance from otherwells- _ . _ _ - - Yes - . - - - - Conservation Order No. 4320 has no interwell_spacing_rest[ictions, _ 7 Sufficient acreage available in-drilling unit_ _ - - - _ _ - _ _ - _ - Yes - . - - -Conservation Order No. 4320 has_ng interwell_spaeing_restrictions, Wellbo[ewill be_more than 500' from 8 If deviated, is_wellboreptot-included - - . _ - - - Yes an-externa(proPerty linewhere_ownership or-landownership changes.- _ _ _ . - - _ _ 9 Ope[ator only affected party - - - - - - - - Yes - - - - - - - - - 10 Operator has.appropriate. bond inforoe---------- --- ----- ------ -- Yes. .----- ------- ----- -- ------------ --- --- ------ ------ - -- 11 Permit can be issued without conservation order Yes Appr Date 12 Permit_canbeissuedwjthoutadminist[ative-approyal___________________-__ Yes_ -__-----___-___-__---________-___-_____--_---_--_-_______..__--_____-_--- SFD 81912005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order# (put 10# in_comments).(For- Yes - -Area Injection Order No.-2B_ _ - _ - - - _ _ - _ _ _ .. - _ - 15 All wells-within1/4_milearea ofreyiewidentified(Forseruicewellonly)_______________ Yes_ _-____None__-----.---._------..._---_----..-._---.-_-.--.-_-__---_---_.-- 16 Pre-produced injector: duration of preproduction less than_3 months_(Fgr service well only) - - Yes 17 ACMP_Finding of Consistency_has been issued_for_thisprojea- _ _ _ _ - NA_ _ _ _ - ACMP determination_n_o longer_affeets t_he permit to drill process.- - - . - Engineering 18 Conducto[string_provided___________________________________ Yes_ _-_----______----_-_-________-__ 19 Surface casing-protectsalLknown_USDWs___________________--__-.-____ NA__ ----_Allaquifersexempted,40CFR_147.1Q2-(bk3).____--_.-_-_________--.--_ -------------- 20 CMT_voladeguate_tocirculate-onconductor_&surf_csg.__--__-_____-___-_____ Yes- --_ _______________________________,--_ __________--_-_________-_.-____ 21 CMT-vol adequate_to tie-in long string tosurf csg- - .. - - No_ _ _ . -All hydrocarbon zoneswill_ be_coyered. Annular disposal may-be-proposed, 22 CMT_willcoyerallknow_n_productiyehorizon_s__-..---_______-_-__- No-- --____Slottedlinercompletion planned__________________________________________________ 23 Casing designs adequate for C,TB&_germafr_ost-__---_ __________________ Yes- ______-_.....-______...__________-__.-__-_____-_.__..-- _____..__---__-- 24 Adequate tankage-or reserve pit _ .. Yes - - .. - - Rig is_equippedwith st_eel_pits. -No reserve_p_itplanned, All waste to approved annulus ordisposal wel_l.- - . - 25 If_a_re-drill,has-a10-4.03 for abandonment been approved_____________________ NA-- _______-.__--_____-._-__________--_--_______--_---__________--_-_____.- 26 Adequate wellbore separation_proposed- - - -- - - - - - - - - - - - - - -- - - - - - - - - - -- - - Yes - - - _ _ ..Proximity analysis performed, Traveling cylinder plot.provided.. Gyros possible._ _ - - - - - _ _ _ _ _ _ _ _ _ - - - _ 27 Ifdiverterrequi_red, doesitmeetregulati4ns_____--_-.-____-__---__ Yes- ----------------------------------------------------------------- Appr Date 28 Drilling fluid_program schematic & equip list adequate_ _ _ _ - - - _ _ - - Yes - - - - _ -Maximum expected formation pressure 9,4_EMW._ MW planned up to 10.2 ppg in 9-718" hole._ 9.5 ppg in Kupa_ruk, TEM 8/9/2005 29 BOPEs,_dgtheymeetregulation_______--.-________ ------------- Yes_ ____ ___ __ -- ___________----__--________,-__--___ ---. ________ ______________ 30 BOPE-press rating appropriate; test to_(put prig incomments)_ - - - . - - Yes - - - - MASP calculated at 2526psi, 3500-psi_appcopriate. CPAI normal tests to 5000-psi, .. - . 31 Choke.manfoldcompliesw/API_RP-53~May84)--------- ------------------ Yes- ----------------------------.-----------------------,---.---.--------.--- 32 Work willoccufwithoutoperationshutdow_n_______________________________ Yes_ _____-.---____--_----_______--_--_-_____-----_---_______-...__________..-- 33 Ispresence-of H2S gas_probable- - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - --- Yes _ _ _ - _ - - H2S is reported_on-lC-pad._ Mud should preclude-H2$on ng, Rig has sensors and_alarms., - - _ . - _ _ - - - - . 34 Mechanical_condition of wells within AOR yerifed (For service well only) Yes - - .. - - - There are no penetrations_of the Kuparuk within_1/4 mile-of 1 C-20 as proposed.. - - - - - - - Geology 35 Permitean be issued wlo hydrogen_sulfide measures- - - . - . - - - - - - - No_ - - _ - 90 ppm H2$was measured in offset well_1_C-1.2_in August_2004. - _ _ . - _ - - - _ _ - 36 Data_presented oq potential overpressure zones - - - - - - - - - - - - Yes . - _ - - -Expected gradient is 8,1_- 9:4-ppg EMW; _w_ill_be drilled with 92 - 9,5ppg mud.- Appr Date 37 _ _ - - Seismic analysis-of shallow gaszones - - - - - - - - - - - --- - - - - NA_ - Gas hydrates may be encountered. _Mitigation_measureddiscvssed in 1 C-20 Drilling Hazards-Summary. SFD 819/2005 38 Seabed conditionsuruey-(ifoff-shore)__________________________________ NA__ _-_---_____ 39 _Conta_c#name/phonefor_weeklyprogress_reports[exploratoryonly]---____-_____--- NA__ ___-._ ______________________________--_ Geologic Commissioner: Engineering Public Date: Commissioner: Date Commi sinner D ~' ~' ~ ~~'~, 9-10.°s ~ a '"V • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitiing Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 05 08:31:38 2006 Reel Header Service name .............LISTPE Date .....................06/04/05 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/04/05 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1C-20 PB1 API NUMBER: 500292327370 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 05-APR-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004046666 MW0004046666 MW0004046666 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE P. SMITH OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK F. HERBERT MWD RUN 5 MWD RUN 6 JOB NUMBER: MW0004046666 MW0004046666 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: l0E FNL: 1617 FSL: FEL: FWL: 1214 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 101.20 GROUND LEVEL: 60.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~ 3 5s'~3~ v ~ ~ a•e~`~-=iT~3 ~ ~ L~-~ Scientific Technical Services Scientific Technical Services V zG acs- ~iq BIT S K (IN) 1ST STRING 13.500 2ND STRING 9.875 3RD STRING 6.750 PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 16.000 125.0 10.750 11113.0 7.625 17659.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 4-6 INCLUDED PRESSURE-WHILE-DRILLING(PWD). MWD RUN 6 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND AZIMUTHAL LITHODENSITY (ALD) MWD RUN 6 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEO-PILOT ROTARY STEERABLE BHA (GP). THE EWR TOOL FAILED (AND RECORDED DATA WERE LOST) AFTER FOUR PASSES THROUGH A 24.3 DOG-LEG SEVERITY ZONE WITHIN THE RUN 6 INTERVAL. ONLY REAL-TIME SEDP,SEMP,AND SESP DATA WERE ACQUIRED - SEXP DATA WERE NOT PULSED TO THE SURFACE. 5. ALL DATA CURVES ARE SMOOTHED WITH A STEP OF 0.5 FT, AND A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED WITH A 1.1 FT WINDOW. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-6 REPRESENT WELL 1C-20 PB1 WITH API#: 50-029-23273-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18683'MD/6586'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-C0~ BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.2 - 9.5 PPG MUD SALINITY: 11,500 PPM CHLORIDES FORMATION WATER SALINITY: 11,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 3446.5 18538.5 RPX 34.46.5 17681.0 RPS 3446.5 18538.5 FET 3446.5 18538.5 RPM 3446.5 18538.5 GR 3454.0 18624.5 ROP 3493.5 18683.0 NPHI 17642.5 18597.0 NCNT 17642.5 18597.0 FCNT 17642.5 18597.0 RHOB 17656.0 18611.5 DRHO 17656.0 18611.5 PEF 17656.0 18611.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3446.5 6370.0 3 6370.0 11130.0 4 11130.0 14230.0 5 14230.0 17726.0 6 17726.0 18683.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type........ ~......0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FONT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3446.5 18683 11064.8 30474 3446.5 18683 FCNT MWD CNTS 113.42 820.11 403.494 1910 17642.5 18597 NCNT MWD CNTS 14492.1 32676 24123.5 1910 17642.5 18597 RHOB MWD G/CM 0.05 4.303 2.35948 1912 17656 18611.5 DRHO MWD G/CM -4.064 1.667 -0.0254618 1912 17656 18611.5 RPD MWD OHMM 0.97 2000 14.7764 30185 3446.5 18538.5 RPM MWD OHMM 0.37 1768.03 10.8536 30122 3446.5 18538.5 RPS MWD OHMM 0.37 2000 7.23625 30185 3446.5 18538.5 RPX MWD OHMM 1.2 208.31 6.26958 28470 3446.5 17681 FET MWD HOUR 0.17 253.02 2.66094 30185 3446.5 18538.5 GR MWD AP2 14.52 423.15 99.1922 30342 3454 18624.5 PEF MWD BARN 1.03 14.96 3.57761 1912 17656 18611.5 ROP MWD FT/H 1.45 1943.26 152.652 30380 3493.5 18683 NPHI MWD PU-S 17.83 56.97 29.953 1910 17642.5 18597 First Reading For Entire File..........3446.5 Last Reading For Entire File...........18683 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... ~04j05 • Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 3446.5 6321.0 RPX 3446.5 6321.0 RPS 3446.5 6321.0 FET 3446.5 6321.0 RPD 3446.5 6321.0 GR 3454.0 6329.0 ROP 3493.5 6370.0 LOG HEADER DATA DATE LOGGED: 26-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6370.0 TOP LOG INTERVAL (FT) 3493.0 BOTTOM LOG INTERVAL (FT): 6370.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 68.2 MAXIMUM ANGLE: 75.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) 125.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 212.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 5.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.750 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.530 104.0 MUD FILTRATE AT MT: 5.000 68.0 MUD CAKE AT MT: 4.300 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # • REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3446.5 6370 4908.25 5848 3446.5 6370 RPD MWD020 OHMM 6.35 51.1 14.3475 5750 3446.5 6321 RPM MWD020 OHMM 5.47 46.98 13.1273 5750 3446.5 6321 RPS MWD020 OHMM 5.16 49.3 12.6219 5750 3446.5 6321 RPX MWD020 OHMM 4.86 40.29 11.5425 5750 3446.5 6321 FET MWD020 HOUR 0.19 29.08 1.11003 5750 3446.5 6321 GR MWD020 API 14.52 1 24.94 68.3661 5751 3454 6329 ROP MWD020 FT/H 11.45 19 43.26 225.432 5754 3493.5 6370 First Reading For Entire File..........3446.5 Last Reading For Entire File...........6370 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File 'I'ype ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6321.5 11081.0 RPX 6321.5 11081.0 RPD 6321.5 11081.0 FET 6321.5 11081.0 RPM 6321.5 11081.0 GR 6329.5 11088.5 ROP 6370.5 11130.0 LOG HEADER DATA DATE LOGGED: O1-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11130.0 TOP LOG INTERVAL (FT) 6370.0 BOTTOM LOG INTERVAL (FT) 11130.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.2 MAXIMUM ANGLE: 75.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESTS. 4 78633 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 125.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Spud Mud 10.20 151.0 7.8 250 4.0 3.700 70.0 2.340 114.8 5.000 70.0 4.200 70.0 Logging Direction.......~......Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6321.5 11130 8725.75 9618 6321.5 11130 RPD MWD030 OHMM 3.17 31.45 7.50141 9520 6321.5 11081 RPM MWD030 OHMM 3 32.04 7.17046 9520 6321.5 11081 RPS MWD030 OHMM 2.81 26.15 6.84739 9520 6321.5 11081 RPX MWD030 OHMM 2.6 23.85 6.2969 9520 6321.5 11081 FET MWD030 HOUR 0.17 32.92 1.19754 9520 6321.5 11081 GR MWD030 API 29.48 130.84 77.3601 9519 6329.5 11088.5 ROP MWD030 FT/H 3.32 1783.28 178.786 9520 6370.5 11130 First Reading For Entire File..........6321.5 Last Reading For Entire File...........11130 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT; .5000 FILE SUMMARY VENDOR TOOL CODE START STOP DEPTH RPS 11081.5 14186.0 RPX 11081.5 14186.0 FET 11081.5 14186.0 RPM 11081.5 14186.0 RPD 11081.5 14186.0 GR 11089.0 14193.5 ROP 11130.5 14230.0 LOG HEADER DATA DATE LOGGED: 13-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14230.0 TOP LOG INTERVAL (FT) 11130.0 BOTTOM LOG INTERVAL (FT) 14230.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 73.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... D~H 9.875 11113.0 LSND 9.40 60.0 9.0 550 3.5 • 1.850 74.0 1.070 132.8 1.900 74.0 1.450 74..0 Datum Specification Block~b-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11081.5 14230 12655.8 6298 11081.5 14230 RPD MWD040 OHMM 1.85 1856.28 12.9307 6210 11081.5 14186 RPM MWD040 OHMM 1.68 446.38 4.21816 6210 11081.5 14186 RPS MWD040 OHMM 1.56 292.39 3.78831 6210 11081.5 14186 RPX MWD040 OHMM 1.45 208.31 3.57529 6210 11081.5 14186 FET MWD040 HOUR 0.17 228.61 4.60121 6210 11081.5 14186 GR MWD040 API 40.62 178.59 99.0635 6210 11089 14193.5 ROP MWD040 FT/H 3.87 855.58 103.629 6200 11130.5 14230 First Reading For Entire File..........11081.5 Last Reading For Entire File...........14230 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 14186.5 17681.0 RPD 14186.5 17681.0 RPX 14186.5 17681.0 RPM 14186.5 17681.0 FET 14186.5 17681.0 GR 14194.0 17689.0 ROP 14230.5• LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 17726.0 17-DEC-05 Insite 66.37 Memory 17726.0 14230.0 17726.0 69.8 77.8 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 9.875 11113.0 LSND 10.00 64.0 8.8 800 2.8 1.800 81.0 1.040 145.4 .900 81.0 1.800 81.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 ~ RPX MWD050 OHMM 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14186.5 17726 15956.3 7080 14186.5 17726 RPD MWD050 OHMM 2.53 2000 16.3478 6990 14186.5 17681 RPM MWD050 OHMM 2.15 1738.76 12.3778 6990 14186.5 17681 RPS MWD050 OHMM 1.48 22.62 5.50682 6990 14186.5 17681 RPX MWD050 OHMM 1.2 12.27 4.28844 6990 14186.5 17681 FET MWD050 HOUR 0.23 26.31 1.26825 6990 14186.5 17681 GR MWD050 API 51.29 423.15 163.18 6991 14194 17689 ROP MWD050 FT/H 1.45 423.27 108.691 6992 14230.5 17726 First Reading For Entire File..........14186.5 Last Reading For Entire File...........17726 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 17642.5 18597.0 FCNT 17642.5 18597.0 NCNT 17642.5 18597.0 RHOB 17656.0 18611.5 DRHO 17656.0 18611.5 PEF 17656.0 18611.5 RPM 17681.5 18538.5 FET 17681.5 18538.5 RPS 17681.5 18538.5 RPD 17681.5 18538.5 GR 17689.5 18624.5 ROP 17726.5 18683.0 LO G HEADER DATA DATE LOGGED: 29-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 18683.0 TOP LOG INTERVAL (FT) 17726.0 BOTTOM LOG INTERVAL (FT) 18683.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.1 MAXIMUM ANGLE: 90.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 CTN COMP THERMAL NEUTRON 10603684 EWR4 Electromag Resis. 4 162742 ALD Azimuth. Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 17659.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 53.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .210 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .100 156.0 MUD FILTRATE AT MT: .240 68.0 MUD CAKE AT MT: .280 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 RHOB MWD060 G/CM 4 1 68 12 4 ~ DRHO MWD060 G/CM 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 FET MWD060 HOUR 4 1 68 32 9 GR MWD060 API 4 1 68 36 10 PEF MWD060 BARN 4 1 68 40 11 ROP MWD060 FT/H 4 1 68 44 12 NPHI MWD060 PU-S 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 17642.5 18683 18162.8 2082 17642.5 18683 FCNT MWD060 CNTS 113.42 820.11 403.494 1910 17642.5 18597 NCNT MWD060 CNTS 14492.1 32676 24123.5 .1910 17642.5 18597 RHOB MWD060 G/CM 0.05 4.303 2.35948 1912 17656 18611.5 DRHO MWD060 G/CM -4.064 1.667 -0.0254618 1912 17656 18611.5 RPD MWD060 OHMM 0.97 2000 56.877 1715 17681.5 18538.5 RPM MWD060 OHMM 0.37 1768.03 42.6581 1652 17681.5 18538.5 RPS MWD060 OHMM 0.37 2000 10.8717 1715 17681.5 18538.5 FET MWD060 HOUR 0.27 253.02 14.6347 1715 17681.5 18538.5 GR MWD060 API 32.33 93.98 66.3551 1871 17689.5 18624.5 PEF MWD060 BARN 1.03 14.96 3.57761 1912 17656 18611.5 ROP MWD060 FT/H 1.84 293.4 123.257 1914 17726.5 18683 NPHI MWD060 PU-S 17.83 56.97 29.953 1910 17642.5 18597 First Reading For Entire File..........17642.5 Last Reading For Entire File...........18683 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/04/05 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/04/05 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF • • Physical EOF End Of LIS File ~ 3.8 ~ s~ C1Tc 2~~0 - «~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 04 16:17:36 2006 Reel Header Service name .............LISTPE Date .....................06/04/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/04/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1C-20 API NUMBER: 500292327300 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 04-APR-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004046666 MW0004046666 MW0004046666 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE P. SMITH OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK F. HERBERT MWD RUN 5 MWD RUN 6 MWD RUN 8 JOB NUMBER: MW0004046666 MW0004046666 MW0004046666 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE P. SMITH OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK F. HERBERT MWD RUN 9 JOB NUMBER: MW0004046666 LOGGING ENGINEER: P. SMITH OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: l0E FNL: 1617 FSL: FEL: FWL: 1214 ELEVATION (FT FROM MSL 0) UIC 2OS-ffg r KELLY BUSHING: DERRICK FLOOR: 101.20 GROUND LEVEL: 60.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 125.0 2ND STRING 9.875 10.750 11113.0 3RD STRING 6.750 7.625 17659.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING 1C-20 PB1 AT 17900'MD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-6,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 4-6,8,9 INCLUDED PRESSURE-WHILE-DRILLING (PWD). MWD RUNS 6,8,9 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHODENSITY (ALD), AND AT-BIT INCLINATION (ABI) MWD RUNS 6,9 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). THE EWR TOOL FAILED (AND RECORDED DATA WERE LOST) AFTER FOUR PASSES THROUGH A 24.3 DOG-LEG SEVERITY ZONE WITHIN THE RUN 6 INTERVAL. ONLY REAL-TIME SEDP,SEMP,AND SESP DATA WERE ACQUIRED - SEXP DATA WERE NOT PULSED TO THE SURFACE. NO PROGRESS WAS MADE DURING MWD RUN 7. 6. ALL DATA CURVES ARE SMOOTHED WITH A STEP OF 0.5 FT, AND A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED WITH A 1.1 FT WINDOW. 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-6,8,9 REPRESENT WELL 1C-20 WITH API#: 50-029-23273-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 21081'MD/6658'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.2 - 9.6 PPG MUD SALINITY: 11,500 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPM 3446.5 21029.5 RPS 3446.5 21029.5 RPD 3446.5 21029.5 RPX 3446.5 21029.5 FET 3446.5 21029.5 GR 3454.0 21022.5 ROP 3493.5 21081.0 NPHI 17642.5 20995.0 NCNT 17642.5 20995.0 FCNT 17642.5 20995.0 RHOB 17656.0 21009.5 DRHO 17656.0 21009.5 PEF 17656.0 21009.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3446.5 6370.0 MWD 3 6370.0 11130.0 MWD 4 11130.0 14230.0 MWD 5 14230.0 17726.0 MWD 6 17726.0 17900.0 MWD 8 17900.0 18708.0 MWD 9 18708.0 21081.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3446.5 21081 12263.8 35270 3446.5 21081 FONT MWD CNTS 113.42 1218.45 427.988 6706 17642.5 20995 NCNT MWD CNTS 14492.1 38103.4 24896.2 6705 17642.5 20995 RHOB MWD G/CM 0.05 4.303 2.45301 6708 17656 21009.5 DRHO MWD G/CM -4.064 1.667 0.0334544 6708 17656 21009.5 RPD MWD OHMM 0.97 2000 14.6687 35167 3446.5 21029.5 RPM MWD OHMM 0.37 1768.03 10.588 35167 3446.5 21029.5 RPS MWD OHMM 0.37 2000 7.68832 35167 3446.5 21029.5 RPX MWD OHMM 1.2 208.31 6.68386 34723 3446.5 21029.5 FET MWD HOUR 0.17 253.02 2.73412 35167 3446.5 21029.5 GR MWD API 14.52 423.15 94.8503 35138 3454 21022.5 PEF MWD BARN 1.03 14.96 3.46676 6703 17656 21009.5 ROP MWD FT/H 0.23 1943.26 145.228 35176 3493.5 21081 NPHI MWD PU-S 13.38 56.97 28.1938 6706 17642.5 20995 First Reading For Entire File..........3446.5 Last Reading For Entire File...........21081 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3446.5 6321.0 FET 3446.5 6321.0 RPD 3446.5 6321.0 RPX 3446.5 6321.0 RPM 3446.5 6321.0 GR 3454.0 6329.0 ROP 3493.5 6370.0 LOG HEADER DATA DATE LOGGED: 26-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6370.0 TOP LOG INTERVAL (FT) 3493.0 BOTTOM LOG INTERVAL (FT) 6370.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 68.2 MAXIMUM ANGLE: 75.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) 125.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 212.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 5.3 ~ RESISTIVITY (OHMM) ERATURE (DEGF) AT T MUD AT MEASURED TEMPERATURE (MT) 3.750 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.530 104.0 MUD FILTRATE AT MT: 5.000 68.0 MUD CAKE AT MT: 4.300 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3446.5 6370 4908.25 5848 3446.5 6370 RPD MWD020 OHMM 6.35 51.1 14.3475 5750 3446.5 6321 RPM MWD020 OHMM 5.47 46.98 13.1273 5750 3446.5 6321 RPS MWD020 OHMM 5.16 49.3 12.6219 5750 3446.5 6321 RPX MWD020 OHMM 4.86 40.29 11.5425 5750 3446.5 6321 FET MWD020 HOUR 0.19 29.08 1.11003 5750 3446.5 6321 GR MWD020 API 14.52 124.94 68.3661 5751 3454 6329 ROP MWD020 FT/H 11.45 1943.26 225.432 5754 3493.5 6370 First Reading For Entire File..........3446.5 Last Reading For Entire File...........6370 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File 'I'ype ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 6321.5 11081.0 RPX 6321.5 11081.0 FET 6321.5 11081.0 RPM 6321.5 11081.0 RPS 6321.5 11081.0 GR 6329.5 11088.5 ROP 6370.5 11130.0 LOG HEADER DATA DATE LOGGED: O1-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11130.0 TOP LOG INTERVAL (FT) 6370.0 BOTTOM LOG INTERVAL (FT) 11130.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.2 MAXIMUM ANGLE: 75.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 13.500 125.0 Spud Mud 10.20 151.0 7.8 250 4.0 3.700 70.0 2.340 114.8 5.000 70.0 4.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep .Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6321.5 11130 8725.75 9618 6321.5 11130 RPD MWD030 OHMM 3.17 31.45 7.50141 9520 6321.5 11081 RPM MWD030 OHMM 3 32.04 7.17046 9520 6321.5 11081 RPS MWD030 OHMM 2.81 26.15 6.84739 9520 6321.5 11081 RPX MWD030 OHMM 2.6 23.85 6.2969 9520 6321.5 11081 FET MWD030 HOUR 0.17 32.92 1.19754 9520 6321.5 11081 GR MWD030 API 29.48 130.84 77.3601 9519 6329.5 11088.5 ROP MWD030 FT/H 3.32 1783.28 178.786 9520 6370.5 11130 First Reading For Entire File..........6321.5 Last Reading For Entire File...........11130 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 11081.5 14186.0 RPX 11081.5 14186.0 RPD 11081.5 14186.0 RPS 11081.5 14186.0 RPM 11081.5 14186.0 GR 11089.0 14193.5 ROP 11130.5 14230.0 LOG HEADER DATA DATE LOGGED: 13-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14230.0 TOP LOG INTERVAL (FT) 11130.0 BOTTOM LOG INTERVAL (FT) 14230.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 73.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 11113.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): LSND 9.40 60.0 9.0 550 3.5 1.850 74.0 1.070 132.8 1.900 74.0 1.450 74.0 REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11081.5 14230 12655.8 6298 11081.5 14230 RPD MWD040 OHMM 1.85 1856.28 12.9307 6210 11081.5 14186 RPM MWD040 OHMM 1.68 446.38 4.21816 6210 11081.5 14186 RPS MWD040 OHMM 1.56 292.39 3.78831 6210 11081.5 14186 RPX MWD040 OHMM 1.45 208.31 3.57529 6210 11081.5 14186 FET MWD040 HOUR 0.17 228.61 4.60121 6210 11081.5 14186 GR MWD040 API 40.62 178.59 99.0635 6210 11089 14193.5 ROP MWD040 FT/H 3.87 855.58 103.629 6200 11130.5 14230 First Reading For Entire File..........11081.5 Last Reading For Entire File...........14230 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 s RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 14186.5 17681.0 RPS 14186.5 17681.0 RPM 14186.5 17681.0 RPX 14186.5 17681.0 RPD 14186.5 17681.0 GR 14194.0 17689.0 ROP 14230.5 17726.0 LOG HEADER DATA DATE LOGGED: 17-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17726.0 TOP LOG INTERVAL (FT) 14230.0 BOTTOM LOG INTERVAL (FT) 17726.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.8 MAXIMUM ANGLE: 77.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 11113.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down LSND 10.00 64.0 8.8 800 2.8 1.800 81.0 1.040 145.4 .900 81.0 1.800 81.0 Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14186.5 17726 15956.3 7080 14186.5 17726 RPD MWD050 OHMM 2.53 2000 16.3478 6990 14186.5 17681 RPM MWD050 OHMM 2.15 17 38.76 12.3778 6990 14186.5 17681 RPS MWD050 OHMM 1.48 22.62 5.50682 6990 14186.5 17681 RPX MWD050 OHMM 1.2 12.27 4.28844 6990 14186.5 17681 FET MWD050 HOUR 0.23 26.31 1.26825 6990 14186.5 17681 GR MWD050 API 51.29 4 23.15 163.18 6991 14194 17689 ROP MWD050 FT/H 1.45 4 23.27 108.691 6992 14230.5 17726 First Reading For Entire File..........14186.5 Last Reading For Entire File...........17726 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH L J NCNT 17642.5 17900.0 NPHI 17642.5 17900.0 FONT 17642.5 17900.0 DRHO 17656.0 17900.0 PEF 17656.0 17900.0 RHOB 17656.0 17900.0 FET 17681.5 17900.0 RPS 17681.5 17900.0 RPD 17681.5 17900.0 RPM 17681.5 17900.0 GR 17689.5 17900.0 ROP 17726.5 17900.0 LOG HEADER DATA DATE LOGGED: 28-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17900.0 TOP LOG INTERVAL (FT) 17726.0 BOTTOM LOG INTERVAL (FT) 17900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.6 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 CTN COMP THERMAL NEUTRON 10603684 EWR4 Electromag Resis. 4 162742 ALD Azimuth. Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 17659.0 BOREHOLE CONDITIONS • MUD TYPE: Flo-Pro MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 55.0 MUD PH: 8.5 MUD CHLORIDES (PPM} 29000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .210 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .100 153.0 MUD FILTRATE AT MT: .240 68.0 MUD CAKE AT MT: .280 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down • • Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FONT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 RHOB MWD060 G/CM 4 1 68 12 4 DRHO MWD060 G/CM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 FET MWD060 HOUR 4 1 68 32 9 GR MWD060 API 4 1 68 36 10 PEF MWD060 BARN 4 1 68 40 11 ROP MWD060 FT/H 4 1 68 44 12 NPHI MWD060 PU-S 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 17642.5 17900 17771.3 516 17642.5 17900 FCNT MWD060 CNTS 113.42 820.11 404.738 516 17642.5 17900 NCNT MWD060 CNTS 14492.1 31821.3 23238.9 516 17642.5 17900 RHOB MWD060 G/CM 0.05 4.303 2.1226 489 17656 17900 DRHO MWD060 G/CM -4.064 1.667 -0.296008 489 17656 17900 RPD MWD060 OHMM 0.97 2000 192.254 438 17681.5 17900 RPM MWD060 OHMM 0.37 1768.03 104.879 438 17681.5 17900 RPS MWD060 OHMM 0.37 2000 15.184 438 17681.5 17900 FET MWD060 HOUR 0.82 253.02 54.7879 438 17681.5 17900 GR MWD060 API 32.33 79.18 60.0646 422 17689.5 17900 PEF MWD060 BARN 1.03 14.96 4.50327 489 17656 17900 ROP MWD060 FT/H 1.84 219.48 59.663 348 17726.5 17900 NPHI MWD060 PU-S 17.83 56.97 31.205 516 17642.5 17900 First Reading For Entire File..........17642 Last Reading For Entire File...........17900 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Nuntber...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 • Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 17847.0 RPS 17847.0 RPM 17847.0 PEF 17900.5 FET 17900.5 RPX 17900.5 ROP 17900.5 NPHI 17900.5 GR 17900.5 NCNT 17900.5 DRHO 17900.5 FONT 17900.5 RHOB 17900.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 18655.0 18655.0 18655.0 18636.0 18655.0 18655.0 18708.0 18620.5 18648.0 18620.5 18635.5 18620.5 18635.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 04-JAN-06 Insite 66.37 Memory 18708.0 17900.0 18708.0 85.9 95.7 TOOL NUMBER 203301 116332 159436 183652 6.750 17659.0 Flo-Pro 9.20 40.0 9.2 21000 3.8 .190 76.0 .100 158.0 .230 76.0 .380 76.0 • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD080 CNTS 4 1 68 4 2 NCNT MWD080 CNTS 4 1 68 8 3 RHOB MWD080 G/CM 4 1 68 12 4 DRHO MWD080 G/CM 4 1 68 16 5 RPD MWD080 OHMM 4 1 68 20 6 RPM MWD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPX MWD080 OHMM 4 1 68 32 9 FET MWD080 HOUR 4 1 68 36 10 GR MWD080 API 4 1 68 40 11 PEF MWD080 BARN 4 1 68 44 12 ROP MWD080 FT/H 4 1 68 48 13 NPHI MWD080 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 17847 18708 18277.5 1723 17847 18708 FCNT MWD080 CNTS 205.4 6 87.88 442.498 1441 17900.5 18620.5 NCNT MWD080 CNTS 18301.9 31 197.8 24773.3 1441 17900.5 18620.5 RHOB MWD080 G/CM 2.135 2.904 2.40721 1471 17900.5 18635.5 DRHO MWD080 G/CM -0.188 0.661 0.0784337 1471 17900.5 18635.5 RPD MWD080 OHMM 2.52 1520.33 10.6978 1615 17847 18655 RPM MWD080 OHMM 2.3 17.78 6.77054 1615 17847 18655 RPS MWD080 OHMM 2.41 17.48 6.28893 1616 17847 18655 RPX MWD080 OHMM 2.15 14.12 5.5362 1510 17900.5 18655 FET MWD080 HOUR 0.41 149.9 3.13838 1510 17900.5 18655 GR MWD080 API 44.27 143.48 74.0119 1496 17900.5 18648 PEF MWD080 BARN 1.28 7.13 2.54618 1472 17900.5 18636 ROP MWD080 FT/H 0.23 488.68 98.082 1616 17900.5 18708 NPHI MWD080 PU-S 17.92 46.23 26.8216 1441 17900.5 18620.5 First Reading For Entire File..........17847 Last Reading For Entire File...........18708 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Bate of Generation.......06/04/04 Maximum Physical Record..65535 File Type. . ...............LO Next File Name...........STSLIB.008 • Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 18621.0 NCNT 18621.0 FCNT 18621.0 DRHO 18636.0 RHOB 18636.0 PEF 18639.0 GR 18648.5 FET 18655.5 RPD 18655.5 RPM 18655.5 RPS 18655.5 RPX 18658.5 ROP 18708.5 S LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TXPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD STOP DEPTH 20995.0 20995.0 20995.0 21009.5 21009.5 21009.5 21022.5 21029.5 21029.5 21029.5 21029.5 21029.5 21081.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 09-JAN-06 Insite 66.37 Memory 21081.0 18708.0 21081.0 83.2 91.7 TOOL NUMBER 178505 116332 159439 183652 6.750 17659.0 Flo-Pro 9.20 48.0 MUD PH: ~ 9.9 MUD CHLORIDES (PPM): 11500 FLUID LOSS (C3): 7.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .340 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .170 142.7 MUD FILTRATE AT MT: .300 70.0 MUD CAKE AT MT: .580 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD090 CNTS 4 1 68 4 2 NCNT MWD090 CNTS 4 1 68 8 3 RHOB MWD090 G/CM 4 1 68 12 4 DRHO MWD090 G/CM 4 1 68 16 5 RPD MWD090 OHMM 4 1 68 20 6 RPM MWD090 OHMM 4 1 68 24 7 RPS MWD090 OHMM 4 1 68 28 8 RPX MWD090 OHMM 4 1 68 32 9 FET MWD090 HOUR 4 1 68 36 10 GR MWD090 API 4 1 68 40 11 PEF MWD090 BARN 4 1 68 44 12 ROP MWD090 FT/H 4 1 68 48 13 NPHI MWD090 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 18621 21081 19851 4921 18621 21081 FCNT MWD090 CNTS 259.6 12 18.45 426.112 4.749 18621 20995 NCNT MWD090 CNTS 19893.7 38 103.4 25113 4749 18621 20995 RHOB MWD090 G/CM 2.217 3.02 2.50122 4748 18636 21009.5 DRHO MWD090 G/CM -0.426 0.246 0.0534507 4748 18636 21009.5 RPD MWD090 OHMM 3.51 11 78.41 14.0026 4749 18655.5 21029.5 RPM MWD090 OHMM 3.33 42.84 12.5367 4749 18655.5 21029.5 RPS MWD090 OHMM 3.08 26.44 11.4183 4749 18655.5 21029.5 RPX MWD090 OHMM 2.83 21.73 9.53598 4743 18658.5 21029.5 FET MWD090 HOUR 0.31 66.43 2.5675 4749 18655.5 21029.5 GR MWD090 API 37.64 1 51.08 65.5389 4749 18648.5 21022.5 PEF MWD090 BARN 1.31 7.11 3.64564 4742 18639 21009.5 ROP MWD090 FT/H 0.84 3 26.03 111.173 4746 18708.5 21081 NPHI MWD090 PU-S 13.38 36.99 28.283 4749 18621 20995 First Reading For Entire File.......... 18621 Last Reading For Entire File........... 21081 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/04/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................ST5 LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/04/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library. • Scientific Technical Services Scientific Technical Services End Of LIS File
