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206-001
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-14A KUPARUK RIV UNIT 1C-14A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-14A 50-029-22861-01-00 206-001-0 W SPT 6245 2060010 1561 2528 2529 2533 2538 333 455 416 395 4YRTST P Matt Herrera 5/17/2022 MIT-IA Performed to 1800 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-14A Inspection Date: Tubing OA Packer Depth 580 1800 1730 1720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518151657 BBL Pumped:1 BBL Returned:1 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 14:03:11 -08'00' • MEMORANDA State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Regg P.I.Supervisor e510-11)8 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-14A FROM: Austin McLeod KUPARUK RIV UNIT IC-14A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-14A API Well Number 50-029-22861-01-00 Inspector Name: Austin McLeod Permit Number: 206-001-0 Inspection Date: 5/13/2018 - Insp Num: mitSAM180514080230 Rel Insp Num: _ Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T Well 1C-14A ' Type Inj W -TVD 6245 Tubing 2383 - 2384 - 2386 - 2384- PTD 2060010 - Type Test, SPT Test psi 1561 - IA 1285 1880 - 1845 - 1840 - BBL Pumped: j 0.9 "BBL Returned: 0.8 " OA 332 391 371- 364 Interval 4YRTST jP/F 1 P ✓ Notes: MIT-IA -- it SCANNED JUN 0 12018 Wednesday,May 16,2018 Page 1 of 1 MEMORANDUM • TO: Jim Regg ~ r/~~=~,1~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ]C-14A KUPARUK RIV UNIT 1C-14A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 1C-14A API Well Number: 50-029-22861-01-00 Insp Num: mitJCr100523180226 Permit Number: 206-001-0 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 P.T.D 1C-]4A 2060010 _ _ Type h~l~~. ~TypeTest W T D ~ 6245 / IA SPT I -~ i Test pst I 1561 i QA 479 314 2440 492 2380 2360 439 409 Interval 4YRTST P~F P / TUbing 1719 1715 1719 i~ 171 ~ Notes: 3.6 bbls pumped for test. No problems witnessed. / Tuesday, May 25; 2010 Page 1 of 1 ~ ~ ~, .~ #~ ~. xi. . • !~' v ~ r s` ,~ 1. yp~~..~_.,. y :~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • ConocoPhillips Alaska CJ RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk'/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM /TIFF LIS gp 1 Hardcopy Print, Petrotechnical Data Center, M633 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRONIKRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 _._~ ..._ Electronic Anchorage, Alaska 99501-3510 LIS ~~ ~.Q~ uzc ~o~ _~ ~ ~9a3a .~- ~ ~_~ 19~3~ ao~-o~~ l 9 ~3y v s C 2o~-v~~ ~o~s- loaf ~~,~v~l /~b35- ~ ~i~3 ~ ~~ ID DEC ~ 3 20019 ~~laska Dil ~ ~~~ Cons. ~ar~~ission ,Anrhor~g~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED JAN 0 7 2009 Alaska Oil 8~ Gas Cons. Commission Anchorage Jan 2, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ~~~f~~~ JAi~ :~ 200 ~~~ ~~ Dear Mr. Maunder: /~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Similarly, It was noticed In August 2007 that 5 wells on DS 1 C had similar cement and sealant treatments. These wells were inadvertently omitted from the 10-404 submitted at that time for other work being performed. These wells are included here. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Kl ' _ ConocoPhillips Well Integrity Supervisor ~- s ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) __ Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbfs ft al 1F-09 183-104 11" na 11" na 1.70 12/7/2008 1 F-14 183-146 18" na 18" na 2.00 12/7/2008 1 F-17 196-047 8" na 8" na 1.70 12/7/2008 1 F-19 196-052 8" na 8" na 1.70 12/7/2008 1 F-20 196-053 6" na 6" na 1.00 12/7/2008 1C-111 201-128 5' 9" 0.50 18" 8/27/2007 21.00 8/29/2007 1 C-13 198-011 32' 10" 4.00 18" 8/27/2007 17.00 8/29/2007 1 C-14 1206-001 14' 6" 2.00 18" 8/27/2007 9.00 8!29/2007 1 C-21 205-034 38' 10" 4.00 18" 8/27/2007 8.60 8/29/2007 1 C-23 199-034 10' 10" 1.50 18" 8/27/2007 23.00 8/29/2007 a3 ~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2060010 Well Name/No. KUPARUK RIV UNIT 1C-14A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22861-01-00 MD 14157 TVD 6592 Completion Date 11/23/2006 Completion Status 1-OIL Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey 10701 14157 Open 12/8/2006 Rpt Directional Survey 10701 14157 Open 12/8/2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~/ N Chips Received? ~. Formation Tops ~ / N Analysis Y~ Received? - - -- __ ' -_ Comments: n, Q , \ f ~ C ~ ~4~~ I f 1 ~+ a 1'~' Y' ol-.Lu JU~J~ -------- - 4 ~ --- Compliance Reviewed By: -- - ---- r~ --- Date: ~~_ V (_. MEMORANDUM TO: Jim Regg ~~~ ~~~.`~7 P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-14A KUPARUK RIV UNIT 1C-14A Src: Inspector NON-CONFIDENTIAL 2,ob-ool Reviewed By: P.I. Suprv,~ Comm Well Name: KUPARUK RIV UNIT 1C-14A Insp Num: mitCS070603141333 Rel Insp Num: API Well Number: 50-029-22861-01-00 Permit Number: 206-001-0 Inspector Name: Chuck Scheve Inspection Date: 6/2/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Ic-IaA Type Inj. v' TVD 6259 IA soo ztso zloo zloo P.T.D zo6oolo TypeTest SPT Test psi 1564.75 pA 3zo ~ aso aao azo Interval ~IT'~- P/F P Tubing Iooo Iooo Iooo Iooo Notes' Well converted from a producer to an injector 5/14/07. Wednesday, June O6, 2007 Page 1 of 1 ~ RECEIVED STATE OF ALASKA `~~"~~ ~ 5 ~QQ~ ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska all & 183 COWS, a~33~mISS1011 REPORT OF SUNDRY WELL OPERATIONS anCnnrana 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Oil 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: ConocoPhillips Alaska, IrtC. Development ^ Exploratory. ^ 206-001 / 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22861-01 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 103' 1 C-14A 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit ~f)yL Z~Z'7F2 ~ -/Z.o 7 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 1415T feet , true vertical 6592' feet Plugs (measured) Effective Depth measured. 14157 feet Junk (measured) true vertical 6592 feet 2-3/8" Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 7189' 9-5/8" 7292' 4527 PRODUCTION 10400' 7" 10503' 6409` LINER TOP-ABAI 450' 4-1/2" 10750' 658T WINDOW S/T 1' 4-1/2" 10743' Perforation depth: Measured depth: 11999-12389; 12392-1 4123 true vertical depth: 6576-6556; 6556-6589 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10336' MD. Packers &SSSV (type & measured depth) no packer SSSV= SSSV SSSV= 1830' 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 397 1 208 943 1117 280 Subsequent to operation 3635. ~ 404 978 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAGQ '' GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Ni,4 if C.O. exempt: 307-090 contact Bob Christensen /Bob .Buchholz Printed Name Robert D. hristens n Title .Production Engineering Technician Signature Phone 659-7535 Date. ~ , v ~ ~~~`~~N 7 ~ 2007 ~ ~ ~ G• ~Z-d7 Form 10-404 Revised 04/2004 n [~ ~ ~ ~ n' ~ ~ ~ (~ Submit Origin~alyf~/~ 7 1 C-14A DESCRIPTION OF WORK COMPLEl'ED SUMMARY Date Event Summary 05/13/07 Commenced Water Injection a i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein~admin.state.ak.us; Jim Re~~admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCG REP: ConocoPhiliips Alaska Inc. Kuparuk 1 KRU / 1 C-14A 62/07 Greenwood /Ives /Bates Chuck Scheve Packer Pretest initial 15 Min. 30 Min. Well 1 C-14A T In'. W TVD 6,259' Tubi 1000 1000 1000 1000 Interval I P.T.D. 2060010 T test P Test 1564.75 Casi 300 2150 2100 2100 PJF P Notes: Converted from prod to injection. BOI 5/14!07 OA 320 480 440 420 Well T In'. TVD Tu ' Interval P.T.D. T test Test - P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Casi P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test C P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test Casi P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Casi P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Intemat Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water 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-14A 06-02-07.x1s ~y~T~~+ ~y AAry~~ ~ ®1~ A~`i`1`~~7T 333 W 7th AVENUE, SUITE 700 ®iss7~~~L~1li®ld ~!®l~~r~~7"~~7'`I®17 ANCHORAGE, ALASKA 99501-3539 PHONE {907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 C-14A Sundry Number: 307-090 Dear Mr. Christensen: 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 ~it~s 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 March, 2007 Encl. Sincerely, • • Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 ConocaPh i I I i ps Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 March 10, 2007 ~ c ^ E ~"~ n Tom Maunder, P.E. MAR 1 3 2007 Senior Petroleum Engineer Alaska Oil ~ Gas Cons. Commission State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk well 1C-14A (PTD 206-001) from Production to WAG Injection service. Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1 C-14A (PTD 206-001). If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, Robert D. Christensen Attachments u STATE OF ALASKA +1+'~ MAR ~ 3 ALASKA OIL AND GAS CONSERVATION COMMISSION 2Q~T APPLICATION FOR SUNDRY APPROVAL Alaska Oit & Gas Cons Omission 20 AAC 25.280 Anchora 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Producer to Chan e a roved ro ram Injector g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 206-001 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22861-01 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 ^~ 1C-14A , 9. Property Designation: ~ /~, 0 ~ L ZgZT ~ ~~~ ~ 10. KB Elevation (ft): 11. Field/Pool(s): ~ Kuparuk River Unit ; ~ RKB 103' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14157' - 6592' - 14157' 6592' Casing Length Size MD ND Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 7189' 9-5/8" 7292' 4527 PRODUCTION 10400' 7" 10503' 6409' LINER TOP-ABANDONED LE 450' 4-1 /2" 10750' 6587' WINDOW S!f 1' 4-1/2" 10743' 6591' Slotted Liner 3876' 2-3/8" 14157 6592' ~ ~~r cs~~ /~•n Perforation Depth MD (ft): ~~,t..e~ Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ~b 11999-12389; 12392-14123 3 ~'~ 6576-6556; 6556-6589 3-1 /2" L-80 10336' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= SSSV SSSV= 1830' 13. Attachments: Description Summary of Proposal Q 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: April 15, 2007 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 Nam R Bert D. Chr' tenSen Title: Production Engineering Technician Signature r Phone 659-7535 Date 3 ID ~ ~- 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.~,O~~tA.C~S~~rcC~r~C'v.1~~cS~yC~ ~t~c`~MC~'CC~.~JC~S ~C).~lrc: STG~U~~\Z.~~. Subsequent Form Required: 1..t~y S ~ ~~~ ~ 5 1~~7 APPROVED BY ~ /~ ~~ ~ ~ Approved by: OMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ': i Submit in Duplicate • 1 C-14A DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin WAG Injection service in Kuparuk Well 1C-14A post sidetrack pre-production. In addition to accessing a previously upswept area, 1C- 14Awill provide Water and MI support for Kuparuk C sands to offset producers 1C-16 & 23. The 9-5/8" Surface casing (7292' and / 4525' tvd) was cemented with 612 sx AS III LW, 348 sx Class 'G', and 60 sx AS I. The 7" Production casing (10503' and / 6409' tvd) was cemented with 130 sx Class 'G'. The 4-1/2" Liner Top (10745' and / 6593' tvd) was cemented with 130 sx Class 'G'. The 2-3/8" Slotted Liner (14157' and / 6592' tvd) was cemented with 24 sx Class 'G'. The Cement Bond Log (01/02/99) performed on the original w Ilbore (114) indicates uniform cement bond from 6369' tvd (10450' md) to 6648' tvd (10867' and}. The C sand Sidetrack Window top is located @ 10742" and / 6591' tvd. The top of Kuparuk C sand was found at 10744' and / 6592' tvd. The injection tubing/casing annulus is isolated via a Baker ZXP Liner Top Packer located @ 10300' and / 6259' tvd. ore: // ei~+,: /7~~d q~s G ~ie-~'ocPvice~ ,'aye cfo~', ~ ~~, >~Qt o,,$, ~o e P 7C~ le$vrs~~a~ vJ°e~c~~.a, ,S Coesisrrrr ~vr'r~j P/'roi' G„~~j~'Sf~c~, Gi'PP~'ova /f, ~ 3/~~e7 10700 ;1~~~~ Iw ~ 10800 • `` x C~a~sc~~~~~i~1~~s A~a~~c~x ~~>~ a TUBING API: 500292281 (0-1o33s, SSSV T e: TRDP OD:3.500, ~•~~•>.•r. Annular Fluid: ID:2.992) •••••••~: Reference Log: 36.6' RKB ".. Last Ta Last Taa Date: PRODUCTION SLOTTED LINER PACKER (10281-10285, OD:2.740) PIPE (10292-11999, OD:2.375) Perf _ _ (11999-12389) _ _ Perf (12392-14123) - .,, • KRU 1 C-14A LaSL VV/V: KBV Kea50n: No[e On L I Y Reduced Pressure Ratin Ref Lo Date: Last U date: 12!10/2006 TD: 14157 ttKB Max Hole An le: 97 de 10995 ~q~+ it V'.M'~.~' iii:'?<''i`'`isi;iiisii;} i;isiasi?'i2ii``i;ii•,`:i%iiii% i~i` 'i?;i ~ isisi'i'isiasisiis asi;k si;j::asi%;;;isSi2s'iiiiiii'. Size To Bottom TVD Wt Grade Thread 16.000 0 121 121 62.58 H-40 9.625 0 7292 4525 40.00 L-80 7.000 0 10503 6409 26.00 L-80 4.500 10300 10750 6596 12.60 L-80 4.500 10742 743 10 6591 0.00 ................. ..................... a~ ........................ ............... . ..................... ..................................... Size To Bottom TVD Wt Grade Thread 2.375 10281 12390 6556 4.70 L-80 STL 2.375 12390 14157 14157 4.70 L-80 STL Interval TVD Zone Status Ft SPF Date T e Comment 11999 - 12389 6576 - 6556 390 32 11/22/2006 SLOTS Akernatin solid/slotted i e 12392 - 14123 6556 - 6589 1731 32 11/22/2006 SLOTS Akernatin solid/slotted i e ..................... ............................. ......................................... .... ................................................................................................:.:::::: : St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3835 2588 CAMCO KBMM GLV 1.0 BK 0.188 1383 11/30/200 2 6523 4094 CAMCO KBMM OV 1.0 BK 0.250 0 11/30/200 3 8478 5195 CAMCO KBMM DMY 1.0 BK 0.000 0 3/8/1998 4 9634 5851 CAMCO KBMM DMY 1.0 BK 0.000 0 3/8/1998 5 10226 6206 CAMCO MMM DMY 1.5 RK 0.000 0 3/8/1998 ?~t~ >: ~~ ~<:>. ill .~>: ..;:::Y:: ':'.' ~~......+~±C~ : :.:. ':: '.:: :: MR~~'~~ '::.. ::::.i . i ~7!1~. ~rl i~al<:~: 9~8::><::<>«:<:::>?:>:::>;>:>::>::::<:::>:::>:::>:::>::>::>:<:>:<:::: De th TVD T e Descri tion ID 1830 1474 SSSV CAMCO TRDP-4E 2.812 10272 6239 NIP CAMCO'D' NIPPLE w/NO GO PROFILE 2.750 10300 6259. PACKER BAKER ZXP LINER TOP PACKER 4.438 10311 6267 SEAL BAKER LOCATOR/SEAL ASSEMBLY 3.000 10314 6269 HANGER BAKER'HMC' LINER HANGER 4.438 10321 6274 SBE SEAL BORE EXTENSION 4.000 10337 6286 TTL TUBING TAIL 2.992 .~.r.+~....{.~.................... ~:SJ~I:FQT2:: . M '~ : ................ ...... . ....................... ~'~'::~ ~ -[~ '~ ~a '~' .. ...... ..... ... f.. ...2.................................................................................................................................................. ~~. .....~~~fi'.'.~~~~.if~~:::~1:[.1~~~:iL%~~{':~i::'::::::::::::!:i::i::::::i::::::i::::i::::::i:::C:C::::i::ii::::::''::::::i:::::::i ::::::::::::::~ ........ ............................................................................................................................................ De th TVD T e Descri tion ID 10281 6245 PACKER BTT 35'KB' LINER TOP PACKER 1-810 10285 6248 LOCATOR LOCATOR/SEAL ASSEMBLY- SPACED 1' ABOVE DEPLOYMENT SLEEVE 1.800 10286 6249 De to SLV BTT LINER DEPLOYMENT SLEEVE 2.250 10292 6253 PIPE SOLID PIPE LINER w/PUP, COLLAR 1.995 11572 6604 O-RING O-RING SUB 1.920 12389 6556 SHOE STEEL GUIDE SHOE, CRAYLOA TYPE 1.920 12390 6556 De to SLV 3" BAKER DEPLOYMENT SLEEVE 2.270 12391 6556 XO CROSSOVER BOX 1.920 14123 6589 O-RING 2-3/8" O-RING SUB 1.000 14156 6591 SHOE UNIQUE SELF-ORIENTING GUIDE SHOE 1.995 ~12/10/2006~ THERE IS A REDUCED PRESSURE RATING OF THE LTP @ 2500 psi, IF PRESSURE IS EVER (APPLIED TO THE 2-3/8" x 3-1l2" LINER LAP MECHANICAL INTEGRITY REPORT 98- old ~~ ~ -~O ~ GPUD DATE: z~~IS~95 OPER ~ FIELD f~~l ~-R.U RIG RELEASE : - 3~ i'~ ~A `a kLLL NJMBEP. °E$ - , ~ WELL DATA TD:. Io9~da.MD.. b~92 TVD; PBTD: 10$83 MD 669$ TVD ... ~ Casing : ~'~ ~L $~ Shoe : Io5o3 t~ TVD ; DV : ~ -TVD lZ.b'st Liner :.g, Ste'` ~ oo Shoe : to ~ ao 3~' ~a9'~a TVD ; TOP : ~ TVD Tubing : ~'/~' Packer yo oo~ i~ TVD ; Set at 1x336 Hole Size ~,1ZS ~ ~ and 8'12 ~~ ; Perfs ) ob96 to la"~16 MECHANICAL INTEGRITY - PART #I Annulus Press Test: IP ; 15 min ~0 min Convents i irLCHANIC~..L INTEGRITY -PART #2 ~~~~ sv~z~~~~ ciOC~~ c~~~~t, Cement Volumes : Amt. Liner~_; Csg 13o5x DV ~4'~i I2.b# -093 ~ s l~ Jol to cover perms 5x ~ . - ~. z2.9 6'Ig ' .t~4S ~iF ~og~~ . 1o883~x.~31 -r (10980- io98o~x .1~ `t$ + l!1~98a -1ob96.~x. aBoS =~0 SX 3'Iz x ~b~~8 • 0 9~ z c~~~Theoretical TOC . o $a5 51~/c.F' ~ Lit 2 ~ ._.- _ ~ o~6q 6 -- rc ~ 30 - 30 ~ . o~ 8os 1 - 9~ ~~~ ~,.~d ~~ Cement Bond Log (Yes or No) J~f o In AOGCC File ~ ~~~~ ~~-~' CPL Evaluation, zone above perfs CONCLUSIONS Part #1. Part fL: r,.:°'~ j ~ d- ~a ~ ~ v ~e~~ ~~ chi - ~ \R ` .~/ °, c, ~ ~.~ y ~ -~_ ~~I~t~ l`lY1!~~~ ~~ u~_ ~ y, 1 ~ \ ~ 1~~ _~"?1, S CCU t"~Cc_!I\~~ L ~ ~~. tom. ~\~~ t(~~Xi- ~ ~ w$ r~ . a 3~~ ~i \i'f~~c~ ~ Cfi~t~sc.~ ~ ~ mac`-,to ~~, ~s~l~~-c~, ~-4.fc ~_..., ~.t+,cr 1~c~ ApzZ~cssvcs,G\o~~.~:;e~ 1~~1~v~~~.. I ~\''~~ 1 r ~;` ! ~.f,~ .{< eS ~,~~.i l \ (~ ~ -F. f~~i ~~,;~ l,ti.)r.'~ ~ L I ~~~ I I\~~ ~ i ~ l 4~ ~°~ K~ Production Log;.. Type ; Evaluation _ ~--.- , STATE OF ALASKA ~ ,OHO ALASKA AND GAS CONSERVATION COMMISSION / ~~EIVED ~~C 2 8 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG?~3n~F~ E~; ,~ ~,~~ Cons COmmissiort AttCht)rana 1a. Well Status: ®Oil ~ ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.~os zoAAC zs.»° ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ' ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband 11/23/2006 ~•Ob 12. Permit to Drill Number 206-001 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded / • ~ 11/8/2006 - 13. API Number 50-029-22861-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/18/2006. 14. Well Name and Number: Ku aruk 1C-14A ' 1566 FNL, 1139 FWL, SEC. 12, T11 N, R10E, UM Top of Productive Horizon: 1766' FSL, 546' FEL, SEC. 06, T11 N, R11 E, UM 8. KB Elevation (ft): 41' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 3499' FSL, 755' FWL, SEC. 05, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 14157 + 6592 Ft River Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562146. y- 5968672. Zone- ASP4 10. Total Depth (MD+TVD) .14157 + 6592 Ft 16. Property Designation: ADL 028242 • TPI: x- 570609 y- 5972079 Zone- ASP4 Total Depth: x- 571888 y- 5973824 Zone- ASP4 11. Depth where SSSV set 1830' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1465' (Approx.) 21. Logs Run: MWD DIR/GR 7 J~ OF ~//~/ Oi/ 10.7 ,h ' " r..~9'l'7VD ~ /• 2.0'~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTINGDEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRAQE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 121' Surface 121' 24" 9 cu ds Hi h Earl 9-5l8" 40# L-80 Surface 7292' Surface 4525' 12-1 /4'• 612 sx AS III LW, 348 sx'G', 60 sx AS I 7" 26# L-8 rface 105 3' rfac 4 8-1 /2" 130 sx Class ' ' 4-1/2" 12.6# L-80 10300' 6259' 6593' 6-1/8" 130 sx Class'G' 2-3/8" 4.6# L-80 10281' 14157' 6245' 6592' 3" Slotted w/ Bonzai Cmt, 24 sx Class 'G' 10 - 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 10336' 10300' MD TVD MD TVD 11999' - 12389' 6576' - 6556' 12392' - 14123' 6556' - 6589' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 2500' Freeze Protect w/ 22 Bbls of Diesel 26. PRODUCTION TEST Date First Production: December 3, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 12/24/2006 Hours Tested $ PRODUCTION FOR TEST PERIOD OIL-BBL 272 GAS-McF 587 WATER-BBL 408 CHOKE SIZE 176 GAS-OIL RATIO 2,160 FIOW TUbing Press. 261 CaSing PreSSUre 920 CALCULATED 24-HOUR RATE OIL-BBL 816 GAS-MCF 1,762 WATER-BBL 1,224 OIL GRAVITY-API (CORK) 22 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". ':itf None 1~~' ~~ ~'=a Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE /'Y /~ ~ •c? G~~~L 28. GEOLOGIC MARKERS 29. TION TESTS Include and briefly su marize test results. List intervals tested, NnMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". KOP (Kuparuk C2) 10744' 6592' None Base C2 /Top C1 10813' 6635' Top C1 /Base C2 (Inverted) 10996' 6639' Top C2 /Base C3 (Inverted) 11770' 6595' Top C3 /Base C4 (Inverted) 12045' 6571' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. I / Signed Terrie Hubble Title Technical Assistant Date `~! ~/~P Kuparuk 1 C-14A 206-001 Prepared By Name/Number. Terrie Hubble, 564-4628 Drilling Engineer: Ares Worfhin on, 564-4102 Well Number Permit No. / A royal No. ~ INSTRUCTIONS Gewew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this wel! 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: list all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Start: 10/25/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date ~ ~ NPT i Phase rom - To Hours as ode -_ __ _ _ - 11/5/2006 00:00 - 01:00 1.00 MOB P PRE 01:00 - 01:15 0.25 MOB P PRE 01:15 - 02:15 I 1.00 I MOB I P I I PRE 02:15 - 03:45 1.50 MOB P PRE 03:45 - 04:00 0.25 MOB P PRE 04:00 - 15:00 11.00 MOB P PRE 17:105 - 18:00 ~ 0.75 MOB P PRE 18:00 - 00:00 I 6.001 MOB I P I I PRE 11/6/2006 ~ 00:00 - 03:15 ~ 3.25 ~ BOPSUFj P ~ ~ PRE 03:15 - 07:00 I 3.75 ~ BOPSUp P PRE 07:00 - 10:00 3.00 BOPSU P PRE 10:00 - 19:00 9.00 BOPSU P PRE 19:00 - 19:30 I 0.501 BOPSUR P I I PRE 19:30 - 23:00 3.50 BOPSU P PRE 23:00 - 00:00 1.00 BOPSU P PRE 11/7/2006 100:00 - 06:00 I 6.001 BOPSUR P I I PRE Page 1 of 16 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations Make ready to move rig off of WOA Z-01a Held PJSM on moving off of well, Assigned task and confirmed communication ops, defined hazards and mitigated same Move off well and drove to the edge of Z-Pad and set down in preparation of removing CT reel from reel house Remove reel from house Safety Meeting with crew and BP Security Mobilise rig to Kupuark 1 C-14A. AOGCC notified for pending BOP test. On location at 1500 hrs. Pre-pad inspection completed with pad operator. Waiting for small) amount of dirt work to be completed before moving over well. Leveled pad around wellhead Moved rig over well and set down Accept rig at 18:00 hrs 11-5-2006 NU BOP's Change out ram blocks to 2" and 2-3/8" -+PU 2"CT sppol and placed in the reel houue. Install bulk head and megged line Finish NU BOP's. Tried to shell test and found a leak Shell test to 4000 psi. Called DSO to open SSV and bleed down SSSV hydraulic and close same Service MV, SV and choke Held PJSM on PU & RU to pull BPV. (Note FMC wellhand was required to pull the valve. Conoco will not pull BPV's through a BOP stack. Whoever's wellhead it is then that hand needs to pull the BVP) After pulling BPV the well flowed 15 bbls of diesel through the closed MV. May present some problems will have to wait and see. RD Conoco's lubricator. NU double 2-1/16" 5K valves on lower TOT double gate which is needed to monitor WHP during pressure deployments. In doing so found a piece of cement laying inside BOP stack. Pressure test BOP stack. 250psi low 4000psi high 5 min each. AOGCC rep. John Crisp has wavied witnessing test. Initial test not holding. Review closing procedures for WMK valves. Have grease crew service valves. Work valves and close tight. Retest, leaking still but appears to be with rig equipment. Regrease all stack valves. Isolate all valves and test lower 2" combi's. Good test ,tree valves holding. Upper 2" combi's leaking, work through that issue. Tested H2S and explosive gas alarms. Held PJSM on way forward and mitigated the hazards associated with said harazds Changed out bails, PU and stab pack off on well and change out lower brass. Work on SLB computer, unable to turn chains in injector head. Stab injector and pin. PU injector and make ready to pull 2" CT across pipe shed Loaded CT with SW Vol CT = 39.2 bbls PU 5-1/2" lubricator and stand in derrick Slack Management. Install CTC and rev circulated SW down CT RU CT cutter and cut off 38 ft of 2" CT. Dress wire. .Looking for required cross-over of Nordics. Installed dimple connector and pull tested to 36k Cir. CT prior to reheading. Beheading CTC and UOC. Printed: 11/272006 10:32:45 AM BP EXPLORATION Page 2 of 16 Operations Summary. Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~ Hours ~ Task Code ( NPT ? -. 11 /7/2006 06:00 - 10:50 4.83 ~ STW H I P P 10:50 - 13:00 2.171 STWHIP P Spud Date: 10/25/2006 Start: 10/25/2006 End: 11 /23/2006 Rig Release: 11 /23/2006 Rig Number: Phase Description of Operations WEXIT Pressure test lubricator to 1500psU5min. PU BHA and practice Pressure Deploying it. Found out we didn't have all the 7" SLB lubricator needed due to recent contract revisions. Had to rob 2' section off bottom of 4" BHA lubricator. (ordered out a 5' section of lubricator and it will stay with rig) Good learning experiences for all crews members that they will need later. WEXIT RIH to 1000' open EDC and open SSSV. Continue RIH slowly past SSSV no problem. RIH to 10662 ft 13:00 - 15:30 I 2.501 STWHIPI P 15:30 - 15:50 I 0.331 STWHIPI P 15:50 - 18:30 I 2.671 STWHIPI P 18:30 - 00:00 I 5.50 ! STW HI P I P 11 /8/2006 100:00 - 04:00 I 4.00 I STW H I P I P 04:00 - 06:45 I 2.751 STWHIPI P 06:45 - 07:00 0.25 STWHIP P 07:00 - 08:30 1.50 STWHIP P 08:30 - 09:45 1.25 STWHIP P 09:45 - 11:30 1.75 STWHIP P 11:30 - 13:30 2.00 STWHIP P 13:30 - 15:30 2.00 STWHIP P 15:30 - 18:30 I 3.001 DRILL I P WEXIT SD pumps and well flowing. Diverted wellbore to Tiger tank, increased circulating pressure to 2200 psi with WHP of 700 psi and circulated wellbore clean of hydrocarbons. Circulated at 1.25 bpm maintaining 600 psi on annulus. Circulated 55 bbls. SD and checked flow. OK. Circulated 120 bbl's to TT which 35 bbl was diesel. Tie in from 10,660ft to 10,698 ft with + 6 ft correction WEXIT Closed EDC an started circulating down CT at 1.50 bpm CTP = 2475 psi Up wt = 26.7k Down wt = 7.5 k Vp = 185 bbls Tagged TOWS at 10,743.5 ft wo pumps (pinch pt) WEXIT Tagged pinch point at 10,742.6 ft TOWS at 10,740.5 ft ` Op = 1.49 / 1.48 bpm CTP = 2,834 psi Vp = 184 bbl's Mill window at 6 min/ 0.1 ft as per BOT /BP's SOP Adding sxs biozan to seawater while milling WEXIT Continue to time mill window. 2800 psi fs at 1.49 in/out. DHWOB: 1.5 k# WEXIT Continue displacement to flopro. Continue time milling ahead. Mill to 10760'. Make several reaming passes up and down through window. Dry drift same. W Indow smooth WEXIT Circulate out of hole through choke, following pressure schedule. WEXIT OOH, held PJSM on pressure undeploying BHA, WHP = 600 psi SSSV is closed with 600 psi below WEXIT Pressure undeploying Milling BHA with 600 psi on well WEXIT Test MWD with BHI and make up on catwalk WEXIT Tried to pressure deploy the 2.6 deg bend in the BOP and was unable to to get bit through BOPS. PUH with wireline. Bleed pressure off of well above SSSV. Deployed BHA in the hole. PT lubricatior to 700 psi WEXIT RIH, line out super choke. RIH w/ Op at 0.52/ 0.42 bpm WEXIT Tied-in and corrected +4.5 ft HS TF and RIH and tag bottom at 10760 ft. CTP high at 3800 psi and O~ p = 1.46 / 0.34 bpm. Density = 8.82 / 8.64 ppg. BHP = 4650 psi ECD 14.2PUH above WS to open EDC and try to circulate with reduced circulatring pressure and lower ECD. Circulate several btms up. PROD1 Tagged bottom at 10, 760 ft, set TF to HS Op = 1.53 / 1.55 bpm CTP =3100 / 3300psi Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 C-14 1 C-14 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/25/2006 Rig Release: 11/23/2006 Rig Number: Date I From - To Hours Task Code ~ NPT Phase 11/8/2006 15:30 - 18:30 3.00 DRILL P PROD1 18:30 - 00:00 5.50 DRILL P PROD1 11/9/2006 100:00 - 00:45 ~ 0.751 DRILL P PROD1 00:45 - 03:15 I 2.501 DRILL I P I I PROD1 03:15 - 06:15 I 3.001 DRILL I P I I PROD1 06:15 - 09:00 I 2.751 DRILL I P I I PROD1 09:00 - 12:00 I 3.001 DRILL I N I FLUD I PROD1 12:00 - 12:45 I 0.751 DRILL I P I I PROD1 12:45 - 14:55 I 2.171 DRILL I P I I PROD1 14:55 - 16:10 I 1.251 DRILL I P I I PROD1 Page 3 of 16 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations Vp = 315 bbl Had MI Mud engineer looking at mud for contamination TOWS at 10, 742 ft TOW at 10744.75 RA Marker at 10, 750 ft BOW at 10751.50 ft ROP slow at 9-15 fph. DHWOB: 3.5-4.5k# IA/OA/PVT: 516/370/314 bbls. WHP/BHP/ECD: 55/3798/11.24 PPg• Drill ahead from 10,800'. Very slow ROP. 3100 psi fs at 1.54.in/out. 200-300 DPSI. DHWOB: 2-3k#. IA/OA/PVT: 580/375/313 bbls. WHP/BHP/ECD: 60/3790/11.0 ppg. Angle building smoothly. GR reading 150 to 200 API through much of section. Continue to drill build section. ROP slowly improving. Landed build section at 10875', Estimate 93 deg at bit. Trap 800 psi WHP. Pull through window dry. Circulate out of hole maintaining BHP as per pressure/TVD schedule. Close SSSV and trap 800 psi under same. Pull to surface and tag up. Flow check well. WeII stable. Continue to POH to surface. Hold PJSM during trip. Tag up and space out. Get off well and unstab coil. LD build assembly. Replace kevlar injector sling. Adjust motor to 0.8 deg bend. Bit 1-2. Decide to pick up a rebuild. MU lateral drilling assembly with resistivity tool. RIH with lateral BHA with EDC pressured up on WHP to 800 psi and opn SSSV. Stopped at 442 ft to reboot BHI computer. RIH 10, 660 ft Op 0.5 / 0.24 bpm Acts like yesterday with mud Tied in and corrected +3.5 ft. Cicrculated well to reduce shear rate /shear stress on the mud. Fluid coming up is thick and foamy (gas). MIDF recovered sample for analysis. Lost 31 bbl fluid regaining circulation at 1:1 Retort a mud sample and flound 8% liquid that can not be determine at the rig. W ith a heated up sample the sample has normal parameters and with a flowline temperature circulated up sample, the mud has thickoptic properties i.e. high YP, PV and gels. BHT = 106 deg F. With 60 bbl's recovered up the annulus and 3 hrs circulating, well started to circulated at 1:1 SW I and close EDC prior to going in the open hole. RIH at 150 fph conducting MAD pass from 10,755 ft down to 10,875 ft TF at HS Op = 1.57 / 1.55 bpm CTP = 3,333 psi Added 100 bbl of Flo-Pro to mud system Drilling TDF at 80-90 R Drilled to 10,956 ft Op = 1.52 / 1.54 bpm CTP 3100 / 3300 psi WOB 0.5 to 3.5 klbt ROP = 40-100 fph Vp = 400 bbls, Density = 8.8 ppg ECD 10.9-11.5 ppg (BHCP = 4322 psi) Switch to MP2 repair MPi lost o-ring on liner wash pump. Drilling TF at 80-90-120 R Op = 1.55 / 1.56 bpm Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Page 4 of 16 Legal Well Name: 1C-14 Common Well Name: 1 C-14 Spud Date: 10/25/2006 Event Name: DRILL+COMPLETE Start: 10/25/2006 End: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date .From - To Nours i Task Code ( NPT Phase ~ Description of Operations 11/9/2006 14:55 - 16:10 1.25 DRILL P PROD1 16:10 - 16:23 0.22 DRILL P PROD1 16:23 - 18:00 1.62 DRILL P PROD1 18:00 - 00:00 6.00 DRILL P PROD1 11/10/2006 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 02:15 0.75 DRILL P PROD1 02:15 - 06:20 4.08 DRILL P PROD1 06:20 - 07:34 1.23 DRILL P PROD1 07:34 - 10:25 2.85 DRILL P PROD1 10:25 - 12:30 2.08 DRILL P PROD1 12:30 - 14:45 2.25 DRILL P PROD1 CTP 3100 / 3350 psi WOB 0.5 to 4.0 klbf ROP = 35 fph Vp = 395 bbls, Density = 8.8 ppg ECD 11.3 ppg (BHCP = 4410 psi) Increased Op to 1.66 bpm to clean up bit, balled up with clay / shale starting at 10, 920 ft MD. No fluid loss while drilling W iper trip with 150R TF to clean the low side of the hole Orient TF to HS before RIH. RIH Drilling TF at 135-170 R Op = 1.55 / 1.56 bpm CTP 3100 / 3350 psi WOB= 4.0 klbf ROP = 10 fph Vp = 395 bbls, Density = 8.8 ppg ECD 11.14 ppg (BHCP = 4348 psi) Drilling with negative CTW after wiper trip. WOB from BHI is 4.5k Bit could be plugged as before which could account for the low ROP IA / OA = 620 / 400 psi RU to bleed down to 190 and 0 psi Drill ahead from 10985'. 3100 psi fs at 1.55 in/out. 200-300 dpsi. DHWOB:4-5k#. WHP/BHP/ECD: 51/3910/11.52. IA/OA/PVT: 190/155/395 bbls. Drilling ahead at 97 deg inc. ROP 10-15 FPH. CTW: -1000#. Concerned about weight transfer, but DHWOB is good. Waiting on truck with new mud to pump a 50 bbl pill. Drill ahead from 11,055. 3050 psi fs at 1.54 in/out. 200-250 dpsi. DHWOB: 4-5k#. WHP/BHP/ECD: 48/3822/11.32 ppg. IA/OA/PVT: 260/254/394 bbls. Inc: 94 to 95 deg. Continued slow ROP Circulate 50 bbls new flo vis mud down coil. Check pick up weight several times with new mud in annulus. Maximum improvement was only 500# weight reduction. New mud basically had no effect (3% lubtex, 1 % 776). No improvement in ROP was noted. Continue to drill ahead. Drill ahead from 11,060' TO 11108 ft (11fph) Drilling lateral /gumbo w/ 100LTF. Op = 1.52 / 1.55 psi, CTP = 3,200 psi WOB /CTP = 4.02 klb / 1,1361b ROP= 5-11 fph, Vp = 457 bbl's. Added 50 bbl last night on test POOH following pressure schedule designed for 1C-14. Stopped at 1,600 ft. SD pump and closed SSSV and trapped 650 psi OOH, conventional BHA handling. LD motor and found the DOSTRWD324 had 3 plugged nozzle on the nose and 1 plugged on the gauged. PU New bit and motor set at 0.8 deg bend. No broken insert on HTC bit. Changed O-Ring on LOC and checked DBV. RIH to 200 ft Open EDC Circulating through open EDC while RIH Op = 1.5 / 1.99 bpm at 101 fpm running speed. Fluid not acting as the 2 trips before at 5700 ft RIH and started tossing some cir at 8,700 ft, slowed down at 3 fpm. Cir at 1.5 bpm down CT, gas cut mud at surface, WHP = 200 psi. RIH circulating at 1.5 bpm ,the density and flow out at 1:1 while Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Start: 10/25/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date ; I From - To Hours Task ~, Code NPT ' Phase 11/10/2006 12:30 - 14:45 2.25 DRILL P PRODi 14:45 - 15:50 1.08 DRILL P PRODi 15:50 - 17:30 1.67 DRILL P PROD1 17:30 - 19:00 I 1.501 DRILL I P I I PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 0.00 DRILL P PROD1 11/11/2006 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 03:00 2.25 DRILL P PROD1 03:00 - 06:30 3.501 DRILL P ~ PROD1 06:30 - 08:30 I 2.001 DRILL I P I I PROD1 08:30 - 10:30 ~ 2.001 DRILL P I PROD1 10:30 - 12:24 I 1.901 DRILL I P I I PROD1 12:24 - 13:45 I 1.351 DRILL I P I I PROD1 Page 5 of 16 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations RIH at 9700 tt. Tie in from 10,670 ft to 10,700 ft. SD pump open ckoke and close EDC Corrected +2.5 ft. RIH with HS TF At 10,755 ft Op = 1.5 bpm. RIH at 10 fpm, CTP = 3000 psi at 12 fpm Out Micro Motion Failed, (no rate, density or temperature).Had to cycle pumps to kick start the out MM. RIH circulating at 1.65 bpm at 3300 psi (BHP = 4500 psi. Hole is a little ratty from 11, 015 ft to 11,122 ft Drilling lateral in C1 gumbo w/ 100LTF. Several stalls getting started This motor seems stronger than the old one. Op = 1.60 / 1.62 psi, CTP = 3400/3600 psi. Densit = 8.84 / 8.71 ppg WOB /CTP = 4.02 klb / 1200 Ib, ROP 20-44 fph Vp = 457 bbl's Lost swab in MP1 PU and switch over to MP2 Drill ahead from 11,200. 3500 psi fs at 1.64 in/out. 200-250 dpsi. DHWOB: 1.2k#. WHP/BHP/ECD: 55/3900/11.5 ppg. IA/OA/PVT: 315/323/240 bbls. Begin mud swap to new flo pro (with 3% lubtex & 1 % 776) Wiper trip to window. Hole smooth. Drill ahead from 11,250'. Wiper trip to window. Hole smooth. Drill ahead from 11,375'. 3300 psi fs at 1.63 in/out. 250 dpsi. DHWOB: 2.5-3.5k#. WHP/BHP/ECD: 48/3844/11.37 ppg. IA/OA/PVT: 514/375/443 bbls. Inc: 95 deg. ROP has slowed again. Drill ahead from 11415'. ROP picked up again to 60-80 fph. Then slows down again. Geologists indicate that we are drilling through alternating clay and siltsone intervals. Wiper trip to tie-in SWI and trapped 700 psi while pulling through WS area. Open EDC Having trouble with charge pump. PUH cir at 1.7 bpm to cleanout liner and surge 3-1/2" tubing Tied in at 10, 670 ft to 10,700 ft and corrected +4 ft. Drilling inverted lateral section towards upper section C2 Op = 1.55 / 1.56 bpm ,CTP= 3,100 / 3,350 psi; Density = 8.86 / 8.7 pP9 BHP's 4,015 / 4,508 psi ECD 11.89 ppg; WHP = 50-100 psi WOB / CTW = 700 / -0 Ibf; ROP 62 - 120 fph to start Vp = 426 bbl's Adjusted pit volum in preparation of the 75 bbl of new mud coming from MI Deadhorse Vp = 366 bbl at 10:00 hrs Drilling inverted lateral section towards upper section C2 loer section C3 Op = 1.58 / 1.58 bpm ,CTP= 3,100 / 3,497 psi; Density = 8.86 / 8.7 PP9 BHP's 4,015 / 4,860 psi ECD 11.62 ppg; WHP = 50 psi WOB / CTW = 1.5 / -Ibf; ROP 20 fph to start ROP slowed down again Mud is being aired up, added some diesel to surface to break out air Wiper trip after drillling 150 ft Started new 8.7 ppg Flo-Pro w/ 1 %Lube Tech and 3% Lube 776 down CT at 11,200 ft while RIH Down CTW = 4,100 LBF at 14.1 fpm Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Spud Date: 10/25/2006 Event Name: DRILL+COMPLETE Start: 10/25/2006 End: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours ' Task ', Code ~ NPT ~, Phase Description of Operations 11/11/2006 12:24 - 13:45 1.35 DRILL P PROD1 Up CTW = 24,800 LBF 13:45 - 14:20 0.58 DRILL P PROD1 Drilling inverted lateral section towards upper section C2 lower 14:20 - 14:25 I 0.081 DRILL I P I I PROD1 14:25 - 17:15 I 2.831 DRILL I P I I PROD1 17:15 - 19:30 I 2.251 DRILL I P I I PROD1 19:30 - 19:45 0.25 DRILL N PROD1 19:45 - 22:00 2.25 DRILL P PRODi 22:00 - 22:30 0.50 DRILL P PRODi 22:30 - 00:00 1.50 DRILL P PROD1 11/12/2006 100:00 - 01:30 I 1.501 DRILL I P I PROD1 01:30 - 02:45 1.25 DRILL P PROD1 02:45 - 03:15 0.50 DRILL P PROD1 03:15 - 04:00 0.75 DRILL P PROD? 04:00 - 06:00 2.00 DRILL P PRODi 06:00 - 07:15 I 1.251 DRILL I P PROD1 07:15 - 08:55 I 1.671 DRILL I P I I PROD1 08:55 - 11:30 I 2.581 DRILL I P I I PROD1 section C3 Op = 1.58 / 1.58 bpm ,CTP= 3,100 / 3,600 psi; Density = 8.78 / 8.75 PP9 BHP's 3,980 / 4,550 psi ECD 11.75 ppg; WHP = 50 psi WOB / CTW = 1.5 / -3000lbf ROP started at 10-28 fph PU at 14 fpm; CT PUW. = 24,800 Ibf up RIH at 14 fpm CT down = 4800 Ibf down No difference with the new cocktail of tube in the annulus Drilling inverted lateral section towards upper section C2 lower section C3 Op = 1.59 / 1.60 bpm ,CTP= 3,100 / 3,710 psi; Density = 8.78 / 8.75 ppg BHP's 3,980 / 4,773 psi ECD 11.62 ppg; WHP = 50 psi WOB / CTW = 2.5 / -1,7001bf ROP at 13 fph Vp = 340 bbl's Drill ahead from 11,722'. 3500 psi fs at 1.58 in/out. 200 dpsi. DHWOB: 3k#. WHP/BHP/ECD: 51/3903/11.58 ppg. IA/OA/PVT: 555/328/358 bbls. Inc: 92 deg. ROP continues to be low: 10-20 fph. Rig down to 1 genst. Reduce pump rate and begin to POH to casing. Able to bring a 2nd genset back on line. Run back to btm. Drill ahead trom 11,770'. Wiper trip to window. Hole smooth in both directions. Drill ahead from 11,800'. 3500 psi fs at 1.6 in/out. 200-300 dpsi. DHW06:3-4k#. Drill ahead from 11,885. ROP slowed down from 75 to 15 fph. DHWOB still good (2-3k#) Make wiper trip to window. Circulate up to tbg tali at 10,337'. Log gr tie above window. Add 5' correction. Wiper trip back in hole. Hole smooth to bottom. Drill ahead from 11,910'. 3500 psi fs at 1.68 iNout. 200 dpsi. DHWOB: 2.5-3.0 k#. Inc: 95.3 deg. ROP continues to be slow even after wiper trip. (10-15 fph). Drilling inverted lateral section towards upper section C3 lower section C4 Op = 1.62 / 1.65 bpm ,CTP= 3,100 / 3,695 psi; Density = 8.91 / 8.88 PP9 BHP's 3,980 / 4,726 psi ECD 11.92 ppg; WHP = 40 psi WOB ! CTW = 2.0 / -21001bf Vp = 337 bbls ROP started at 80-110 fph We are in the fast footage for the day Wiper trip after drilling 150 ftBHP = 4156 psi (ECD = 12.32 PPg) Drilling inverted lateral section lower section C4 Op = 1.62 / 1.65 bpm ,CTP= 3,450 / 3,695 psi; Density = 8.91 / 8.88 PP9 BHP's 4,025 / 4,476 psi; ECD 11.89 ppg; WHP = 40 psi Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: 1C-14 Common Well Name: 1 C-14 Spud Date: 10/25/2006 Event Name: DRILL+COMPLETE Start: 10/25/2006 End: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 'Code' NPT ' Phase 11/12/2006 08:55 - 11:30 2.58 -- DRILL ~ P I ( , PROD1 11:30 - 13:30 I 2.001 DRILL I P I PROD1 13:30 - 16:50 I 3.331 DRILL I P I I PROD1 16:50 - 18:30 1.671 DRILL P PROD1 18:30 - 18:45 0.25 DRILL P PROD1 18:45 - 19:30 0.75 DRILL P PROD1 19:30 - 22:00 I 2.501 DRILL I P I I PROD1 22:00 - 00:00 I 2.001 DRILL I P I I PROD1 11/13/2006 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 01:30 - 02:00 I 0.501 DRILL I P I I PROD1 02:00 - 02:30 0.50 BOPSUt~ P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 06:10 3.171 DRILL P I PROD1 06:10 - 06:20 I 0.171 DRILL I P I I PROD1 06:20 - 07:50 ~ 1.50 ~ DRILL ~ P ~ I PROD1 07:50 - 10:40 I 2.831 DRILL P PROD1 Description of Operations WOB / CTW = 1.25 / -21001bf ROP 100 fph Vp = 397 bbls Added pit 4 to system Wiper Trip after drilling 150 ft WHP = 200 psi BHP = 4080 psi (ECD = 12.10ppg) Clean trip Drilling lateral section in C4 Op = 1.63 / 1.68 bpm ,CTP= 3,450 / 3,695 psi; Density = 8.91 / 8.88 PP9 BHP's 3982 / 4,605 psi; ECD 12.01 ppg; WHP = 40 psi WOB / CTW = 1.25 / -20001bf ROP 50-70 fph Vp = 404-411 bbls Stacking increased in the last 20 ft drill prior to the wiper trip Wiper trip holding 200 psi on choke BHP = 4000 psi). Hole is leveling out at 6,555 ft TVD Hole smooth to tbg tail. Log gr tie in from 10,670'. Add 6' correction. Continue wiper trip to bottom. Hole smooth to btm. 1.6k# do wt at btm. Prep to swap mud. Drill ahead from 12,346'. 3550 psi fs at 1.62 in/out. CT WT/DHWOB: -5k#/1.3k#. Drill to 12,378. New mud around. Unable to make any footage. Very little motor work. Dicsuss with geo & town. Decide to trip for BHA inspection and agitator. 25k# CT up wt off btm. Circulate out of hole. Hold 200 psi in open hole. Open EDC at window. Continue to circ out of hole following BHP pressure schedule. Continue to circulate out of hole. Maintain BHP as per pressure schedule. Close SSSV with 800 psi trapped below. Bleed WHP pressure and flow check for 5 minutes. Well stable. POH to surface. Tag up and monitor well again for flow. Hold PJSM while POH to review BHA handling procedure with crew. LD BHA. BHA in good condition. HTC bit was graded 1-1 with 1 plugged nose jet. Function test BOP rams, annular, and HCR valves. MU lateral drilling assembly w/ resistivy, agitator, 0.8 deg mtr, and new Hycalog bi-center bit. Agitator sln: AS218-29-114. Stab coil. Test MWD tools. Get on well. Flow test agitator on well. Run in hole. Circulate 1.5 bpm through open EDC. Open SSSV w/ 800 psi WHP. Slow pipe and CBU at 6000'. Repeat and CBU at 8000'. CBU at 10,000'. Vp at 10,719 ft = 365 bbl's Tie-in starting at 10,670 ft MD to 10, 715 ft. Corrcected +4 ft. Trapped 700 psi on WH (BHP 3900 psi), SD pump. Close EDC. RIH past whipstock. Start MP and RIH circ at 1.51 bpm CTP 3800 psi with 100 psi on wellhead. BOB drilling lateral in C4 TF at 65 L Op = 1.52 / 1.54 bpm ,CTP= 3,750 / 3,950 psi; Density = 8.91 / 8.88 PP9 BHP's 3858 / 5000 psi; ECD 11.52 ppg; WHP = 40 psi WOB / CTW = 1.25 / -600 to 500 Ibf ROP 30-70 fph Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-14 1 C-14 DRILL+COMPLETE Start: 10/25/2006 NORDIC CALISTA Rig Release: 11/23/2006 NORDIC 2 Rig Number: Date ~ From - To I Hours Task Code i NPT Phase 11/13/2006 07:50 - 10:40 2.83 DRILL P PROD1 10:40 - 13:10 2.50 DRILL P PRODi 13:10 - 17:15 4.08 DRILL P PROD1 17:15 - 19:45 2.50 DRILL P PROD1 19:45 - 23:30 3.75 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 11/14/2006 00:00 - 01:15 1.25 DRILL P PROD1 01:15 - 01:45 0.50 DRILL P PROD1 01:45 - 03:00 1.25 DRILL P PROD1 03:00 - 06:30 3.50 DRILL P PROD1 06:30 - 09:30 3.00 DRILL P PROD1 09:30 - 11:30 2.00 DRILL P PRODi 11:30 - 12:30 1.00 DRILL P PROD1 12:30 - 13:45 1.25 DRILL P PROD1 13:45 - 15:00 1.25 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 17:20 1.83 DRILL P PROD1 17:20 - 21:00 3.67 DRILL P PROD1 21:00 - 22:40 1.67 DRILL P PROD1 22:40 - 00:00 1.33 DRILL P PROD1 11/15/2006 00:00 - 03:15 3.25 DRILL P PROD1 Page 8 of 16 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations Vp = 370 bbls Wiiper trip Trapped 200 psi on wellhead BOB drilling lateral in C4 TF at 90 L Op = 1.45 / 1.48 bpm ,CTP= 3,6500 / 3,750 psi; Density = 8.86 / 8.71 PP9 BHP's 3868 / 4988 psi; ECD 11.54 ppg; WHP = 30 psi WOB / CTW = 1.25 / 500 Ibf ROP 30-50 fph; Vp = 371 bbls Could of encountered a fault of 12, 580 ft. erratic ROP and stalls. ROP dropped 50 to 12 fph, (hard). Back to drilling normally at 12,610 ft Wiper trip to window. Hole smooth. Drill ahead form 12,680'. 4050 psi fs at 1.46 in/out. 100-150 dpsi. CT/DHWOB: -1300!1.0-2.0 k#. WHP/BHP/ECD: 30/3861/11.54 ppg. IA/OA/PVT: 277/298/395 bbls. Inc: 91.7 deg. Had a little trouble getting started after short trip, but ROP varied from 45 to 70 FPH once under way. Wiper trip up to tubing tail at 10,337'. Continue wiper trip to tbg tail. Log gr tie in from 10,670'. Add 2' correction. Wiper trip in hole. Hole smooth in both directions. Drill ahead from 12,850'. 3900 psi fs at 1.52 in/out. 100-200 dpsi. DHWOB: 0.9 - 1.5k#. CT Wt 26k# up/-1 k# do wt. WHP/BHP/ECD: 26/3790/11.43 ppg. IA/OA/PVT: 286/297/388 bbls. Inc: 92 deg. Became dill stuck at 12,880'. Shut do pump. Came free. Drill ahead. Mud pump #1 down. Bring pump #2 on line. Wiper trip at 13,000 ft Clean trip up and down BOB drilling lateral section at 90L TF staying below D-Shale. Differential stuck at 13, 020 ft. Had work at it and came free in 15 minutes. Op = 1.51 / 1.53 bpm ,CTP= 3,950 / 4,150 psi; Density = 8.91 / 8.88 PP9 BHP's 3858 / 5000 psi; ECD 11.52 ppg; WHP = 40 psi WOB / CTW = 1.25 / -600 to 500 Ibf ROP 30-70 fph Vp = 357 bbls Drilling 20 and then PU 100 ft to clean up solids 200 ft wiper trip, PUW at 27klbf clean BOB drilling lateral section at 90L TF staying below D-Shale. Op = 1.51 / 1.53 bpm ,CTP= 3,950 / 4,150 psi; Density = 8.91 / 8.88 PP9 BHP's 3858 / 5000 psi; ECD 11.52 ppg; WHP = 40 psi WOB / CTW = 1.25 / -600 to 500 Ibf ROP 30-70 fph Vp = 356 bbls. Worked differential tight CT. Pulling up to 50k and shutting down pump .BHA comes free. Wiper trip to tubing tail at 10,337'. Log gr tie in from 10,670'. Subtract 16' correction. Wiper trip back to TD. Drill from 13092' 1.55/3350/90L to 13200'. Start fresh Flo Pro mud Wiper to window was clean W iper to TD was clean Drill from 13200-13350' 1.56/3400/90L w/ 100-500 psi dill, 1.0-2.2k wob w/ -Sk surface wt at 50-100'/hr w/ 11.14 ECD at Printed: 1127/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Start: 10/25/2006 Contractor Name: NORDIC CALISTA Rig Release: 11!23/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task ~ Code NPT ; Phase 11/15/2006 00:00 - 03:15 3.25 DRILL P PROD1 03:15 - 05:15 2.00 DRILL P PROD1 05:15 - 07:15 2.00 DRILL P PROD1 07:15 - 08:30 I 1.251 DRILL I P I I PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 10:30 1.00 DRILL P PROD1 10:30 - 11:30 1.00 DRILL P PROD1 11:30 - 14:30 I 3.001 DRILL I P I I PRODi 14:30 - 14:37 0.12 DRILL P PROD1 14:37 - 15:10 0.55 DRILL P PRODi 15:10 - 17:05 1.92 DRILL P PROD1 17:05 - 17:30 0.42 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 18:50 I 0.331 DRILL I N I I PROD1 18:50 - 19:50 I 1.001 DRILL I P I I PROD1 19:50 - 20:05 I 0.251 DRILL I P I I PROD1 20:05 - 20:55 I 0.831 DRILL I P I I PROD1 Page 9 of 16 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations 88 deg at 6438' TVD in 66 api sand while fin mud swap W iper to/thru window was clean Open EDC and circ 1.75/3200. POOH for hours on agitator while follow pressure schedule. Close SSSV with 750 psi trapped below. Bleed WHP pressure and flow check for 5 minutes. Well stable. POH to surface. Tag up and monitor well again for flow. Hold PJSM while POH to review BHA handling procedure with crew. LD BHA. BHA in good condition. Some wear on one of the wear pads on BHA. HYC bit was graded 1-1 and balled up. Cut 22' of coil Pull test coil connector to 38k Rehead ecoil, install chicksan in reel hardline. MU lateral drilling assembly w/ new flow sub, resistivity sub, agitator, 0.8 deg mtr, and new Hycalog bi-center bit. Agitator s/n: AS218-35-H4HF. Stab coil. Test MW D tools. Get on well. Keep EDC closed. RIH while circulating at minimum rate. Open SSSV w/ 800 psi WHP. RIH while circulating according to pressure schedule. Open EDC. Slow pipe and CBU at 9000'. Vp at 10,719 tt = 329 bbl's Tie-in starting at 10,670 ft MD to 10695ft. There was a +25 ft correction during the tie-in. This is not normal so the counter on the injector was checked. A little debris was found on the counter wheel. Close EDC. RIH past whipstock to bottom. Tag Bottom and P/U. Mad Pass last 25' BOB drilling lateral at 90 L and 88 deg incl to 13417'. See all three curves on res tool shift to 1's at 13360-13380'? Could be boundary, or res tool problem. Also, begin having trouble getting back to bottom (we are reaching the end of the rope . . .) Op = 1.48 / 1.48 bpm , CTP= 3,770 / 3,900 psi; Density = 8.87 / 8.73 pP9 BHP's 3813 / 5242 psi; ECD 11.40 ppg; WHP = 26 psi WOB / CTW = 1.08 / -300 to 900 Ibf ROP 60-70 fph Vp = 363 bbls Relog from bit depth of 13380' to TD-still missing data. PVT 365 Resume drilling from 13417' 1.5/3800/100L w/ 200# dill and 1.5-3.Ok wob w/ -6k surface wt at 11.3 ECD at 89 deg. Swap to right at 13445'. Drill to 13456'. Lost charge pump prime and returns at the same time 50' wiper to sort out issues and discuss 1.52/1.04/3600 w/ 10.9 ECD. Head back to TD and returns improved to 1.47/1.17/3600 PVT 353 Resume drilling from 13456' 1.48/0.73/3550/1058 to hold 88 deg and are losing avg 0.4 bpm returns at 10.94 ECD. Res too- is intermittent. Geo's need it to steer. Plan is to drill -50' to next wiper point to hopefully plug up loss zone with cuttings before TOH to replace res tool. Drill to 13500' and res tool Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-14 1 C-14 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Date !From - To I Hours ; Task Code NPT ---- 11/15/2006 20:05 - 20:55 0.83 DRILL P 20:55 - 21:10 0.25 DRILL P 21:10 - 21:50 I 0.671 DRILL I N 21:50 - 00:00 I 2.171 DRILL I P 11/16/2006 100:00 - 00:35 I 0.581 DRILL I P 00:35 - 04:00 I 3.421 DRILL I P 04:00 - 06:00 2.00 DRILL P 06:00 - 06:40 0.67 DRILL N SFAL 06:40 - 07:10 0.50 DRILL P 07:10 - 09:50 2.67 DRILL P 09:50 - 11:30 1.67 DRILL P 11:30 - 16:30 I 5.001 DRILL I N I DFAL 16:30 - 17:00 ( 0.501 DRILL I N I DFAL 17:00 - 19:50 I 2.83) DRILL I N 19:50 - 20:25 0.58 DRILL N 20:25 - 20:50 0.42 DRILL N 20:50 - 22:10 1.33 DRILL N 22:10 - 00:00 1.83 DRILL N 11/17/2006 00:00 - 00:15 0.25 DRILL N 00:15 - 00:55 0.67 DRILL N Page 10 of 16 Spud Date: 10/25/2006 Start: 10/25/2006 End: 11/23/2006 Rig Release: 11/23/2006 Rig Number: Phase Description of Operations PROD1 started working again. Final loss rate is 1.52/1.25/3830 PROD1 200' wiper before relog missing res tool data. Pull off btm at 29.4k, had 3k overpull, but no change in loss rate at 13453' (loss zone up depth) PVT 320 PROD1 Log missing data from 13400' to TD. Res tool working okay now ...and still losing 0.3 bpm at 11.1 ECD PVT 306 PROD1 Wiper to window was clean except for minor OP and MW at -11000'. Wiper back in hole PRODi Wiper to TD tagged at 13541' (counter wheel has slipped again). Corr to 13500' PVT 267 PROD1 Drill from 13500' 1.51/1.31/3900/1808 w/ 100-300 psi dill, 0.6-1.5k wob, w/ 11.2 ECD. Start to see GR increase from 70 to 140 api so point TF down for a few feet to avoid penetrating D shale and then drill at 86 deg. Diff sticky at 13580' (high perm area verified by res tool) Drill to 13650' 1.46/1.30/3840 PVT 220 PRODi W iper to/thru window was clean. Open EDC. Continue wiper to tubing tail while circ 1.65/1.35. RIH and park at 10600' PRODi Change out counter wheel due to large deviations during tie-ins PROD1 Tie-in starting at 10,670 ft MD to 10725ft. Corrcected -14 ft. Trapped 750 psi on WH (BHP 3800 psi), SD pump. PROD1 Bleed down WH pressure, RIH past whipstock to bottom. PROD1 BOB drilling lateral at 165 R and 89 deg incl. Op = 1.51 / 1.28 bpm , CTP= 4500 psi; Density = 8.96 / 8.80 PP9 BHP's 3807 / 5717 psi; ECD 11.30 ppg; WHP = 22 psi W OB / CTW = 2.41 / -4400 to -6000 Ibf ROP 80-90 fph IAP = 112 psi, OAP = 237 psi Vp = 368 bbls PROD1 POOH for Orienter Failure. Circulate according to pressure schedule. Downhole pressure gauges not working, CBU at tubing tail (10,300'). POOH with 800 psi on wellhead while circulating to displace coil volume. Close SSSV with 800 psi trapped below. Bleed WHP pressure and flow check for 5 minutes. Well stable. POH to surface. Tag up and monitor well again for flow. Hold PJSM while POH to review BHA handling procedure with crew. PROD1 LD BHA. BHA in good condition. HYC bit was graded 1-1 and will be re-run. PROD1 Noticed line of severe pitting on coil near coil connector. Cut off CTC and 20' of CT. Behead CTC. PT 40k. Head up BHI. PT 3500 psi PROD1 MU BHA PROD1 RIH w/ BHA #7 to 200'. Prep to open EDC and found short in tool. POOH to check tools PROD1 LD BHA and test. Found short at flow sub PROD1 Open EDC. RIH w/ BHA #7 circ thru EDC 0.7/1800. Open TRSSV w/ 800 psi positive assist. RIH following pressure schedule PROD1 Finish RIH w/ BHA #7 PROD1 Log tie-in from 10670' and missed it first time. Relog from 10650'. Corr +26' 10723'E=10852'M Printed: 11/27/2006 10:32:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 11/17/2006 00:15 - 00:55 00:55 - 02:15 02:15 - 07:00 07:00 - 08:45 08:45 - 09:15 09:15 - 12:30 12:30 - 18:00 18:00 - 20:00 20:00 - 22:15 22:15 - 00:00 11/18/2006 00:00 - 01:00 01:00 - 02:50 02:50 - 03:10 03:10 - 05:50 05:50 - 11:15 BP EXPLORATION Operations Summary Report 1 C-14 1 C-14 DRILL+COMPLETE Start: 10/25/2006 NORDIC CALISTA Rig Release: 11/23/2006 NORDIC 2 Rig Number: Hours Task Code ~NPT Phase Page 1 1 of i 6 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations 0.67 DRILL N PROD1 Close EDC PVT 350 1.33 DRILL N PROD1 RIH thru window, clean. W iper to TD 1.35/3230 was clean to tag at 13692'. Also, reached TD w/ positive 3k string wt and CTP is 500 psi lower than yesterday PVT 351 4.75 DRILL P PRODi Drill from 13692' w/ 1.43/1.30/3340/90L w/ 300-600 psi dill, 1-2.5k wob w/ -4k surf wt w/ 11.4 ECD at 83 deg avg, but got as low as 80 deg. Adjust TF to 45L to get back to 85 deg and penetration slowed to a crawl, but still getting 2.5k wob. Had a good differential overpull at 13760' Drilled to 13800' by 0600 hrs and penetration rate increasing. Weight stacked up at 13850' 1.75 DRILL P PROD1 Wiper to window. Hole smooth. 0.50 DRILL P PROD1 Log gr tie in from 10,670'. Add 14' correction. 3.25 DRILL P PROD1 Wiper trip back to bottom was smooth. Had a lot of -5k to -8k# coil weight from 12,800' to 13,800;. 5.50 DRILL P PROD1 Drilling ahead from 13856' at 90L and 83 deg incl. Op = 1.52 / 1.39 bpm ,CTP= 4000 fs / 4200 psi; Density = 8.89 / 8.73 PP9 BHP's 3909 / 5564 psi; ECD 11.63 ppg; WHP = 33 psi W OB / CTW = 1.04 / -4000 to -8000 Ibf ROP 60-70 fph IAP = 83 psi, OAP = 344 psi Vp = 253 bbls Poor weight rtransfer. Begin circulating 2 ppb alpine beads down coil. Able to get 2k# DHWOB. PU wt: 26k#. RIH coil wt: -3k to -5k# with beads around. Drilliing on a hard spot at 13,941'. Drill ahead to 14000'. Losses have increased to 1.54/1.13/4000 w/ 11.6 ECD Agitator has been working intermittently and has 47 hrs. Discuss progress w/ town. Elect to trip for fresh BHA tools PVT 186 2.00 DRILL P PROD1 Wiper to window was clean, FS of 1.5/4300 is high PVT 150 2.25 DRILL P PROD1 POOH circ thru bit while follow pressure schedule. Close TRSSSV w/ 800 psi. Inspect 100' CT PVT 110 1.75 DRILL P PROD1 LD drilling assy. Bit was 1-1-I. Found stator rubber. Changed bit, motor and agitator. Changed out EDC after finding sleeve would not fully open (assumed beads are hindering operation) 1.00 DRILL P PROD1 MU drilling BHA. Agitator s/n: AS218-49 1.83 DRILL P PRODi RIH w/ BHA #8 circ 0.3/1150 thru bit. Chk agitator at 500'. Open TRSSSV w/ 800 psi positive assist. RIH following pressure schedule 0.33 DRILL P PROD1 Log tie-in down from 10670', corr +17.5' PVT 154 2.67 DRILL P PRODi Wiper to TD at normal speed and pos string wt until 13150' set down w/ TF 180 out. Could not RIH at normal speed due to neg wt after that. Avg speed <6'/min w/ -8k wt. Start stringing in beads at 2 ppb. After 30 bbls out the bit and at 13260' were able to RIH freely at 38'/min at +1 k string wt. Arrive back at TD tagged at 14006' w/ Ok string wt 5.42 DRILL P PROD1 Drill from 14006' w/ 1.44/1.28/3680/90L w/ 3550 psi fs, 0.5-1.5k wob w/ -6.5k surf wt w/ 12.34 ECD at 85 deg avg, ROP 30-50 fph BHP's 3980 / 4954 psi; WHP = 26 psi IAP = 70 psi, OAP = 336 psi Vp = 359 bbls Frequent BHA wiper trips made, began to get dill sticky. Printed: 11!27/2006 10:32:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From - To ;Hours ( Task I Code I NPT 11/18/2006 05:50 - 11:15 5.42 DRILL P 11:15 - 11:45 0.50 DRILL P 11:45 - 13:45 2.00 DRILL P 13:45 - 14:00 0.25 DRILL P 14:00 - 17:00 3.001 DRILL ~ P 17:00 - 19:00 2.00 DRILL P 19:00 - 21:00 2.00 DRILL P 21:00 - 22:00 1.00 DRILL P 22:00 - 22:45 0.75 CASE P 22:45 - 23:00 0.25 CASE P 23:00 - 00:00 1.00 CASE P 11/19/2006 00:00 - 01:20 1.33 CASE P 01:20 - 03:00 1.67 CASE P 03:00 - 04:45 1.75 CASE P 04:45 - 05:20 0.58 CASE P 05:20 - 05:35 0.25 CASE P 05:35 - 06:00 0.42 CASE P 06:00 - 07:00 I 1.00 I CASE I P 07:00 - 08:00 ~ 1.00 I CASE P 08:00 - 10:30 I 2.501 CASE I P 10:30 - 11:15 0.75 CASE P 11:15 - 12:45 1.50 CASE P 12:45 - 15:30 I 2.751 CASE I P Page 12 of 16 Spud Date: 10/25/2006 Start: 10/25/2006 End: 11 /23/2006 Rig Release: 11/23/2006 Rig Number: Phase ' Description of Operations PROD? Shaker samples taken every 50 ft PRODi Differentially stuck at 14162'. Finally pulled free at 60k# after several attempts. Called TD at 14162'. PROD1 Wiper to / thru window. Hole smooth. Up weight 25k# PROD1 Log GR tie in at 10670' to 10699'. Corrected +17'. Trapped 800 psi on WH (BHP 3800 psi), SD pump. PRODi RIH, mad pass from 13200' to bottom. ~ 12800', avg speed 28'/min w/ 4k wt. @ 14150', 10'/min wf 1.7k# Tagged TD at 14157' which is official TD PROD1 Wiper back to window. PROD1 POOH for liner circ thru bit 1.5/3100 and following pressure schedule. Close TRSSSV w/ 800 psi. Finish POOH PROD1 LD drilling BHA PROD1 Bring liner tools to floor. RU to run liner PROD1 Safety mtg re: run liner PROD1 MU Unique indexing guide shoe on one solid joint followed by 54 jts 2-3/8" 4.7# L-80 STL RUNPRD Finish MU 55 jts 2-3/8" slotted liner RUNPRD Install BTT 3" GS, agitator and BHI MWD assy (OA 1815'E=0'M). Pressure wellbore to 800 psi and open TRSSSV RUNPRD RIH w/ liner on CT w/o pump and following pressure schedule. Swaco choke became unreliable/jammed due to beads (assumed). Swap to manual choke PVT 235 RUNPRD 26.3k, 9.2k at window. Start RIH thru open hole at 50'/min w/ +8.2k w/o pump. Set down at 11401' one time RUNPRD Log tie-in down from 12420' (at 11670' GR), corr +8' RUNPRD Continue RIH w/liner from 12450' at 60'/min. Had one set down at 13850'. RIH w/liner 60'/min w/o pump w/ +1 k wt to setdown at TD at 14166' CTD. Did not reciprocate RUNPRD Bring pump rate up to 1.7 bbl/min @ 4400 psi and release GS from liner at 26k. Top of liner #1 is at 12390' ELMD. Reset CT counter to GS depth. POOH to window replacing voidage at 48 ft/min following pressure schedule. RUNPRD Bring coil just above window and CBU at 10725' w/ 10.5 ppg kill wt brine. Op = 0.90 / 0.88 bpm , CTP= 1860; Density = 10.48 / 8.70 ppg RUNPRD Pumped 110 bbls until return density reached 10.5 ppg. POOH following pressure schedule. Bleed WHP pressure and flow check for 5 minutes. Well stable. POH to surface. Tag up and monitor well again for flow. RUNPRD PJSM. LD BHA w/ GS tool, MU nozzle for reel blow down, get back on well RUNPRD While waiting on methanol truck, pumped 10.5 brine through Swaco choke. Choke appeared to unclog and function normally. PJSM. Pump 10 bbls 60/40 methanol through coil and blow down reel with nitrogen. Pumped 1500 scf/min of nitrogen for 15'. Methanol and nitrogen returns were taken in tiger tank. RUNPRD PJSM for reel swap. RD CT, swap from a-thru coil reel to non e-thru coil reel. Install tugger slip connector. Unstab coil and spool back onto reel. Secure coil to reel. Lower reel onto flat bed trailer. Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Spud Date: 10/25/2006 Event Name: DRILL+COMPLETE Start: 10/25/2006 End: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task , Code I NPT Phase Description of Operations 11/19/2006 15:30-17:45 17:45 - 18:00 18:00 - 22:00 22:00 - 00:00 11 /20/2006 100:00 - 01:45 01:45 - 02:00 02:00 - 02:15 02:15 - 05:00 05:00 - 05:40 05:40 - 08:00 08:00 - 08:45 08:45 - 09:30 09:30 - 11:45 11:45 - 14:00 2.25 CASE P 0.25 CASE P 4.00 CASE P 2.00 CASE P 1.75 CASE P 0.25 CASE P 0.25 CASE P 2.75 CASE P RUNPRD Spot trailer with 2" a-free coil reel. PU reel and mount in reel stand. MU hardline in reel. RUNPRD Crew change/safety mtg RUNPRD Fin MU hardline in reel. Install internal grapple and PT. Pull CT to floor and stab into injector. Install Kendall CTC w/ 1.06" ID and PT at 38k. Install nozzle, stab onto well. Prep to circ over closed swab valve RUNPRD Fill CT w/ 10 bbls 60/40 McOH followed by 40 bbls 10.5# KW F 2.0/2000 and take returns to tiger tank until returns were clean then circ to pit. PT CTC, reel and hardline at 4000 psi. Unstab, remove nozzle and install dart catcher w/ 1500# shear pins. Load BTT wiper dart and circ to bung hole and couldn't get rate. Fished out a thread protector. Resume circ 1.3/900 RUNPRD Pump 20 bbls past displacement before dart hit-assumed due to pumping at low rate while working to clear bung hole. Reload dart, repin dart catcher and repeat at 1.5/1030. Dart sheared pins at calc displ of 40.5 bbls RUNPRD RD test equipment. Set injector on legs. RU to run liner RUNPRD Safety mtg re: run liner RUNPRD Open swab valve and well on a vac. Fill w/ 3 bbl MU tapered steel guide shoe on 12 jts 2-3/8" 4.7# L-80 STL slotted liner w/o centralizers MU 13 jts 2-3/8" 4.7# L-80 STL solid liner w/ centralizers. Install ported baffle sub on 10' solid pup w/ O-ring sub. MU 40 jts 2-3/8" 4.7# L80 STL solid liner w/ centralizers RUNPRD Install false table and RU to run CSH RUNPRD PU BTT stinger for O-ring sub. MU 42 jts CSH and space out using RUNPRD PT O-ring sub to 400 psi. RUNPRD MU liner running BHA to 1"CSH and 2-3/8" liner. PU injector and connect CTCC to swivel. RUNPRD RIH w/ liner on CT at 75'/min. Circulate at minimum rate. Rtns slowly increased to proper displacement. DPRB RUNPRD 29k# up wt at 10,700'. 9k# do wt. Run through window and into open hole. Set do at 11,276', 11,533', 11,960'. Work pipe at 11,960'. No progess. Circulate 10.5 brine w/ safe-tube. Pump at 0.75 bbl/min, CTP 1080 psi. DPRB RUNPRD Able to work past 11960', made slow progress while circulating safe-tube. Set do at 12016', slow progress to 12044' DPRB RUNPRD Began to circ 50 bbl pill w/ lppb bio, 2ppb alpine beads, 1/2% safe-tube. Stack up -6 to -8k# and slowly work pipe downhole to 12280'. No more progress. RUNPRD Continue to attempt to make hole from 12280' w/o progress due to lockup conditions. Pilof test of beads in the 10.5 brine shows that they float to surface, however, mixed w/ 1 ppb biozan they stay suspended. So, WO delivery of more biozan and then bring system up to 1+ ppg biozan. String in beads at 1+ppb. after isolating pit 5. PUH to 12230' RUNPRD RBIH and from 12250' were able to RIH w/ liner at 1.5'/min w/ pos str wt while wo bio/beads to get circa 0.7/0.65/1060 completely around into annulus. Go past 12280' w/ a little wt loss, then continue in hole at 1.5'/min at +1 k string wt. Try to go faster and end up stacking near max. Set pilot at 1.5'/min 0.67 CASE P 2.33 CASE P 0.75 CASE P 0.75 CASE P 2.25 CASE P 2.25 CASE N 14:00 - 15:00 1.00 CASE N 15:00 - 18:00 3.00 CASE N 18:00 - 19:45 I 1.75 I CASE I N 19:45 - 20:45 I 1.00 I CASE I N Printed: 11/27/2006 10:32:45 AM 8P EXPLORATION Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1C-14 Event Name: DRILL+COMPLETE Start: 10/25/2006 Contractor Name: NORDIC CALISTA Rig Release: 11/23/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task ~ Code ~ NPT { Phase ----__ __ 11/20/2006 ~ 19:45 - 20:45 1.00 ~ CASE N ~ RUNPRD 20:45 - 22:00 1.251 CASE (N I I RUNPRD 22:00 - 23:00 I 1.001 CASE N RUNPRD 23:00 - 23:15 0.25 CASE P RUNPRD 23:15 - 00:00 0.75 CASE P RUNPRD 11/21/2006 100:00 - 00:20 I 0.331 CASE I P I I RUNPRD 00:20 - 00:45 0.42 CEMT P RUNPRD 00:45 - 02:00 1.25 CEMT P RUNPRD 02:00 - 02:45 I 0.751 CEMT I P I I RUNPRD 02:45 - 04:30 1.75 CASE P RUNPRD 04:30 - 05:00 0.50 CASE P RUNPRD 05:00 - 07:15 2.25 CASE P RUNPRD 07:15 - 14:15 7.00 BOPSU P RUNPRD Page 14 of 16 Spud Date: 10/25/2006 End: 11 /23/2006 Description of Operations and let CT move on it's own. Get to 12330' with positive string wt, but start to go negative fast. By 12350' were at -9.4k at <1'/min Lost all returns and CTP increased at 12352' (-30' from TD) 0.7/0/1140. Do frequent 30' pickups and returns came back to normal each time. Assume there is/are swelling shales) at the centralizers) above the baffle sub. Have 10k overpulls and increased loss of returns each time when pull thru 12310' and 12280'. Try to get back to bottom and start losing ground to 12333' due to lockup and drag at shales) while circ 0.7/0.58/930 Discuss. Can't leave the liner with OH seperation so need to get to TD. Also, need a good cement job. Alternative is to rerun liner w/o centralizers so order the same Meanwhile have got liner back down to 12350' So, after explaining the alternative to the SWS driller we were able to get past 12352' and with numerous attempts were able to get to a depth of 12383' w/ max down wt and no more progress after 10 attempts. This would be -12380' w/ normal down wt so with a normal correction of +10' this would be 12390' which is where the top of the first section was left (12389'). This is also verified by the UDAC and mechanical counters which say we are at 10298' plus the BHA=12407'. Park at TOL1 and circ 0.6/0.45/900 w/ steady returns Safety mtg re: cement Swap to 10.5 KW F w/o beads and pump 17 bbls 0.85/0.7/1270. PUH to 12364' w/ 35.8k up wt to ball drop spot. Load 5/8" aluminum ball and chase with the same fluid. RBIH to 12382' and stack wt. Displace ball 1.71/1.22/3700 Circ ball to seat at 36.6 bbls and sheared at 3800 psi. PUH 26.5k and verified free of liner. Stack -3k on TOL at planned 10286' ELMD SD pump and wo cementers to batch up PT DS @ 4000 psi w/ 2 bbls FW. DS mix and pump 5.0 bbls 15.8 ppg G cement w/ latex at 1.0/0.78/1900 at 70 deg. Load CT wiper dart. Kick out dart with 500 psi and displace to seat with 20 bbls of 8.7 ppg 1.5# biozan 1.4/1.10/3200 followed by 10.5# KW F w/o beads. After cement turned corner at 36.5 bbls, CTP increased to 1.4/4400. Red rate to 1.0/4000 until 39.0 bbls. Red rate to 0.45/1800 while wait for dart to seat at 40.5 bbls. Dart did not seat. Pumped exactly 1.0 bbl and SD pump so as to not overdisplace PUH at 26.Sk and did not see press drop off when stinger pulled out of O-ring sub. PUH clean, replacing voidage at 0.3/660. Saw dart hit at 45.3 bbls and pressured up to 2900 psi before shearing. Assume dart got held up in the CTC due to low pump rate. POOH thru liner at 50'/min POH Chk for flow. LD CRLRT Standback 1" CSH. Prep to test BOP's Start BOPE test. Test to 250 / 4000 psi for 5 min each. Had trouble getting good tests throughout testing. Inspect and grease injector. Printed: 11/27/2006 10:32:45 AM BP EXPLORATfON Page 15 of 16 Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 10/25/2006 Start: 10/25/2006 End: 11/23/2006 Rig Release: 11/23/2006 Rig Number: Date From - To Hours Task I. Code I NPT --x-- 11/21/2006 07:15 - 14:15 ~ 7.00 BOPSURP 14:15 - 14:30 0.25 CASE P 14:30 - 17:30 3.00 CASE P 17:30 - 19:30 2.00 CASE P 19:30 - 21:20 I 1.831 CASE I P 21:20 - 22:00 0.67 CASE P 22:00 - 00:00 2.00 CASE P 11/22/2006 00:00 - 01:30 1.50 CASE P 01:30 - 04:00 2.50 CASE P 04:00 - 05:00 1.00 CASE P 05:00 - 08:15 3.25 CASE P 08:15 - 12:00 I 3.751 CASE I P 12:00 - 13:00 1.00 CASE P 13:00 - 15:30 2.50 CASE P 15:30 - 16:15 I 0.751 CASE I P 16:15 - 16:45 ~ 0.50 ~ CASE ~ P 16:45 - 17:20 I 0.581 CASE I P 17:20 - 19:20 I 2.001 CASE I P 19:20 - 20:20 I 1.001 CASE I P Phase Description of Operations RUNPRD Swap out 10.5# KW F in pits and CT for 8.6# 2% KCL w/ 2 ppb biozan RUNPRD PJSM for MU cleanout run BHA. RUNPRD PU cleanout BHA and CSH RUNPRD RIH to TOL at 10281' pumping min rate. (Did not see liner top) Diluted the 10.5# brine with 8.6# KCI and had an average 8.9# milling fluid RUNPRD RIH at 24'/min pumping lbpm at 2050psi free-spin. Seeing 200psi motor work at 11350'. cleanout to 11400' pick-up clean. Wash down to 11440'. Drilling soft cement stringers starting at 11440' motor-work 400psi tag O-ring sub at 11573'. PU wt 22k. RUNPRD Close choke. PT liner lap to 2000psi. Repeated attempts but leaked off down to 1100psi within 1 min. No surface leaks. RUNPRD Wiper back to 11460'. RIH tag o-ring sub at 11573' Begin time milling sub. 1.0 bpm 2750psi FS (picked up additional 600psi possibly particle plugged mill) 250psi MW RUNPRD Continued milling o-ring sub. RUNPRD Time mill on float and ported baffle subs. Numerous stalls on each with 5-10k overpulls. Reviewed with night crew members the recent BP policy changes concerning the use of traction devices on footware while working outside the rig. RUNPRD RIH to 12032' and tagged out on top of liner with CTC . RUNPRD TOH to 11500' RIH back to 11590' no obstructions, continue TOH following pressure schedule. Tag up w/ 700 psi w/ 8.9# fluid. Close TRSSSV and bleed off press RUNPRD Set back injector. Drop ball to open circ sub. LD 1"CSH singles. Clear floor of tools RUNPRD MU BTT LTP assy on two jts 2-3/8" STL tubing RUNPRD RIH w/ BHA #12 circ min rate following pressure schedule at 80'/min. Open TRSSSV w/ 700 psi assist RUNPRD 10000' 21.1 k RIH and sting into seal assy at 10293' CTD. Pressure BS (liner lap) to 1450 psi w/ 0.3 bbls of 8.9 ppg biozan/KCI/brine w/ 690 psi on CT, IA 10, OA 220 and held okay for 20 min. Can't pressure higher (and guarantee it will hold after setting) due to tool having been turned down to clear the 2.75 'D' nipple. Discuss-will remove packer and test at a higher pressure with seals only RUNPRD Bleed off BS to 600 psi. Pull stinger out of deployment sleeve 25.4k. POOH 65'/min filling from the BS while discuss some more. CPAI willing to live with limitations. RIH to 10272' RUNPRD PUH to ball drop spot at 10255'. circ to warm CT, discuss w/ crew. Load 5/8" aluminum ball RUNPRD Circ 0.87/0.77/1420 ball over gooseneck. Ball on seat at 41.41 bbls away. RIH to 10293'. PU to neutral wt 23k plus 1' Bring coil pressure to 1500psi. Slack-off coil wt to -1 k setting LTP. Bleed down coil to 800psi. Line up on BS. Double bllock choke line side. RUNPRD Pressure up BS to 2000psi for 30 min. Double block kill line side. Final pressure 1820psi. Bleed off all backside and coil. Bring up CTP to 3300psi and shear setting tools. Bleed off pressure. Printed: 11/27/2006 10:32:45 AM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: 1 C-14 Common Well Name: 1 C-14 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 ~ i Date rom - o Hours I Task Code NPT _ ,- - _ __- 11/22/2006 20:20 - 22:15 ~ 1.92 ~ CASE ~ P 22:15 - 23:00 0.75 WHSUB P 23:00 - 00:00 1.00 WHSUB P 11/23/2006 00:00 - 01:45 1.75 WHSUB P 01:45 - 03:50 2.08 WHSUB P 03:50 - 04:20 0.50 WHSUB P 04:20 - 04:35 0.25 WHSUB P 04:35-05:00 0.42 WHSUB P 05:00 - 05:15 0.25 WHSUB P 05:15 - 07:00 I 1.751 RIGD I P 07:00 - 09:00 2.00 RIGD P 09:00 - 12:00 3.00 BOPSU P Spud Date: 10/25/2006 Start: 10/25/2006 End: 11/23/2006 Rig Release: 11/23/2006 Rig Number: Phase Description of Operations RUNPRD TOH following pressure schedule. Close SSSV trapping 600psi. Hold PJSM review plan forward for LD tools and PU next BHA. Tag up observe well for possible flow. POST LD BHA. PU 6' stinger and nozzle. POST RIH pressure up well to 600psi and open SSSV had 540psi. Continue RIH POST RIH to 10250'. SW truck arrived started pumping downhole. POST Displacing wellbore with SW to 2500' POST Freeze protect from 2500' to surface with 22 bbls of diesel. Closed SSSV trapping 600psi. POST LD stinger assembly. POST With T-bar set BPV. Close MV & SV POST PJSM review procedures and hazards for blowing down coil reel with N2. POST Pump 10 bbls of corrosion inhiber into 2" coil followed with N2. RDMO SWS N2 pumper. Bleed off N2 to tiger tank POST Cut off CTC. Install internal grapple. Pull CT back to reel and secure Finish cleaning pits POST ND BOPE. NU tree cap and PT ~ 4000 Rig Released at 1200 hrs 11/23/06 Additional entries for this date can be found on iC-25 Printed: 11/27/2006 70:32:45 AM ~ ~ • • by BP Alaska Baker Hughes INTEQ Survey Report ~it~ .e ......,~ r Company; BP AmoCA Date: 11/20/2006 Time: 09:34:38 Page: I Field: Kuparuk Co-ordinate(NE) Reference: Well: 14, True North Site: KRU 1 C Pad Vertical (TVD) Reference: 1 C Pad Datum 102.0 Well: 14 Section (VS) Reference: Well (O.OON,O.OOE,62.65Azi) Wellpath: 1 C-14A Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 10701.03 6559.30 TIP 10742.00 6590.53 KOP 14157.00 6591.55 TD Survey: MWD Start Date: 11/9/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10701.03 40.25 68.39 6559.30 6457.30 3078.51 7508.91 5971812.50 569628.83 8083.88 0.00 MWD 10742.00 40.43 67.64 6590.53 6488.53 3088.44 7533.50 5971822.63 569653.34 8110.28 1.26 MWD 10771.05 46.68 68.25 6611.57 6509.57 3095.95 7552.05 5971830.29 569671.82 8130.20 21.56 MWD 10800.71 59.18 68.70 6629.42 6527.42 3104.61 7574.02 5971839.13 569693.72 8153.70 42.16 MWD 10830.65 72.51 69.07 6641.64 6539.64 3114.42 7599.45 5971849.16 569719.06 8180.79 44.54 MWD 10860.85 86.11 69.41 6647.23 6545.23 3124.91 7627.13 5971859.88 569746.66 8210.20 45.05 MWD 10894.17 92.23 71.84 6647.71 6545.71 3135.96 7658.55 5971871.18 569777.97 8243.18 19.76 MWD 10927.93 94.01 75.78 6645.87 6543.87 3145.36 7690.91 5971880.85 569810.26 8276.24 12.79 MWD 10954.02 96.26 79.52 6643.54 6541.54 3150.91 7716.29 5971886.61 569835.58 8301.34 16.68 MWD 10995.45 97.38 85.33 6638.61 6536.61 3156.34 7757.05 5971892.37 569876.29 8340.03 14.18 MWD 11036.69 94.97 87.13 6634.18 6532.18 3159.03 7797.96 5971895.41 569917.17 8377.61 7.28 MWD Field: Kuparuk 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 : bggm2006 Site: KRU 1 C Pad UNITED STATES :North Slope Site Posftioa: Northing: 5968605.00 ft Latitude: 70 19 29.107 N From: Map Easting: 562247.20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground LeveL• 0.00 ft Grid Convergence: 0.48 deg Well: 14 Slot Name: Well Position: +N/-S 68.05 ft Northing: 5968672.21 ft Latitude: 70 19 29.777 N +E/-W -100.26 ft Easting : 562146.39 ft Longitude: 149 29 45.844 W Position Uncertainty: 0.00 ft Wellpath: 1 G14A Drilled From: 1 C-14 Tie-on Depth: 10742.00 ft Current Datum: 1 C Pad Datum Height 102.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/19/2006 Declination: 23.83 deg Field Strength: 57615 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 102.00 0.00 0.00 62.65 Survey Program for DeSnihve Wellpath Date: 11/20/2006 Validated: No Version: 7 Actual From To Survey Tookode Tool Name ft ft 121.00 10701.03 MWD (121.00-10980.00) (0) MWD MWD -Standard 10742.00 14157.00 MWD (10742.00-14157.00) MWD MWD -Standard • • by BP Alaska ~•$ Baker Hughes INTEQ Survey Report uvTE 4 Company: BP Amoco Date: 11/20/2006 Time: 09:34:38 Page: 2 Field: Kuparuk Co-ordinate(NE) Reference: Well: 14, True North Site: KRU 1 C Pad Vertical (TVD) Reference: 1C Pad Datum 102.0 Well: 14 Sectio n (VS) Reference: Well (O.OON,O. OOE,62.65Azi) Weltpath: 1C- 14A Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E/V1' MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11070.98 92.81 90.14 6631.85 6529.85 3159.84 7832.15 5971896.50 569951.36 8408.35 10.79 MWD 11098.79 91.77 91.69 6630.74 6528.74 3159.40 7859.93 5971896.29 569979.14 8432.83 6.71 MWD 11129.46 90.97 87.00 6630.01 6528.01 3159.75 7890.58 5971896.89 570009.78 8460.21 15.51 MWD 11158.80 89.34 82.72 6629.93 6527.93 3162.38 7919.80 5971899.76 570038.97 8487.37 15.61 MWD 11189.42 89.98 76.70 6630.11 6528.11 3167.85 7949.91 5971905.48 570069.04 8516.62 19.77 MWD 11228.26 92.16 71.89 6629.38 6527.38 3178.35 7987.28 5971916.29 570106.31 8554.64 13.59 MWD 11258.02 92.99 71.05 6628.05 6526.05 3187.80 8015.47 5971925.97 570134.42 8584.02 3.97 MWD 11288.49 93.89 66.78 6626.22 6524.22 3198.74 8043.84 5971937.15 570162.70 8614.25 14.30 MWD 11320.71 94.62 62.35 6623.83 6521.83 3212.54 8072.85 5971951.18 570191.59 8646.35 13.90 MWD 11350.07 93.98 59.35 6621.62 6519.62 3226.80 8098.42 5971965.65 570217.03 8675.61 10.42 MWD 11380.48 94.69 57.02 6619.33 6517.33 3242.78 8124.18 5971981.85 570242.66 8705.84 7.99 MWD 11410.36 94.75 59.87 6616.87 6514.87 3258.36 8149.56 5971997.64 570267.90 8735.54 9.51 MWD 11446.61 94.07 63.75 6614.08 6512.08 3275.43 8181.41 5972014.97 570299.61 8771.67 10.84 MWD 11475.57 94.50 66.20 6611.91 6509.91 3287.65 8207.57 5972027.40 570325.67 8800.52 8.57 MWD 11511.09 95.59 70.21 6608.79 6506.79 3300.78 8240.42 5972040.80 570358.40 8835.73 11.66 MWD 11542.33 94.35 75.46 6606.08 6504.08 3309.96 8270.14 5972050.23 570388.05 8866.35 17.21 MWD 11572.46 93.06 78.93 6604.13 6502.13 3316.62 8299.46 5972057.13 570417.30 8895.45 12.26 MWD 11601.96 92.85 81.01 6602.61 6500.61 3321.76 8328.47 5972062.50 570446.27 8923.57 7.08 MWD 11629.91 92.16 86.28 6601.39 6499.39 3324.84 8356.21 5972065.82 570473.98 8949.63 19.00 MWD 11660.20 93.18 88.58 6599.98 6497.98 3326.20 8386.43 5972067.43 570504.19 8977.10 8.30 MWD 11690.24 93.42 90.70 6598.25 6496.25 3326.39 8416.42 5972067.87 570534.17 9003.82 7.09 MWD 11720.16 91.98 87.18 6596.84 6494.84 3326.94 8446.30 5972068.67 570564.04 9030.61 12.70 MWD 11750.05 92.44 83.98 6595.69 6493.69 3329.24 8476.07 5972071.21 570593.79 9058.12 10.81 MWD 11789.96 94.25 77.29 6593.35 6491.35 3335.72 8515.36 5972078.02 570633.02 9095.99 17.34 MWD 11823.22 92.93 72.95 6591.27 6489.27 3344.24 8547.43 5972086.80 570665.02 9128.39 13.61 MWD 11853.04 93.39 69.30 6589.63 6487.63 3353.88 8575.60 5972096.66 570693.10 9157.84 12.32 MWD 11886.90 94.32 60.53 6587.35 6485.35 3368.18 8606.17 5972111.22 570723.55 9191.56 25.99 MWD 11920.24 94.82 57.95 6584.69 6482.69 3385.18 8634.72 5972128.45 570751.96 9224.73 7.86 MWD 11952.88 96.08 53.45 6581.59 6479.59 3403.48 8661.56 5972146.98 570778.64 9256.98 14.26 MWD 11980.73 96.57 50.84 6578.52 6476.52 3420.47 8683.41 5972164.14 570800.35 9284.19 9.48 MWD 12010.48 96.20 48.24 6575.21 6473.21 3439.65 8705.90 5972183.51 570822.68 9312.98 8.77 MWD 12041.71 96.29 44.47 6571.81 6469.81 3461.07 8728.37 5972205.11 570844.96 9342.78 12.00 MWD 12071.04 97.10 42.04 6568.39 6466.39 3482.29 8748.33 5972226.49 570864.74 9370.25 8.68 MWD 12100.44 96.73 45.58 6564.85 6462.85 3503.35 8768.53 5972247.71 570884.77 9397.87 12.02 MWD 12130.29 95.30 48.16 6561.72 6459.72 3523.64 8790.19 5972268.18 570906.26 9426.43 9.84 MWD 12160.34 93.61 50.47 6559.39 6457.39 3543.17 8812.91 5972287.90 570928.81 9455.58 9.51 MWD 12192.89 91.86 54.30 6557.83 6455.83 3563.00 8838.66 5972307.95 570954.39 9487.57 12.92 MWD 12220.60 90.66 57.71 6557.22 6455.22 3578.49 8861.62 5972323.62 570977.23 9515.08 13.04 MWD 12249.24 89.59 61.77 6557.16 6455.16 3592.92 8886.35 5972338.25 571001.83 9543.68 14.66 MWD 12280.74 90.75 65.88 6557.07 6455.07 3606.81 8914.62 5972352.38 571029.98 9575.16 13.56 MWD 12313.03 91.06 68.97 6556.56 6454.56 3619.20 8944.42 5972365.01 571059.68 9607.33 9.62 MWD 12340.10 89.98 71.80 6556.31 6454.31 3628.29 8969.92 5972374.31 571085.10 9634.15 11.19 MWD 12370.41 90.60 76.06 6556.16 6454.16 3636.68 8999.04 5972382.94 571114.14 9663.87 14.20 MWD 12400.54 89.77 79.21 6556.06 6454.06 3643.13 9028.46 5972389.63 571143.51 9692.97 10.81 MWD 12430.35 91.09 76.78 6555.84 6453.84 3649.33 9057.62 5972396.07 571172.61 9721.71 9.28 MWD 12460.43 92.23 74.40 6554.97 6452.97 3656.81 9086.74 5972403.79 571201.66 9751.01 8.77 MWD 12490.42 93.18 70.27 6553.55 6451.55 3665.90 9115.28 5972413.12 571230.12 9780.54 14.12 MWD 12520.00 93.33 69.25 6551.87 6449.87 3676.12 9142.98 5972423.56 571257.74 9809.84 3.48 MWD 12549.55 92.97 60.16 6550.24 6448.24 3688.71 9169.63 5972436.37 571284.28 9839.30 30.74 MWD 12580.91 92.07 57.45 6548.87 6446.87 3704.94 9196.43 5972452.82 571310.94 9870.55 9.10 MWD 12611.08 93.80 54.45 6547.32 6445.32 3721.80 9221.39 5972469.89 571335.76 9900.47 11.47 MWD 12641.40 93.27 51.95 6545.45 6443.45 3739.93 9245.62 5972488.22 571359.84 9930.32 8.41 MWD 12676.31 92.16 49.67 6543.80 6441.80 3761.96 9272.64 5972510.47 571386.68 9964.45 7.26 MWD • by BP Alaska Baker Hughes INTEQ Survey Report ~t~ s llYTEQ Company: BP Amoco Date: 11/20/2006 Time: 09:34:38 Page: 3 Field: Kuparuk Co-ordiuate(NE) Refereuce: Well: 14, True North Site: KRU 1 C Pad Vertical (TVD) Reference: 1 C Pad Datum 102.0 Well: 14 Sectio n (VS) Refe rence: Well (O.OON,O. OOE,62.65Azi) Wellpath: 1 C- 14A Survey Calcalatiou Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 12706.09 90.72 46.69 6543.05 6441.05 3781.81 9294.83 5972530.50 571408.69 9993.27 11.11 MWD 12736.47 91.00 43.17 6542.59 6440.59 3803.31 9316.28 5972552.18 571429.96 10022.20 11.62 MWD 12767.79 91.18 39.83 6542.00 6440.00 3826.76 9337.02 5972575.80 571450.51 10051.40 10.68 MWD 12797.39 90.72 37.37 6541.51 6439.51 3849.89 9355.49 5972599.07 571468.78 10078.43 8.45 MWD 12823.96 90.23 35.06 6541.28 6439.28 3871.33 9371.18 5972620.64 571484.30 10102.22 8.89 MWD 12856.46 89.77 32.08 6541.28 6439.28 3898.40 9389.15 5972647.86 571502.04 10130.62 9.28 MWD 12887.22 90.45 35.33 6541.23 6439.23 3923.99 9406.22 5972673.58 571518.89 10157.53 10.79 MWD 12916.79 91.52 38.35 6540.72 6438.72 3947.65 9423.94 5972697.38 571536.42 10184.14 10.83 MWD 12947.50 92.11 43.03 6539.74 6437.74 3970.91 9443.95 5972720.81 571556.23 10212.60 15.35 MWD 12975.66 91.06 48.07 6538.96 6436.96 3990.62 9464.04 5972740.68 571576.15 10239.50 18.28 MWD 13005.76 89.22 53.43 6538.89 6436.89 4009.66 9487.34 5972759.91 571599.29 10268.94 18.83 MWD 13038.46 89.65 52.83 6539.21 6437.21 4029.28 9513.49 5972779.74 571625.28 10301.19 2.26 MWD 13070.12 91.52 49.22 6538.89 6436.89 4049.18 9538.10 5972799.85 571649.72 10332.19 12.84 MWD 13114.23 90.69 34.88 6538.04 6436.04 4081.85 9567.56 5972832.76 571678.91 10373.36 32.56 MWD 13132.92 89.68 32.78 6537.97 6435.97 4097.37 9577.97 5972848.36 571689.18 10389.74 12.47 MWD 13163.52 89.34 30.92 6538.24 6436.24 4123.36 9594.11 5972874.49 571705.11 10416.02 6.18 MWD 13193.38 90.97 28.35 6538.16 6436.16 4149.31 9608.88 5972900.56 571719.66 10441.05 10.19 MWD 13226.72 89.03 25.75 6538.16 6436.16 4179.00 9624.04 5972930.37 571734.57 10468.16 9.73 MWD 13256.76 87.02 23.34 6539.19 6437.19 4206.31 9636.51 5972957.77 571746.81 10491.78 10.44 MWD 13286.35 86.84 19.12 6540.78 6438.78 4233.84 9647.20 5972985.39 571757.28 10513.93 14.25 MWD 13324.76 88.05 17.99 6542.49 6440.49 4270.22 9659.41 5973021.86 571769.19 10541.49 4.31 MWD 13354.64 88.05 16.48 6543.51 6441.51 4298.74 9668.26 5973050.45 571777.80 10562.45 5.05 MWD 13387.47 89.68 12.46 6544.16 6442.16 4330.51 9676.46 5973082.29 571785.73 10584.33 13.21 MWD 13417.35 89.83 10.76 6544.28 6442.28 4359.78 9682.47 5973111.61 571791.50 10603.12 5.71 MWD 13447.05 89.00 11.02 6544.59 6442.59 4388.95 9688.08 5973140.81 571796.87 10621.50 2.93 MWD 13476.76 87.89 15.78 6545.39 6443.39 4417.83 9694.96 5973169.75 571803.51 10640.88 16.45 MWD 13506.35 86.30 13.59 6546.89 6444.89 4446.41 9702.46 5973198.39 571810.76 10660.67 9.14 MWD 13537.23 86.29 14.50 6548.89 6446.89 4476.30 9709.93 5973228.34 571817.99 10681.05 2.94 MWD 13567.39 85.31 15.96 6551.10 6449.10 4505.33 9717.84 5973257.43 571825.65 10701.40 5.82 MWD 13596.99 89.83 21.85 6552.35 6450.35 4533.28 9727.41 5973285.46 571835.00 10722.75 25.06 MWD 13625.64 89.06 22.61 6552.63 6450.63 4559.80 9738.25 5973312.06 571845.62 10744.56 3.78 MWD 13657.29 86.58 31.21 6553.84 6451.84 4587.98 9752.55 5973340.35 571859.68 10770.20 28.26 MWD 13693.65 81.19 30.61 6557.71 6455.71 4618.98 9771.11 5973371.51 571877.98 10800.94 14.91 MWD 13727.38 79.51 27.59 6563.36 6461.36 4648.03 9787.29 5973400.69 571893.91 10828.65 10.13 MWD 13759.82 82.33 20.67 6568.49 6466.49 4677.25 9800.36 5973430.01 571906.75 10853.69 22.79 MWD 13790.85 84.81 16.35 6571.97 6469.97 4706.48 9810.15 5973459.32 571916.29 10875.81 15.98 MWD 13821.12 85.55 13.96 6574.51 6472.51 4735.59 9818.03 5973488.49 571923.93 10896.19 8.24 MWD 13853.35 88.12 9.49 6576.29 6474.29 4767.09 9824.57 5973520.04 571930.21 10916.46 15.98 MWD 13881.95 89.52 6.67 6576.88 6474.88 4795.40 9828.59 5973548.38 571933.99 10933.04 11.01 MWD 13910.47 90.85 3.74 6576.79 6474.79 4823.80 9831.17 5973576.79 571936.34 10948.38 11.28 MWD 13941.50 $8.45 358.20 6576.98 6474.98 4854.81 9831.70 5973607.80 571936.61 10963.10 19.46 MWD 13972.09 86.04 358.12 6578.45 6476.45 4885.34 9830.72 5973638.33 571935.38 10976.25 7.88 MWD 14001.34 86.72 353.76 6580.29 6478.29 4914.45 9828.65 5973667.42 571933.07 10987.79 15.06 MWD 14031.48 86.26 350.74 6582.14 6480.14 4944.26 9824.60 5973697.19 571928.77 10997.88 10.12 MWD 14060.33 86.08 347.66 6584.07 6482.07 4972.53 9819.20 5973725.41 571923.14 11006.08 10.67 MWD 14090.77 85.67 344.43 6586.26 6484.26 5001.99 9811.88 5973754.81 571915.57 11013.12 10.67 MWD 14113.54 85.36 341.97 6588.04 6486.04 5023.72 9805.32 .5973776.48 571908.84 11017.27 10.86 MWD 14157.00 85.36 341.97 6591.55 6489.55 5064.91 9791.91 5973817.55 571895.09 11024.29 0.00 MWD r-~ r-~ 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: CIE:'3_t'~'~ ~ ~`3 ~3Let~'?!~3_,s~c~'#t:~ ?C.LI~ S~ s a f ~ c~~i~.z~'."...3 :' 3..~U e~~~~.. i~i.'yi~+r'.FU ~~~?{~.:~~,t~C~.'. c~t~. beta ~3~~i'; .~~i:i{E'ntit£'Sf~ ~~31~tefTei~3.Stc'e'~~i.:~?C.~.l~i Contractor: Nordic Rig No.: 2 DATE: 11/21/06 Rig Rep.: Mckeirnan / Sloan Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich / Sevcik E-Mail st~~ac~~~~~rlcrE€~_;~ic "~C?t~~~?~ES~If'F ~?~3:~_~?3 Well Name: 1 C-14A PTD # 206-001 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-4000 Annular: 250-2500 Valves: 250-4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Levet Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves ' 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity. Test Result 200 psi Attained 18 sec P No. Valves 14 P Full Pressure Attained 70 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2125 Test Results Number of Failures: 0 Test Time: 6 Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,€iE~3.-rE~4~ ~t~r~itt_~~~'~t ~K_u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES X)OC NO c - Oper./Rig Waived By Chuck Scheve c -Database Date 11/19/06 Time 10:00 c -Trip Rpt File Witness c -Inspector Test start 07:00 Finish 13:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 11-21-06p.xls 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ~~rti~3_~~~f f_~ x:u~ .ESE°?...~E'g~ ~ J 1 a +~L'+C.~~:v ~.`~~d:~~~~ . i)e'~.jr`tAc~~~r'.~CJ~~~e~~::~f..'{. :F~_c~lE:~.e~.] ~~3fbi"b..E:.£?:~~E`t~~S~£'.tt ~~~ITEi~3.S~cFlfi: ~?C_~i~4 . Contractor: Nordic Rig No.: 2 DATE: 11/6/06 Rig Rep.: Holmes Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Hildreth / Feketi E-MailS~t~c~~~~~rl~rE.~_:~ic~'~L?U~~?E~S~fE'F~~?~):f;~r3 Well Name: 1C-14A PTD # 206-001 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-4000 Annular: 250-3200 Valves: 250-4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves NT HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 2950 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 28 sec P No. Valves 14 P Full Pressure Attained 93 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4~ 2050 Test Results Number of Failures: 0 Test Time: 7 Hours Com onents tested 28 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~i~~3_.-r€tr~~ ~~~rfit3_s~~t~. ~>t_~s Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By John Crisp c -Database Date 11/6/06 Time 10:00 c -Trip Rpt File Witness James Lott c -Inspector Test start 12:00 Finish 19:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 11-6-06p.xls MEMORANDUM To: Jim Regg ~' , ,.- - P.I. Supervisor '!-; ~ r i FROIVt: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-14A KUPARUK RIV UNIT IC-14A Src: Inspector NON-CONFIDENTIAL Qo~ ~b~ Reviewed By: P.I. Suprv ,~~t j~- Comm Well Name: KUPARUK RIV UNIT 1C-14A API Well Number 50-029-22861-01-00 Inspector Name: Jeff Jones Insp Num: mitiJ060530163647 Permit Number: 206-001-0 Inspection Date: 5/30/2006 Rel Insp Num :/ Packer Depth P retest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I IC-14A (Type Inj. N 'j'am 6259 ~ IA ~ 0 2000 1985 1950 ~ 1950 P.T. ~ 2060010 ~TypeTOSt ~~ SPT ., Test pSl ~I 1564.75 ~ DA ~~ 280 j 50~ 0 480 ~ 450 ~ 430 Interval 4YRTST p~ P Tubing ~ 1400 i 1400 ~ 1400 I~ 1400 ~ 1400 ~ Notes 2.7 bbls diesel pumped. 1 well house inspected; no exceptions noted. Wednesday, May 31, 2006 Pave 1 of i RE: 1 C-14A • • Subject: RE:1C-14A' From: "McLaubhln, Scan ~'[" <;Sean.McLaugh~in u bp.cam> Date: Thu,. OS Jan 2i~~16 1 ~~:i~1:2? -09Q0 To: ~hhomas ~-launc~cr ~~-tom maunclcr(u aclmin.statc.ak.us--- Tom, i ~ ~ o ~ 'Q~~ The West Sak 24 abandonment looks like it was handled properly. s e an ~~~~ ~`+EV\iEW`«~ °1~c~ wfc `~ °~~ rc ~ ~C~J'rCs.9 ~ ~ `~-~ \^~ \{ -----Ori final Messa e----- ~ ~' `~~ ~~ SC9,~~~~C~,h~ G~Q~©r~V g g From: Thomas Maunder [mailtc:tom maur_derc:)admin.state.ak,us] __._---------_ _ __. --- _ _ __ __ ___ _ __ ___ _ ____ ----------- _ ~~~~y %~ Sent: Wednesday, January 04, 2006 4:16 PM To: McLaughlin, Sean M i /c,~ Subject: Re: 1C-14A /J If you would take a look at the West Sak 24 and give me your assessment, then I think I will have all I need. Thanks, Tom Maunder, PE AOGCC Sean, Your information on the well identities confirms what I have found. Yes, I did see the bond log for iC-14. I had looked at the original over here and the cement on that one looks good. No problem there. West Sak 24 is the real close approach, 250' as I remember from your document and yes it is abandoned. Have you looked at that well file to be sure it is/was done properly? I suspect that the abandonment was done properly and I will likely check that, but only to confirm what you would state about the well from your research. McLaughlin, Sean M wrote, On 1/4/2006 4:01 PM: Tom, Other than West Sak 24 (which has been p&a'd) there in not another well within a 1/4 mile. West Sak 24 was listed in the permit to drill summary. The next closest well is 1C-22 which is 1470' away. I ', usually list wells of this proximity in the permit summary but not sure why it didn't make it this time. 1C-22 is currently an active well. Baker is finishing up the anti-collision work and I can send you a copy ', if you want. ', Did you get a copy of the CBL for 1C-14? Since we are kicking off in ', the C will this be sufficient to show proof of isolation between the zones. Thanks, sean -----Original Message----- From: Thomas Maunder [mailto:to-r mauz:der'~?admin.state.ak.us] Sent: Wednesday, January 04, 2006 1:30 PM To: McLaughlin, Sean M Subject: 1C-14A Sean, I am reviewing the permit to drill. I don't find anything in the application regarding the existence of or mechanical condition of any wells within 1/4 mile radius beginning at the top of the Kuparuk in 1 of 2 1/5/2006 1:58 PM RE: 1 C-14A 1C-14 and continuing along the trajectory to TD. Please refer to 20 AAC 25.402 (b). Thanks in advance for your attention to this matter. Tom Maunder, PE AOGCC 7 'Content-Description: West Sak 24 P&A report.PDF West Sak 24 P&A report.PDF :Content-Type: application octet-stream Content-Encoding: base64 __ _ __ 2 of 2 1/5/2006 1:58 PM • ;- gg ~.... _. 4 A ...„ ~ ~ ~~ t ~~ ~ ~~ 4 - ~°~ .~%~ .. __ ~o~ r v- n -.a d ._ ~. ~ 3 ., ~..~ Sean McLaughlin CT Drilling Engineer Conoco Phillips Alaska, Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit, Kuparuk 1 C-14A Conoco Phillips Alaska, Inc. Permit No: 206-001 Surface Location: 1566' FNL, 1139' FWL, Sec. 12, T 11 N, R 10E, UM Bottomhole Location: 3503' FSL, 836' FWL, Sec. 05, T11 N, R 11 E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the ommission to witness any required test. Contact the Commission's petrole fi ld inspector at (907} 659- 3607 (pager). ~JR1h~a Chairman DATED this da of Janua , 2006 y D' cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • STATE OF ALASKA ~~Q~1..d ALASKA OIL AND GAS CONSERVATION COSIOI~Y,,~` PERMIT TO DRILL ~l~ SAN 0 ~ 2Q~s 20 AAC 25.005 Alaska Oil & Gas Cons. Comrrlssiolt 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Oil i~Qone ^ Stratigraphic Test ®Service - ^ Development Gas Single one ~l~' ~- 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ° 11. Well Name and Number: Kuparuk 1C-14A 3. Address: do P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 14200 ' TVD 6527ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface:. 1566' FNL 1139' FWL SEC 12 T11N R10E UM ' 7. Property Designation: ADL 028242 River Pool , , , , . , Top of Productive Horizon: 1502' FSL, 1550' FEL, SEC. 06, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 27, 2006 Total Depth: 3503' FSL, 836' FWL, SEC. 05, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1750' '' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562146 ' y- 5968672 ~ Zone- ASP4 10. KB Elevation (Height above GL): 41' feet t5. Distance to Nearest Well Within Pool w. Sak 24 is offset by 250' (PaA'd) 16. Deviated Wells: Kickoff Depth: 10742 ~ feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)-~/~- Downhole: 4491 Surface: 3836 ~ '~ ' ~D 18. asmg rogram: Size .Specifications Setting Depth To Bottom uantity o 'ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 3915' 10285' 6248' 14200' 6527' 9 cu ft Class 'G' & Slotted Liner 19. PRESENT W ELL CONDITI ON SUMM ARY (To be comp leted for Redrill AND Re-e ntry Operations) Total Depth MD (ft): 10980 Total Depth TVD (ft): 6772 Plugs (measured): None Effective Depth MD (ft): 10714 Effective Depth TVD (ft): 6569 Junk (measured): None Casin Len th Size Cement Volume MD TVD r 121' 16" 9 cu ds Hi h Earl 121' 121' 7292' 9-5/8" 12 sx AS III LW, 348 sx'G', 60 sx AS I 7292' 4525' 10503' 7" 130 sx Class 'G' 10503' 6409' r in 680' 4-1/2" 130 sx Class 'G' 10300' - 10980' 6259' - 6772' Perforation Depth MD (ft): 10670' - 10716' Perforation Depth TVD (ft): 6536' - 6571' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certity that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer ~ Prepared By Name/Number. Si nature ~- r~ Phone 564-4387 Date 1 3 0 ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill _ Number: ~}~~ "~~}1 API Number: 50- 029-22861-01-00 Permit Approval Date: - -~ See cover letter for other requirements Conditions of Approval: Samples qui ed ^ Yes .r ~ No Mud Log Required ^ Yes ~ No Hydrog Sulf' a Measures Yes ^ No Directional Survey Required ['Yes `; No Other:1.11?C~Q - ~ Qb~~~c~. C'v.c~p4~c~~ 3OAi~c.aS,~~~(~~(.~-l~ c).C~~~fic~~\rc eE~ ~aA~cas.o~co t~~ , APPROVED BY s0 ~D A roved B THE COMMISSION Date 5~~'L G Form 10-401 sed O6 4 ' i ¢ Submit In Duplicate ~ ~.~ ' ~RU 1 C-14A Sidetrack -Coiled Tul~ Drilling Summary of Operations: A coiled tubing drilling unit will drill a lateral in KRU 1C-14 using the managed pressure drilling technique ~' (MPD, see description below). 1C-14A will be apre-produced injector. The horizontal lateral will target ~ Kuparuk C sand reserves for production. CTD Drill and Complete 1C-14A: Planned for .Tanuary 27, 2006 Pre-Rig Work 1. DHD MIT-IA, and OA. 2. DHD PPPOT-T & IC. 3. DHD PT Master & Swab to 4500 psi. 4. DHD Drawdown test on Master & Swab to 0 psi. 5. DHD Drawdown test SSSV. 6. S Obtain SBHP (3-5 day shut-in); Drift & tag PBTD. 7. C FCO to 10800' 8. S Drift and Tag; Caliper iog to PBTD 9. S Run dummy whipstock drift (2.7" x 10') 10.E Set 3-1/2" x 4-1/2"Baker TTWS at 10742' 11. C P&A liner - 15.8 ppg cmt squeeze 12. O PT cement plug to 1500 psi. 13. O Torque wellhead bolts to spec. 14. O Bleed gas lift and production flowlines down to zero and blind flange 15. O Remove wellhouse, drill mouse hole, level pad Rig Work 16. MIRU Nordic 2. NU 7-1/16" BOPE, test . 17. Mill 2.74" window off a whipstock. The planned KOP is at 10742' in the C sand. 18. Dri113" bicenter hole horizontal lateral from window to 14,200' TD targeting Kuparuk C sands. 19. Complete with a 3 segmented 2 3/8" solid/slotted liner from TD to 10285' md. Use SSSV for liner run. 20. Cement liner from the 10670' to ~ 12500' . Slotted liner will be below this point. 21. Cleanout liner and mill baffle plate. 22. ND BOPE. RDMO Nordic 2. Post Rig work 23. Post CTD rig -Run GLVs. Mud Program: • Step 17: chloride-based biozan brine (8.6 ppg) • Steps 18-20: chloride-based Flo-Pro (8.6 ppg) ~' • Step 21: Seawater (8.4 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1C-14A: 2 3/8", 4.6#, L-80, STL o Solid/cemented liner 10285' and - 12500' and o Slotted liner from 1.2500' and - ]4200' and o A minimum of 8.75 bbls 15.8 ppg cement will be used for liner cementing. rKRU 1 C-14A Sidetrack -Coiled Tul~ Drilling Casing/Liner Information 9 5/8", L-80, 40#, Burst 5750; collapse 3090 psi. 7", L-80, 26#, Burst 7240; collapse 5410 psi 4-1/2", L-80, 12.6#, Burst 8431; collapse 7500 psi Well Control: • Two well bore volumes 0250 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1C-14A - • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1C-14A is W. Sak 24 which is offset by 250'. W. Sak 24 has been P&A'd. The KPA boundary is 1750' away. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • A cement bond log is available for the 4-1/2" liner. Since the new side track is kicking off in zone (C sand) it is not necessary to run another bond log. A copy of the log is attached for reference. Hazards 1C-14A lateral will cross one mapped fault. Lost circulation risk is moderate.' Well 1C-16 has the highest recorded H2S level on the pad at 100 ppm H2S. All H2S monitoring equipment will be operational Reservoir Pressure • The most recent SBHP survey (12-26-OS) was gauged at 4491 psi after a short term shut-in. The pressure is continuing to drop as the well remains shut in. The EMW is 13.2 ppg at 6553' TVD. Max. surface pressure with gas (0.1 psi/ft) to surface is 3836 psi. ~ - Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1C-14 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the inte rity of the BOP equipment. r~~-~.~.~~'~'`'1 ~l5 Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. This well has a tubing retrievable sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. However, it is still possible that deployment of the BHA under trapped wellhead pressure would be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2- 3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. •KRU 1C-14A Sidetrack -Coiled Tu Drillin 9 Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 1C-14A TD: • Estimated reservoir pressure: 3200 psi at 6527' TVD, 9.5 ppg EMW. ~• • Expected annular friction losses while circulating: 1278 psi (based on 90 psi/1000 ft) • Planned mud density: 8.6 ppg equates to 2919 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 4197 psi or 12.4 ppg ECD • When circulation is stopped, a minimum of 1278 psi surface pressure will be applied to maintain constant BHP. KRU 1 C-14 ConocoPhillips Alaska, Inc. 1c-1a API: 500292286100 Well T INJ An le @ TS: 40 de @ 10664 sssv SSSV Type: TRDP Orig 3/4/1998 Angle @ TD: 40 deg @ 10980 (1830-1831, COT IetiOn: OD:3.500) TUBING Annular Fluid: Last W/O: Rev Reason: TAG FILL (0-10336, Reference L Ret L Date: Last U ate: 10/18/2004 oD:3.soo, Last Ta : 10714 TD: 10980 ftKB iD:2.ssz) Last Tag Date: 10/15/2004 Max Hole An le: 59 deg @ 7450 Casin Strin -ALL STRIN GS Gas Lint Descri tion Size To Bottom TVD Wt Grade Thread andrel/Dummy Vale 1 CONDUCTOR 16.000 0 121 121 62.58 H-40 (3635-3836. SURF. CASING 9.625 0 7292 4525 40.00 L-80 oD:s.soo) PROD. CASING 7.000 0 10503 6409 26.00 L-80 LINER 4.500 10300 10980 10980 12.60 L-80 Tubin Strin -TUBING Gas Lin - Size To Bottom TVD Wt Grade Thread andrel/Dummy 3.500 0 10336 6285 9.30 L-80 ABM EUR vai~re 2 (6523-6524 --- - Perforations Summa , OD:s.soo) Interval TVD Zone Status Ft SPF Date T Comment 10670 - 10696 6536 - 6555 C-4 26 4 1/21/1 99 APERF 2.5" HSD, 180 deg ph Gas Lin 10696 - 10716 6555 - 6571 C-4,C-3 20 4 3/17/1998 IPERF 2.5" HSD, 180 deg ph; andrel/Dummy oriented +/- 90 deg from Vale 3 low side (8x76-8476, OD:5 500) Gas Lift MandrelsNalves . St MD TVD Man Man Type V Mtr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3835 2588 Camco _ KBMM DMY 1.0 BK 0.000 0 3/8/1998 Gas Lin andrel/Dumm -- 2 6523' 4094 Camco KBMM DMY 1.0 BK 0.000 0 318/1998 y vaivea 3 8478 5195 Camco KBMM DMY 1.0 BK 0.000 0 3/8/1998 (9634-9635, -- 4 9634 5851 Camco KBMM DMY 1.0 BK 0.000 0 3/8/1998 OD:5.500) 5 10226 6206 Camco MMM DMY 1.5 RK 0.000 0 3/8/1998 Other lu s e ui ., etc. - JEWELRY De th TVD T e Descri tion ID Gas Lin 1830 1474 SSSV Camco TRDP-4E' 2.812 andrel/Dummy Vale 5 10272 6239 NIP Camco 'D' Ni le NO GO 2.750 ;10226-10227, - 10300 6259 PKR Baker 'ZXP' Pkr 4.438 OD:6.018) 10311 6267 SEAL Baker Locator SEAL ASSY 3.000 10314 6269 HNGR Baker'HMC' Liner Han er 4.438 NIP ;1oz7z-10273 10321 6274 SBE Baker 4.000 , OD:3.500) 10337 6286 TTL 2.992 General Notes Date Note 8/12/1998 As hakines in tubi @ 10190' PKR I ;10300-10301, OD:6.151) LINER ;10300-10980, OD:4.500, ' W 1:12.60) SEAL ;10311-10312, OD:4.000) SBE ;10321-10322, OD:4.500) TTL I ;10337-10338, OD:3.500) I Pert '10670-10696) Pert '10696-10716) KRU 1 C-14A C-sand Injector Proposed Completion 3-1/2" Camco TRDP-4E SSSV at 1830' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 9-5/8" 40# L-80 @ 7292' ol'1tC{0-~~"11 ~ 1 -5- Alaska, Inc. 3-1/2" Camco KBMM GLM's @ 3835'. 6523', 8478'. and 9634' MD • 3-1/2" Camco MMM GLM @ 10226' MD 3-1/z" Camco DS nipple, 2.75" min ID @ 10272' MD 2-3/8" STL liner top w/ "G" fishneck and seal bore @ 10290' MD Baker ZXP Packer w/SBE @ 10300' MD r' 2s# L-so @ 10503' MD 3-'/2" muleshoe @ 10336' MD KOP 10742' MD, in C-sand Bonsai circ sub/ Squeezed C sand perfs ~` baffle plate 10670' - 10716' and 3-%" x 4-%2" Baker whipstock 3" openhole 1 C-14A TD @ 14,200' and 2-3/8" slotted liner ConocoPhillips Baker Hughes INTEQ ~ INTEQ Planning Report ~T~4 Company: COnocoPhillips Alaska, Inc. Date: 1/2/2005 Time: 21:34:14 Page: t :Field: Kuparuk River Unit Co-ordinate(NE)'Reference: Well: 1 C-14, True North - Site: KRU 1C Pad Vertical (TVD) Reference: 1C-14 RKB 102.0 Well: 1G14 Section (VS) Reference: Well (O.OON,O.OOE,62.78Azi) VVelipath: Plan 4, 1G14A Survey Cakolatloa Method: Mi nimum Curvature ~ Db: Sybase Field: Kuparuk River Unit North Slope 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: bggm2004 Site: KRU 1 C Pad UNITED STATES :North Slope Site Position: Northing: 5968605. 00 ft Latltude: 70 19 29.107 N From: Map Eastiug: 562247. 20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 1 G14 Slot Name: Well Position: +N/-S 68.05 ft Northing: 5968672. 21 ft~ Latitude: 70 19 29.777 N +E/-W -100.26 ft Easting : 562146. 39 ft ' Longitude: 149 29 45.844 W Position Uncertainty: 0.00 ft Wellpath: PIan4,1G14A Drilled From: 1G14 Tie-on Depth: 10701.03 ft Current Datum: 1 C-14 RKB Height 102.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/29/2004 Declination: 24.54 deg Field Strength: 57589 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (1'VD) +N/-S +E/-W Direction ft ft ft deg 102.00 0.00 0.00 62.78 Plan: Plan #4 Date Composed: 12/29/2004 copy Lamar's plan4 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <- Latitude -a <-- Longitude --> Name Description TVD +N/-S +E/-W Northing. Easting Deg Min ..Sec Deg Min Sec Dip. Dir. ft ft ft: ft ft 1 C-14A Polygon 102.00 3028.02 7494.70 5971761.90 569615.04 70 19 59.520 N 149 26 6.997 W -Polygon 1 102.00 3028.02 7494.70 5971761.90 569615.04 70 19 59.520 N 149 26 6.997 W -Polygon 2 102.00 3229.70 8623.52 5971972.90 570742.04 70 20 1.492 N 149 25 34.029 W -Polygon 3 102.00 3454.78 9100.44 5972201.90 571217.04 70 20 3.700 N 149 25 20.094 W -Polygon 4 102.00 3751.73 9472.95 5972501.90 571587.04 70 20 6.616 N 149 25 9.205 W -Polygon 5 102.00 4241.58 9741.04 5972993.90 571851.04 70 20 11.430 N 149 25 1.358 W -Polygon 6 102.00 4856.72 9975.17 5973610.90 572080.04 70 20 17.477 N 149 24 54.496 W -Polygon 7 102.00 5244.17 9926.37 5973997.90 572028.04 70 20 21.288 N 149 24 55.907 W -Polygon 8 102.00 5176.06 9696.77 5973927.90 571799.04 70 20 20.621 N 149 25 2.615 W -Polygon 9 102.00 4875.90 9711.29 5973627.90 571816.04 70 20 17.669 N 149 25 2.203 W -Polygon 10 102.00 4578.19 9550.80 5973328.90 571658.04 70 20 14.743 N 149 25 6.901 W -Polygon 11 102.00 4086.92 9334.71 5972835.90 571446.04 70 20 9.914 N 149 25 13.230 W -Polygon 12 102.00 3788.65 9121.21 5972535.90 571235.04 70 20 6.983 N 149 25 19.476 W -Polygon 13 102.00 3150.89 7512.72 5971884.90 569632.04 70 20 0.728 N 149 26 6.468 W 1C-14A Faultl 102.00 3787.48 8657.15 5972530.88 570771.05 70 20 6.977 N 149 25 33.028 W -Polygon 1 102.00 3787.48 8657.15 5972530.88 570771.05 70 20 6.977 N 149 25 33.028 W -Polygon 2 102.00 3498.32 8912.79 5972243.88 571029.05 70 20 4.130 N 149 25 25.573 W -Polygon 3 102.00 3393.62 9237.96 5972141.88 571355.05 70 20 3.097 N 149 25 16.081 W -Polygon 4 102.00 3498.32 8912.79 5972243.88 571029.05 70 20 4.130 N 149 25 25.573 W 1 C-14A Target4 6544.00 4070.22 9536.61 5972820.87 571648.06 70 20 9.747 N 149 25 7.335 W 1 C-14A Target3 6552.00 3697.82 9217.48 5972445.88 571332.05 70 20 6.089 N 149 25 16.668 W 1 C-14A Target2 6569.00 3509.39 8904.88 5972254.88 571021.05 70 20 4.239 N 149 25 25.803 W 1 C-14A Targetl 6582.00 3403.44 8655.96 5972146.88 570773.05 70 20 3.200 N 149 25 33.076 W i ~ _ Cor~oc Phillips Baker Hughes INTEQ ~~ INTEQ Planning Report ~T~4 Company: ConocoPhillipsAiaska, Inc. Date: 1/2/2005' Time: 21:34:14 Page: 2 Fieid: Kuparuk River Unit Co-0rdinate(NE) Reference: Well: 1 C-14, True North :::Site: KRU 1 C Pad Vertical (1'VD) Reference: 1 C-14 RKB 102.0 Well: 1C-14 Sectio n (VS) Reference: Well (O.OON,O.OOE,62.78Azi) Wcllpath: Plan 4, 1G14A Survey Calculation Method: Minimum Curvature ~ Db: Sybase Targets Map Map <- Latitude -> <--- Longitude -> Name' Description TVD +N/-S +F/-W Northing Fasting. Deg Min Sec' Deg Min Sec Dip. Dlr. ft ft ft ft ft 1 C-14A Targets 6627.00 5069.53 9876.94 5973822.87 571980.07 70 20 19.571 N 149 24 57.357 W Annotation MD TVD ft ft 10701.03 6559.30 TIP 10742.00 6590.53 KOP ' 10762.00 6605.55 End of 9 Deg/100' DLS 10875.93 6647.06 End of 45 Deg/100' DLS 11075.93 6635.20 5 11350.93 6619.36 6 11500.93 6611.06 7 11625.93 6603.59 8 11950.93 6582.15 9 12200.93 6569.10 10 12375.93 6559.44 11 12575.93 6551.80 12 12700.93 6550.44 13 13000.93 6544.89 14 13100.93 6543.85 15 13450.93 6555.56 16 13550.93 6561.91 17 13725.93 6576.48 18 14200.00 6628.57 TD Plan Section Information MD ' Iucl Atim TVD +Nl-S +E/-W DILS Build Tnrn TFO Target ft deg deg ft ft ft deg/t00ft degl100ft degl100(t deg 10701.03 40.25 68.39 6559.30 3078.51 7508.91 0.00 0.00 0.00 0.00 10742.00 40.43 67.64 6590.53 3088.44 7533.50 1.26 0.44 -1.83 290.06 10762.00 42.23 67.64 6605.55 3093.46 7545.72 9.00 9.00 0.00 0.00 10875.93 93.50 67.64 6647.06 3132.29 7640.09 45.00 45.00 0.00 0.00 11075.93 93.20 91.68 6635.20 3167.85 7835.06 12.00 -0.15 12.02 90.00 11350.93 93.23 58.63 6619.36 3237.23 8096.78 12.00 0.01 -12.02 271.00 11500.93 93.07 76.65 6611.06 3293.97 8234.71 12.00 -0.11 12.02 90.00 11625.93 93.74 91.66 6603.59 3306.64 8358.49 12.00 0.54 12.01 87.00 11950.93 93.53 52.58 6582.15 3404.27 8661.17 12.00 -0.O6 -12.03 271.00 12200.93 92.31 82.60 6569.10 3498.33 8889.36 12.00 -0.49 12.01 91.50 12375.93 93.95 61.63 6559.44 3551.66 9054.72 12.00 0.94 -11.98 275.00 12575.93 90.37 37.88 6551.80 3679.88 9206.12 12.00 -1.79 -11.88 262.00 12700.93 90.87 22.89 6550.44 3787.40 9269.16 12.00 0.40 -11.99 272.00 13000.93 91.18 58.89 6544.89 4010.45 9462.28 12.00 0.10 12.00 89.20 13100.93 90.01 46.95 6543.85 4070.63 9541.91 12.00 -1.17 -11.94 264.50 13450.93 86.33 5.08 6555.56 4377.94 9692.02 12.00 -1.05 -11.96 264.50 13550.93 86.41 17.10 6561.91 4475.69 9711.18 12.00 0.08 12.02 90.00 13725.93 84.14 38.05 6576.48 4629.43 9791.42 12.00 -1.30 11.97 97.00 14200.00 84.30 340.85 6628.57 5075.14 9865.57 12.00 0.03 -12.07 267.00 • Cor~coPhillips Baker Hughes INTEQ ~ INTEQ Planning Report INTEQ Company: ConocoPhillips Alaska, Inc. Date: 1/'2/2005 Time: 21:34:14 Page: 3 Field: Kuparuk River Unit Co-ordinste(NE) Reference: Well: 1 C-14, True North Site:.. KRU 1C Pad Vertical (TVD) Reference: 1 C-14 RKB 102.0 Well: 1 G14 Section (VS) Reference: Well (O.OON,O.OOE,62.78Azi) Wellpatb: Plan 4, 1 G14A .Survey Calculation Method: Minimum Curvature - Db: Sybase Survey MD Iucl Azlm SSTVD N/S FJW MapN MspE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10701.03 40.25 68.39 6457.30 3078.51 7508.91 5971812.50 569628.83 0.00 8085.45 0.00 MWD 10713.74 40.31 68.16 6467.00 3081.55 7516.54 5971815.61 569636.44 1.26 8093.63 290.06 1G74A 10730.80 40.38 67.84 6480.00 3085.69 7526.78 5971819.83 569646.64 1.26 8104.63 290.23 1G14A .- 10742.00 40.43 67.64 6488.53 3088.44 7533.50 5971822.63 569653.34 1.26 8111.86 290.47 MWD 10762.00 42.23 67.64 6503.55 3093.46 7545.72 5971827.76 569665.51 9.00 8125.02 0.00 MWD 10795.27 57.20 67.64 6525.00 3103.09 7569.12 5971837.58 569688.83 45.00 8150.24 0.00 1 G14A 10800.00 59.33 67.64 6527.49 3104.62 7572.84 5971839.14 569692.54 45.00 8154.25 360.00 MWD 10875.93 93.50 67.64 6545.06 3132.29 7640.09 5971867.36 569759.55 45.00 8226.71 0.00 MWD 10900.00 93.50 70.53 6543.59 3140.86 7662.53 5971876.12 569781.92 12.00 8250.58 90.00 MWD 11000.00 93.38 82.55 6537.57 3164.05 7759.43 5971900.10 569878.61 12.00 8347.35 90.18 MWD 11075.93 93.20 91.68 6533.20 3167.85 7835.06 5971904.53 569954.20 12.00 8416.35 90.90 MWD 11100.00 93.24 88.79 6531.85 3167.76 7859.09 5971904.64 569978.23 12.00 8437.67 271.00 MWD 11200.00 93.35 76.77 6526.08 3180.28 7957.95 5971917.98 570076.97 12.00 8531.31 270.84 MWD 11300.00 93.30 64.75 6520.26 3213.12 8052.03 5971951.59 570170.77 12.00 8629.99 270.14 MWD 11350.93 93.23 58.63 6517.36 3237.23 8096.78 5971976.07 570215.31 12.00 8680.81 269.44 MWD 11400.00 93.21 64.52 6514.60 3260.54 8139.84 5971999.73 570258.17 12.00 8729.77 90.00 MWD 11500.00 93.07 76.54 6509.11 3293.75 8233.81 5972033.72 570351.85 12.00 8828.52 90.33 MWD 11600.00 93.62 88.55 6503.26 3306.69 8332.61 5972047.47 570450.54 12.00 8922.30 87.03 MWD 11625.93 93.74 91.66 6501.59 3306.64 8358.49 5972047.63 570476.41 12.00 8945.28 87.70 MWD 11700.00 93.85 82.76 6496.68 3310.23 8432.23 5972051.84 570550.11 12.00 9012.50 271.00 MWD 11800.00 93.85 70.73 6489.95 3333.06 8529.17 5972075.47 570646.85 12.00 9109.15 270.41 MWD 11900.00 93.68 58.71 6483.35 3375.60 8619.22 5972118.75 570736.54 12.00 9208.69 269.60 MWD 11950.93 93.53 52.58 6480.15 3404.27 8661.17 5972147.77 570778.24 12.00 9259.10 268.81 MWD 12000.00 93.36 58.48 6477.19 3431.98 8701.53 5972175.80 570818.37 12.00 9307.67 91.50 MWD 12100.00 92.90 70.49 6471.71 3474.91 8791.48 5972219.47 570907.95 12.00 9407.29 91.85 MWD 12200.00 92.32 82.49 6467.14 3498.21 8888.43 5972243.57 571004.70 12.00 9504.16 92.51 MWD 12300.00 93.29 70.74 6462.25 3521.10 8985.46 5972267.26 571101.53 11.78 9600.92 275.01 MWD 12375.93 93.95 61.63 6457.44 3551.66 9054.72 5972298.40 571170.52 12.00 9676.49 274.42 MWD 12400.00 93.54 58.77 6455.87 3563.60 9075.56 5972310.50 571191.26 12.00 9700.48 262.00 MWD 12500.00 91.77 46.88 6451.22 3623.86 9155.00 5972371.41 571270.19 12.00 9798.68 261.81 MWD 12575.93 90.37 37.88 6449.80 3679.88 9206.12 5972427.85 571320.84 12.00 9869.77 261.26 MWD 12600.00 90.47 34.99 6449.63 3699.24 9220.41 5972447.32 571334.97 12.00 9891.33 272.00 MWD 12700.00 90.87 23.00 6448.46 3786.54 9268.79 5972535.01 571382.62 12.00 9974.29 271.98 MWD 12800.00 91.02 34.77 6446.80 3874.02 9316.83 5972622.88 571429.93 11.78 10057.03 89.18 MWD 12900.00 91.12 46.78 6444.92 3949.59 9382.01 5972698.98 571494.48 12.00 10149.56 89.40 MWD 13000.00 91.18 58.78 6442.91 4009.96 9461.48 5972760.00 571573.43 12.00 10247.84 89.62 MWD 13100.00 90.02 47.06 6441.85 4069.99 9541.22 5972820.69 571652.67 11.78 10346.21 264.45 MWD 13200.00 88.88 35.11 6442.82 4145.22 9606.82 5972896.45 571717.63 12.00 10438.96 264.50 MWD 13300.00 87.78 23.16 6445.74 4232.37 9655.40 5972983.99 571765.48 12.00 10522.02 264.62 MWD 13400.00 86.79 11.18 6450.50 4327.63 9684.83 5973079.48 571794.13 12.00 10591.77 264.96 MWD 13450.93 86.33 5.08 6453.56 4377.94 9692.02 5973129.84 571800.90 12.00 10621.18 265.53 MWD 13500.00 86.35 10.98 6456.69 4426.40 9698.86 5973178.36 571807.33 12.00 10649.43 90.00 MWD 13550.93 86.41 17.10 6459.91 4475.69 9711.18 5973227.74 571819.25 12.00 10682.93 89.62 MWD 13600.00 85.71 22.96 6463.28 4521.66 9727.94 5973273.84 571835.63 12.00 10718.87 97.00 MWD 13700.00 84.44 34.94 6471.90 4608.69 9776.07 5973361.25 571883.03 12.00 10801.47 96.60 MWD 13725.93 84.14 38.05 6474.48 4629.43 9791.42 5973382.12 571898.20 12.00 10824.61 95.56 MWD 13800.00 83.75 29.12 6482.31 4690.72 9832.12 5973443.74 571938.39 12.00 10888.84 267.00 MWD 13900.00 83.46 17.05 6493.49 4781.96 9871.02 5973535.29 571976.53 12.00 10965.17 267.94 MWD 14000.00 83.46 4.97 6504.92 4879.30 9889.96 5973632.77 571994.66 12.00 11026.54 269.29 MWD 14100.00 83.74 352.90 6516.11 4978.47 9888.12 5973731.92 571992.00 12.00 11070.27 270.67 MWD i 14200.00 84.30 340.85 6526.57 ~ 5075.14 9865.57 5973828.39 571968.65 12.00 11094.44 272.03 MWD • • a M __.Y .__...,.... _.. a C w O O r 00 r N c0 a/ f0 C O .~ U N N f0 U_ t' N $ ~~fF$f ~ ~ t ~_ ~ $~ab~~: ~ ~0 8 saecagtf9ar^i==a;i $ $z$iS•$3a$~~ 46~~~~ aipBMia ~ 3 $SsA$S$ 8 ~ g~ c a _ _ v 8^ m J~°° i e8as688B69888RAY889 ~ R•aM1ai:s.2.f~~aai .~ ~ 88p8rya8a68gp8yg8q ~ EEibB ~/~ - ~ ~ ~a: mU ~ g~ tl 858j8888888B8a88888 qq5$y ~7~~CiC VI a ¢ ~ o w- ~~ ~ 5a88e:YRa.tRSatY 5355353 Q ~= ~ 'o e i~ ~ti~`- v fi -sieaza-afertaifr- ~~ $$$ ' S$~lii$6$ i~ $ g s a 8 . -.Ca c 3 A Ii ; bg e$ $_ ~~ < ~ ~~ w rca4arca [C OH6_ ~ n:aectys:95f:ttii•,-' llSii99$$!9$S$I$Yi3 y~eiiif iiS9aa19889 f::::afRSaa:aift-~ ~~ q$ ~~ ~~ ~ ~~ ~L~ 3 3~figtS P 5 9ip99ga=apftalbp:ia f9Ya::a:afaYBiBffii 5 c a DE _ togg ' "~ u ~ ~~ ~9 9 aBie.aa..aa:::aaaae - -` ~ 6 d - 006°= i ~aso^~$i 3aasaii 0 0 m N m g r r $safi3a33ii5a [U~/l~OOI] 4142 e~sgnsn anal • urements are from i t~ of bag of bag of blind/shear Blind/Shears of pipes/slip 2" combi ram/slips • 1 C-14A BAG TOTs ~ ~ Mud Cross I I Mud Cross of flow cross le of pipe/slip 2 3/$" pipe/slip of pipe/slips 2" pipe/slips Flow Tee TOTs ~1 `~ S ~~P ~ ~? ~~/ V'~ i 10Qdd 1 i i i 147,00 ,~ ~ .- GC2 l1~ , ~ I I I , ~ ~ ' i~ ~ ~ ~ _ ' ~ I ' ; ~ , ~ ~~ ~ i~~i~,; ' jay ' , i ;~ ' , ; f ~ ~ ~ ~ ii~~l, ; ~ ; ~ !I ' I ~ i ~ I , ' f-~I~; ~~ I!~ i ~< <,~ ~,~ ;, ~- ~ ;I~ 1 I ,I P f, ,, ~ I '~ ~ ~ ~ , ~ I I ~ : ( ' ~ ~ ii ~ ~ I G i i ~ I , , , , , , , I~ t ~ ~, . ii ~,,, ~.:' ~ ,,, .. ~ ~ ~. ,,,, ,~ ~! s, ~ ~ r~ ~ ~ ~ G ~ ~ .. 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' ',~; i 1~ o f I ~ ~ ~ ~,,. f r ;i i I I ~ l; ( TERRIE L NUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF C] 89-6/7252 246 DATE ~ ~~J M I.~~ OLLARS First National Bank ~Claska Anchorage, AK 99501 MEMO ' ~ ~ ~~ _ ~: 1 25 200060:99 L4~~~6 2 27~~~ L 556~~' 0 246 • S~"c-~`~~C_F- ~~ ~~ TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL/L' ETTER WELL NAME ~~~~ ~ ~°~ ~~~~ CHECK WHAT % ADD-ONS ``CLUE" APPLIES (OPTIONS) , ~ MULTI I The permit is for a new welibore segment of LATERAL existing well , ~ Permit into, API No. !, (If API number ' Production should continue to be reported as last two (?} digits ' a function of the original API number stated are between 60-69) ,above. • In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both '; name (name on permit plus PH) and API number (~0 - 70/80) from records, data and togs acquired ~~, for welt (name on permit). ', PILOT HOLE ~~ ', SPACLNG ;The permit is approved subject to full ~, EXCEPTION 'compliance with 20 AAC 25.0~~. Approval to i ent tin i / ~ ' j g s con infect perforate and produce upon issuance of a conservation order ' !approving a spacing exception. ', (Company Name} assumes I the liability of any protest to the spacing I i exception that may occur. DRY DITCH I All dry ditch sample sets submitted to the SA>VIPLE I Commission must be in no greater than 30' ,' sample intervals from below the permafrost I ' ~ or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transm ittal_chec klist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1C-14A Program SER Well bore seg ^ PTD#:2060010 Comp any CONOCOPHILLIPS ALASKA INC Initial Classll-ype SER ! PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached___ -_-________________ ___________ _________Yes-_--_- ___---.-____-----__ ------------------------------------------------- 2 Lease number appropriate- - - Yes - - - - - - 3 Uniquewell_nameandnumb_e[ -- ------ -- - ---- ---- Yes-- -- -- - -- -- ---- -- -- -- --- -- 4 Well located in a_defined-pool Yes - - _ KUPARUK RIVER,_KUP_ARUK RVOIL - 490100, governed by Conservation Order No. 4320. _ . _ _ 5 Well located proper distance from drilling unit_boundary_ - - - - - - - Yes - - _ _ Conservation Ord_e[ No. 4320 contains no spacing restrictions with respect to drilling unit boundaries. _ - . - - - - - 6 Well located proper distance_ from other wells- - _ _ - Yes _ Conservation Order No. 4320 has no interwell-s acin _restrictions, - - p g - 7 Sufficient acreage available in_drillinq unit_ _ - Yes - - _ _ - Conservation Order No. 4320 has no interwell_spacing-restrictions, Wellbore will be-1750' from fhe_KRU , - _ - , _ 8 If-deviated,is-wellboreplatincluded__________________________ _________Yes_--__ _bounda_rywhereownership cha_nges,_-____-----_____--_____-__-.__-_____---_,-__-_ 9 Operator only affected party - Yes 10 Oper_atorhas-appropriate-bond inforce________________________ _________Yes-____. __,___.___.-__, 11 Permit can be issued without conservation order - - - - Yes - - Appr Date 12 Permit can be issued without administrativ_e_approval _ _ Yes _ - - - - - SFD 11412006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put1O# in_comments)_(Fcr- Yes Area Injection Order No._2B - _ - , _ , - _ _ _ - _ _ - - _ 15 All wells-within 1/4_mile area of review identified (For sen!ice well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ _ - _ _ _ KRU 1 C-22, West Sak 28242 24_ - - _ _ - _ .. - _ _ _ - _ _ _ _ _ - _ _ _ _ _ _ . - _ ------------------- 16 Pre-produced injector: duration of pre production I_essthan-3 months-(For servicewell_onty) _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - ACMP_Findingof Consistency_hasbeenissued_forthisproject--________ _________ NA_----__ _Sidetrackofexistingwell_____-__-__----__ __---_-_----_-_--_____-----_- Engineering 18 Conductorstring_p_rovided_________________________ ______ _________ NA___.___ Conduetorset_inoriginal-well~1_C-14(198-017).---______--____--__--__--____--------- 19 Surfaceszsingprotectsall-known_U_--s___________________-- ------..-_-___--- ---aquiersexempted,4--___147.1Q_(_)__._____-.-______________--_-_______-._ 20 CMT-vol-adequate_tocirculate-onconducto[&surf_csg________________ ________ NA______- -Surf_acecasingsetin_1_C-14.--___--,__----____--_--_____---_-_____----- 21 CMT-vol_adequate_totie-in long string to surfcsg--------- ---------- -- NA__--- -Production-easingse3 in-1C-14,___--_-___-__---____---_______---:_ 22 CMT_willeoyerallknown-productivehorizon_s____ ________________ _________ No--_--__ _Partiallycementedlinerpl_armed.-Remainderslotted.-____-_--_______---.____-_____-______ 23 Casing desyns adequate for G,_T, B &-permaf[ost_ - - _ Yes O[iginal well_meet design requirements, NA for slotted-liner, _ _ _ - - _ _ _ _ - 24 Adequate tankage_or reserve pit - - _ _ _ _ _ - - _ - - Yes - _ Rig is_equipped with steel_pits..No reserve_pitplanned, All waste to approved disposal_wells.- - - . _ - - 25 If_a_re-drill,has_a_10-403forabandonment been approved______________ ________Yes-_____ -$06-005.__--_______---__ __-.-,- 26 Adequate wellbore separation_proposed_ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - _ _ - Ido proximity issues identified, Nearest branch is abandoned section of 1C_14 and trajectories diverge.. _ - . - - . 27 If diverter required, does it meet regulations_ - _ _ - - NA- - BOP stackwill already-be in place, - - - _ _ . _ _ - -- Appr Date 28 _D_rilling fluid-program schematic & equip listadequate- , - _ Yes Maximum expect formation pressure 13.2 EMW, Managed pressure drilling planned with 8.6 ppg fluid_and applied TEM 1!512006 29 BOPES, do they meet-regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - - - - _ _ _ _ or friction_al_ pressure.- 2 well volumes of kiltweight fluid on_loc_ation_as contingency.. _ - _ _ _ _ _ _ _ . _ _ - _ _ _ 30 BOPE-press rating appropriate; test to_(put prig in comments)_ Yes - - - - - - MASP at_3836 psi. Planned BOP test pressure 4000 psi. - - - _ _ - _ _ 31 Choke-manifoldcomplleswlAPIRP-53 fMay64)_ Yes _ _ - _ 32 Work will occur without operationshutdown _ _ Ye$ - - - - - 33 Is presence-of H2Sgri-probable - - - - _ - - Yes - - _ - _ H2S is reported_on-1C_pad._ Mud should preclude-H2S-on_rig._ Rig has sensors and-alarms-- - - - - - - - - - - - 34 Mechanical-condition of wells within AOR verged (For_service well only) - - Yes - _ 1 C-22 is outside the 114 mile.. W$24 is satisfaetorily_abandoned. - _ _ _ _ _ _ _ Geology 35 Pe[mitcan be issued w!ohydrogen-sulfide measures - - - - - - - . - - - - No- - . - _ 1 C-Pad wells measured 20 to 90 ppm_ H2S_dunng 2004. H2$ measures needed. - _ - - - _ _ - 36 Data_presented on_ pote_ntial overpressure zones - - _ , - Yes - - - Currentpressure is_ 1.3,2. ppg EMW, but-is-dropping since injection ceased, and is expected to_approach 9.5 ppg_ - Appr Date 37 Seismic analysis of shallow gas-zones_ _ . _ _ NA, - _ - EMW, Will be drilled with $6 ppg mud and coiled tubing while-maintaining pressure to achieve overbalance, SFD 1/4/2006 38 Seabed condition suruey_(if off-shore) - - _ _ _ Nq - Equivalent circulatingdensity.willbe_12,4_ppg.- - - 39 Contact name/phone for weekly_p_rogress reports_ [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ _ _ - - _ _ _ - _ - _ - _ _ _ - - - - - - . Geologic Co i e i Engineering is Date: Com Date o s' ner r: i si o n Ho Date rizontal sidetrack injection well within Ku aruk C sand. 1 p on r: mm ss p~ S m s~ I `, ` ~~- I ~ ! ~ S ~~~~ ~~~ ~' ~-4 R
